OKLAHOMA CITY--(BUSINESS WIRE)--Devon Energy Corp. (NYSE: DVN) today reported operational and financial results for the second quarter of 2017. Also included within the release is the company’s guidance outlook for the third quarter and full-year 2017.
Highlights
- Oil production from U.S. resource plays exceeds guidance
- Operational momentum builds with high-rate wells in STACK and Delaware Basin
- Efficiencies drive 2017 capital outlook $100 million lower
- Free cash flow generation increases cash balances to $2.4 billion
- Divestiture program advances with $340 million of asset sales
“Devon achieved another high-quality operating performance in the second quarter, building operational momentum in our U.S. resource plays and accelerating efficiency gains across our portfolio,” said Dave Hager, president and CEO. “These successful efforts resulted in record-setting well results that drove our U.S. oil production above guidance expectations with a capital investment that was 17 percent below our budget year to date. As a result of this strong capital efficiency, we are lowering our full-year capital outlook by $100 million and, importantly, we have not made any changes to our planned activity levels in 2017.
“Given our advantaged asset base and ability to deliver best-in-class well results, we remain well positioned to deliver value and returns on our capital investments as we navigate industry conditions,” said Hager. “With our ability to deliver attractive returns in this environment, our top strategic priorities are to maintain operational momentum in our U.S. resource plays, organically fund our capital investment and further improve our investment-grade financial strength.”
STACK and Delaware Basin Drive U.S. Oil Production Beat
Devon’s net production averaged 536,000 oil-equivalent barrels (Boe) per day during the second quarter of 2017, exceeding midpoint guidance by 6,000 Boe per day. Of this total, oil production accounted for the largest component of the company’s product mix at 44 percent of total volumes.
The majority of Devon’s production was attributable to its U.S. resource plays, which averaged 412,000 Boe per day. This performance was highlighted by 8 percent production growth from the company’s STACK and Delaware Basin assets compared to the previous quarter, driving light-oil production in the U.S. above the top end of guidance to an average of 116,000 barrels per day.
Recent drilling activity from the company’s U.S. operations was highlighted by nine high-rate development wells in the STACK and Delaware Basin that achieved initial 30-day rates averaging nearly 2,000 Boe per day.
Best-In-Class Well Productivity
These high-rate development wells showcase Devon’s asset quality and outstanding execution that has generated best-in-class well productivity in North America. Based on publicly available data over the past year, Devon’s 90-day production rates from new wells have achieved the highest rates of any operator and the company’s well productivity has improved by more than 450 percent since 2012 (see page 6 of Q2 Operations Report for more detail).
Strong Exit Rates Build Momentum into 2018
Based on strong results year to date, Devon is firmly on track to achieve its full-year 2017 production targets. Importantly, based on accelerated activity levels in the second half of 2017, the company projects U.S. oil production to exit the year at a rate of 18 to 23 percent higher than the fourth quarter of 2016.
This strong production growth over the remainder of 2017 is driven by the company’s focused capital program in the STACK and Delaware Basin where 90 percent of its U.S. rig activity is allocated. Combined, these two franchise growth assets are expected to advance production by greater than 30 percent by the end of 2017 compared to the same period a year ago. With this strong growth in higher-margin production, liquids volumes are now projected to reach approximately 65 percent of Devon’s product mix by year-end.
In the third quarter, Devon expects total companywide oil production to range between 234,000 and 244,000 barrels per day. A maintenance event at Jackfish 2, completed over a three-week period in July, is expected to curtail production by approximately 15,000 barrels per day in the third quarter.
Lowering 2017 Capital Outlook by $100 Million
In the first half of 2017, the company’s E&P capital expenditures have been 17 percent below the midpoint of guidance, or 39 percent of the full-year budget. This strong performance has been driven by drilling and completion efficiency gains in the STACK and Delaware Basin combined with innovative supply chain initiatives that have completely offset industry inflation year to date.
Due to these positive operating trends, Devon now expects E&P capital investment to range from $1.9 billion to $2.2 billion in 2017, a $100 million decrease compared to previous guidance. With this updated outlook, the company has not made any changes to its planned activity levels in 2017 and is on track to increase to approximately 20 rigs by the end of 2017.
Second-Quarter 2017 Operations Report
For additional details regarding well results and other information about Devon’s E&P operations, please refer to the company’s second-quarter 2017 operations report at www.devonenergy.com. Highlights from the report include:
- STACK production advances 20 percent year to date
- Record Meramec well reaches 6,000 Boe per day
- High-rate oil wells jump-start growth in Delaware Basin
- Resource potential expands in Wolfcamp and Woodford plays
- Powder River Basin delivers strong appraisal wells
Midstream Business Positioned to Achieve Double-Digit Growth in 2017
The company’s midstream business generated $224 million of operating profit in the second quarter, an 8 percent increase compared to the first quarter of 2017. This growth was driven entirely by Devon’s strategic investment in EnLink Midstream. Devon expects its midstream operating profits to advance to a range of $900 million to $950 million in 2017. Based on midpoint guidance, this estimate represents a 10 percent increase compared to 2016.
Devon has a 64 percent ownership in EnLink’s general partner (NYSE: ENLC) and a 23 percent interest in the limited partner (NYSE: ENLK). In aggregate, the company’s ownership in EnLink has a market value of approximately $3.6 billion and is expected to generate cash distributions of approximately $270 million annually.
Significant Operating Cost Improvement by Year-End
Devon’s cost-reduction initiatives are expected to achieve $1.4 billion of annualized operating and general and administrative expenses (G&A) savings in 2017. Lease operating expenses (LOE), the company’s largest field-level cost, totaled $399 million or $8.18 per Boe in the second quarter. Of this amount, $20 million was related to costs associated with maintenance work at Jackfish 3.
Looking ahead, the company projects its per-unit LOE to improve 5 to 10 percent by year-end compared to second-quarter results. This per-unit improvement is driven by the combination of higher production rates from the company’s resource plays and lower operating costs in Canada.
The company also is effectively managing its G&A cost structure. Overhead expenses declined to $164 million in the second quarter, a 9 percent improvement compared to the first quarter. This result was $21 million below the bottom end of the company’s guidance range. Savings were driven by lower employee-related costs.
Higher-Margin Production Expands Operating Cash Flow 135 Percent
Devon’s operating cash flow totaled $810 million in the second quarter compared to $345 million in the year-ago quarter. This 135 percent increase in operating cash flow year over year was attributable to higher commodity prices and an improved cost structure.
Devon’s reported net earnings totaled $425 million or $0.80 per diluted share in the second quarter. Adjusting for items that securities analysts typically exclude from their published estimates, the company’s core earnings totaled $177 million or $0.34 per diluted share.
Free Cash Flow Generation Increases Cash Balances to $2.4 Billion
In the second quarter, the company’s upstream operations fully funded its capital requirements and generated free cash flow, which helped increase Devon’s cash balances by $250 million to $2.4 billion at the end of June.
In addition to the company’s strong liquidity and investment-grade ratings, Devon’s financial position is further bolstered by its attractive hedge position. The company currently has approximately 55 percent of its estimated oil and gas production protected for the second half of 2017 at above-market prices and is in the process of accumulating additional hedges in 2018. This disciplined, risk-management program consists of systematic hedges added on a quarterly basis and discretionary hedges that take advantage of favorable market conditions.
Divestiture Program Achieves $340 Million of Asset Sales
The company’s financial strength will be further enhanced by proceeds from its previously announced $1 billion divestiture program. In aggregate, Devon’s divestiture program will include approximately 35,000 Boe per day (approximately 30 percent liquids) from select leasehold positions within the Barnett Shale and the Eagle Ford, along with other minor non-core properties across the U.S.
In July, Devon took an important step toward its divestiture goal by announcing the sale of its non-core Lavaca County assets in the Eagle Ford for $205 million, which is expected to close by the end of 2017. Combined with other minor asset sales, Devon now has sold $340 million of assets or roughly one-third of its divestiture target.
Efforts to monetize Devon’s Johnson County properties in the Barnett Shale are also progressing. The Johnson County assets represent approximately 20 percent of the company’s net production and cash flow generated from its Barnett Shale position. Devon is actively marketing these assets and expects to complete its $1 billion non-core divestiture program over the next year.
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. Core earnings and core earnings per share referenced within the commentary of this release are non-GAAP financial measures. Reconciliations of these and other 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. 2, 2017, 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; 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, potential locations, risked and unrisked locations, estimated ultimate recovery (or EUR), exploration target size and other similar terms. 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.
| DEVON ENERGY CORPORATION | ||||||||||||||||
| FINANCIAL AND OPERATIONAL INFORMATION | ||||||||||||||||
| PRODUCTION NET OF ROYALTIES | ||||||||||||||||
| Quarter Ended | Six Months Ended | |||||||||||||||
| June 30, | June 30, | |||||||||||||||
| 2017 | 2016 | 2017 | 2016 | |||||||||||||
| Oil and bitumen (MBbls/d) | ||||||||||||||||
| U. S. | 116 | 123 | 119 | 132 | ||||||||||||
| Heavy Oil | 122 | 121 | 130 | 124 | ||||||||||||
| Retained assets | 238 | 244 | 249 | 256 | ||||||||||||
| Divested assets | — | 15 | — | 16 | ||||||||||||
| Total | 238 | 259 | 249 | 272 | ||||||||||||
| Natural gas liquids (MBbls/d) | ||||||||||||||||
| U. S. | 97 | 110 | 97 | 113 | ||||||||||||
| Divested assets | — | 21 | — | 21 | ||||||||||||
| Total | 97 | 131 | 97 | 134 | ||||||||||||
| Gas (MMcf/d) | ||||||||||||||||
| U. S. | 1,194 | 1,293 | 1,200 | 1,322 | ||||||||||||
| Heavy Oil | 14 | 28 | 18 | 22 | ||||||||||||
| Retained assets | 1,208 | 1,321 | 1,218 | 1,344 | ||||||||||||
| Divested assets | — | 206 | — | 210 | ||||||||||||
| Total | 1,208 | 1,527 | 1,218 | 1,554 | ||||||||||||
| Oil equivalent (MBoe/d) | ||||||||||||||||
| U. S. | 412 | 448 | 417 | 465 | ||||||||||||
| Heavy Oil | 124 | 126 | 133 | 127 | ||||||||||||
| Retained assets | 536 | 574 | 550 | 592 | ||||||||||||
| Divested assets | — | 70 | — | 73 | ||||||||||||
| Total | 536 | 644 | 550 | 665 | ||||||||||||
| KEY OPERATING STATISTICS BY REGION | ||||||||||||
| Quarter Ended June 30, 2017 | ||||||||||||
| Avg. Production | Gross Wells | Operated Rigs at | ||||||||||
| (MBoe/d) | Drilled | June 30, 2017 | ||||||||||
| STACK | 105 | 46 | 7 | |||||||||
| Delaware Basin | 56 | 29 | 6 | |||||||||
| Eagle Ford(1) | 63 | 1 | 2 | |||||||||
| Heavy Oil | 124 | 18 | 1 | |||||||||
| Barnett Shale | 155 | — | — | |||||||||
| Rockies Oil | 18 | 3 | 2 | |||||||||
| Other assets | 15 |
5 |
— | |||||||||
| Total | 536 | 102 | 18 | |||||||||
|
(1) Includes partner rig. |
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| FINANCIAL AND OPERATIONAL INFORMATION | ||||||||||||||||||||
| PRODUCTION TREND | ||||||||||||||||||||
| 2016 | 2017 | |||||||||||||||||||
| Quarter 2 | Quarter 3 | Quarter 4 | Quarter 1 | Quarter 2 | ||||||||||||||||
| Oil and bitumen (MBbls/d) | ||||||||||||||||||||
| STACK | 19 | 21 | 19 | 21 | 25 | |||||||||||||||
| Delaware Basin | 36 | 31 | 29 | 30 | 30 | |||||||||||||||
| Eagle Ford | 41 | 33 | 34 | 48 | 36 | |||||||||||||||
| Heavy Oil | 121 | 137 | 139 | 138 | 122 | |||||||||||||||
| Barnett Shale | 1 | 1 | 1 | 1 | 1 | |||||||||||||||
| Rockies Oil | 15 | 11 | 11 | 13 | 13 | |||||||||||||||
| Other assets | 11 | 11 | 11 | 10 | 11 | |||||||||||||||
| Retained assets | 244 | 245 | 244 | 261 | 238 | |||||||||||||||
| Divested assets | 15 | 6 | — | — | — | |||||||||||||||
| Total | 259 | 251 | 244 | 261 | 238 | |||||||||||||||
| Natural gas liquids (MBbls/d) | ||||||||||||||||||||
| STACK | 30 | 23 | 21 | 26 | 31 | |||||||||||||||
| Delaware Basin | 13 | 12 | 10 | 10 | 10 | |||||||||||||||
| Eagle Ford | 17 | 13 | 11 | 15 | 11 | |||||||||||||||
| Barnett Shale | 46 | 44 | 43 | 43 | 42 | |||||||||||||||
| Rockies Oil | 1 | 1 | 1 | 1 | 1 | |||||||||||||||
| Other assets | 3 | 3 | 4 | 3 | 2 | |||||||||||||||
| Retained assets | 110 | 96 | 90 | 98 | 97 | |||||||||||||||
| Divested assets | 21 | 8 | — | — | — | |||||||||||||||
| Total | 131 | 104 | 90 | 98 | 97 | |||||||||||||||
| Gas (MMcf/d) | ||||||||||||||||||||
| STACK | 289 | 292 | 284 | 287 | 298 | |||||||||||||||
| Delaware Basin | 99 | 92 | 89 | 88 | 96 | |||||||||||||||
| Eagle Ford | 103 | 85 | 90 | 119 | 96 | |||||||||||||||
| Heavy Oil | 28 | 18 | 18 | 23 | 14 | |||||||||||||||
| Barnett Shale | 757 | 730 | 710 | 683 | 675 | |||||||||||||||
| Rockies Oil | 31 | 19 | 17 | 15 | 17 | |||||||||||||||
| Other assets | 14 | 13 | 13 | 13 | 12 | |||||||||||||||
| Retained assets | 1,321 | 1,249 | 1,221 | 1,228 | 1,208 | |||||||||||||||
| Divested assets | 206 | 75 | — | — | — | |||||||||||||||
| Total | 1,527 | 1,324 | 1,221 | 1,228 | 1,208 | |||||||||||||||
| Oil equivalent (MBoe/d) | ||||||||||||||||||||
| STACK | 97 | 92 | 88 | 95 | 105 | |||||||||||||||
| Delaware Basin | 65 | 59 | 54 | 54 | 56 | |||||||||||||||
| Eagle Ford | 76 | 61 | 60 | 83 | 63 | |||||||||||||||
| Heavy Oil | 126 | 140 | 141 | 141 | 124 | |||||||||||||||
| Barnett Shale | 173 | 166 | 163 | 158 | 155 | |||||||||||||||
| Rockies Oil | 21 | 16 | 15 | 17 | 18 | |||||||||||||||
| Other assets | 16 | 16 | 16 | 15 | 15 | |||||||||||||||
| Retained assets | 574 | 550 | 537 | 563 | 536 | |||||||||||||||
| Divested assets | 70 | 27 | — | — | — | |||||||||||||||
| Total | 644 | 577 | 537 | 563 | 536 | |||||||||||||||
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| FINANCIAL AND OPERATIONAL INFORMATION | |||||||||||||||||||||
| BENCHMARK PRICES | |||||||||||||||||||||
| (average prices) | Quarter 2 | June YTD | |||||||||||||||||||
| 2017 | 2016 | 2017 | 2016 | ||||||||||||||||||
| Oil ($/Bbl) - West Texas Intermediate (Cushing) | $ | 48.32 | $ | 45.54 | $ | 50.16 | $ | 39.60 | |||||||||||||
| Natural Gas ($/Mcf) - Henry Hub | $ | 3.19 | $ | 1.95 | $ | 3.25 | $ | 2.02 | |||||||||||||
| REALIZED PRICES | Quarter Ended June 30, 2017 | ||||||||||||||||||||
| Oil /Bitumen | NGL | Gas | Total | ||||||||||||||||||
| (Per Bbl) | (Per Bbl) | (Per Mcf) | (Per Boe) | ||||||||||||||||||
| United States | $ | 46.65 | $ | 13.26 | $ | 2.50 | $ | 23.58 | |||||||||||||
| Canada | $ | 29.05 | N/M | N/M | $ | 28.50 | |||||||||||||||
| Realized price without hedges | $ | 37.63 | $ | 13.26 | $ | 2.50 | $ | 24.72 | |||||||||||||
| Cash settlements | $ | 0.29 | $ | (0.03 | ) | $ | 0.04 | $ | 0.22 | ||||||||||||
| Realized price, including cash settlements | $ | 37.92 | $ | 13.23 | $ | 2.54 | $ | 24.94 | |||||||||||||
| 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 | |||||||||||||
| Year Ended June 30, 2017 | |||||||||||||||||||||
| Oil /Bitumen | NGL | Gas | Total | ||||||||||||||||||
| (Per Bbl) | (Per Bbl) | (Per Mcf) | (Per Boe) | ||||||||||||||||||
| United States | $ | 48.18 | $ | 14.36 | $ | 2.59 | $ | 24.72 | |||||||||||||
| Canada | $ | 27.60 | N/M | N/M | $ | 27.03 | |||||||||||||||
| Realized price without hedges | $ | 37.48 | $ | 14.36 | $ | 2.59 | $ | 25.28 | |||||||||||||
| Cash settlements | $ | 0.39 | $ | (0.02 | ) | $ | — | $ | 0.19 | ||||||||||||
| Realized price, including cash settlements | $ | 37.87 | $ | 14.34 | $ | 2.59 | $ | 25.47 | |||||||||||||
| Year 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 | |||||||||||||
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| FINANCIAL AND OPERATIONAL INFORMATION | ||||||||||||||||||||||||
| CONSOLIDATED STATEMENTS OF EARNINGS | ||||||||||||||||||||||||
| (in millions, except per share amounts) | Quarter Ended | Six Months Ended | ||||||||||||||||||||||
| June 30, | June 30, | |||||||||||||||||||||||
| 2017 | 2016 | 2017 | 2016 | |||||||||||||||||||||
| Oil, gas and NGL sales | $ | 1,206 | $ | 1,085 | $ | 2,515 | $ | 1,910 | ||||||||||||||||
| Oil, gas and NGL derivatives | 126 | (142 | ) | 358 | (109 | ) | ||||||||||||||||||
| Marketing and midstream revenues | 1,927 | 1,545 | 3,937 | 2,813 | ||||||||||||||||||||
| Asset dispositions and other | 14 | - | 10 | - | ||||||||||||||||||||
| Total revenues and other | 3,273 | 2,488 | 6,820 | 4,614 | ||||||||||||||||||||
| Lease operating expenses | 399 | 416 | 785 | 860 | ||||||||||||||||||||
| Marketing and midstream operating expenses | 1,703 | 1,338 | 3,506 | 2,404 | ||||||||||||||||||||
| General and administrative expenses | 164 | 147 | 345 | 341 | ||||||||||||||||||||
| Production and property taxes | 71 | 75 | 156 | 153 | ||||||||||||||||||||
| Depreciation, depletion and amortization | 381 | 484 | 762 | 1,026 | ||||||||||||||||||||
| Asset impairments | — | 1,497 | 7 | 4,532 | ||||||||||||||||||||
| Restructuring and transaction costs | — | 24 | — | 271 | ||||||||||||||||||||
| Other operating items | 13 | 4 | 11 | 24 | ||||||||||||||||||||
| Total operating expenses | 2,731 | 3,985 | 5,572 | 9,611 | ||||||||||||||||||||
| Operating income (loss) | 542 | (1,497 | ) | 1,248 | (4,997 | ) | ||||||||||||||||||
| Net financing costs | 116 | 163 | 243 | 327 | ||||||||||||||||||||
| Other nonoperating items | (32 | ) | 85 | (51 | ) | 106 | ||||||||||||||||||
| Earnings (loss) before income taxes | 458 | (1,745 | ) | 1,056 | (5,430 | ) | ||||||||||||||||||
| Income tax expense (benefit) | 7 | (182 | ) | 26 | (399 | ) | ||||||||||||||||||
| Net earnings (loss) | 451 | (1,563 | ) | 1,030 | (5,031 | ) | ||||||||||||||||||
| Net earnings (loss) attributable to noncontrolling interests | 26 | 7 | 40 | (405 | ) | |||||||||||||||||||
| Net earnings (loss) attributable to Devon | $ | 425 | $ | (1,570 | ) | $ | 990 | $ | (4,626 | ) | ||||||||||||||
| Net earnings (loss) per share attributable to Devon: | ||||||||||||||||||||||||
| Basic | $ | 0.81 | $ | (3.04 | ) | $ | 1.88 | $ | (9.33 | ) | ||||||||||||||
| Diluted | $ | 0.80 | $ | (3.04 | ) | $ | 1.87 | $ | (9.33 | ) | ||||||||||||||
| Weighted average common shares outstanding: | ||||||||||||||||||||||||
| Basic | 526 | 524 | 525 | 502 | ||||||||||||||||||||
| Diluted | 529 | 524 | 528 | 502 | ||||||||||||||||||||
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| FINANCIAL AND OPERATIONAL INFORMATION | ||||||||||||||||||||||||
| CONSOLIDATED STATEMENTS OF CASH FLOWS | ||||||||||||||||||||||||
| (in millions) | Quarter Ended | Six Months Ended | ||||||||||||||||||||||
| June 30, | June 30, | |||||||||||||||||||||||
| 2017 | 2016 | 2017 | 2016 | |||||||||||||||||||||
| Cash flows from operating activities: | ||||||||||||||||||||||||
| Net earnings (loss) | $ | 451 | $ | (1,563 | ) | $ | 1,030 | $ | (5,031 | ) | ||||||||||||||
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Adjustments to reconcile net earnings (loss) to net cash from operating activities: |
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| Depreciation, depletion and amortization | 381 | 484 | 762 | 1,026 | ||||||||||||||||||||
| Asset impairments | — | 1,497 | 7 | 4,532 | ||||||||||||||||||||
| Gains on asset sales | (11 | ) | — | (7 | ) | — | ||||||||||||||||||
| Deferred income tax benefit | (5 | ) | (179 | ) | (6 | ) | (386 | ) | ||||||||||||||||
| Commodity derivatives | (126 | ) | 142 | (358 | ) | 109 | ||||||||||||||||||
| Cash settlements on commodity derivatives | 11 | (16 | ) | 19 | 3 | |||||||||||||||||||
| Other derivatives and financial instruments | 16 | 81 | 7 | 308 | ||||||||||||||||||||
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Cash settlements on other derivatives and financial instruments |
2 | (28 | ) | — | (151 | ) | ||||||||||||||||||
| Asset retirement obligation accretion | 14 | 20 | 31 | 39 | ||||||||||||||||||||
| Share-based compensation | 43 | 32 | 89 | 140 | ||||||||||||||||||||
| Other | (49 | ) | 36 | (49 | ) | (158 | ) | |||||||||||||||||
| Net change in working capital | 72 | (143 | ) | 87 | 71 | |||||||||||||||||||
| Change in long-term other assets | 9 | (40 | ) | 10 | 13 | |||||||||||||||||||
| Change in long-term other liabilities | 2 | 22 | 22 | (5 | ) | |||||||||||||||||||
| Net cash from operating activities | 810 | 345 | 1,644 | 510 | ||||||||||||||||||||
| Cash flows from investing activities: | ||||||||||||||||||||||||
| Capital expenditures | (721 | ) | (489 | ) | (1,468 | ) | (1,238 | ) | ||||||||||||||||
| Acquisitions of property, equipment and businesses | (13 | ) | (11 | ) | (33 | ) | (1,638 | ) | ||||||||||||||||
| Proceeds from sale of investment | — | — | 190 | — | ||||||||||||||||||||
| Divestitures of property and equipment | 76 | 191 | 114 | 209 | ||||||||||||||||||||
| Other | (1 | ) | (26 | ) | (4 | ) | (27 | ) | ||||||||||||||||
| Net cash from investing activities | (659 | ) | (335 | ) | (1,201 | ) | (2,694 | ) | ||||||||||||||||
| Cash flows from financing activities: | ||||||||||||||||||||||||
| Borrowings of long-term debt, net of issuance costs | 982 | 450 | 1,795 | 846 | ||||||||||||||||||||
| Repayments of long-term debt | (798 | ) | (290 | ) | (1,385 | ) | (549 | ) | ||||||||||||||||
| Payment of installment payable | — | — | (250 | ) | — | |||||||||||||||||||
| Net short-term debt repayments | — | — | — | (626 | ) | |||||||||||||||||||
| Issuance of common stock | — | — | — | 1,469 | ||||||||||||||||||||
| Issuance of subsidiary units | 17 | 49 | 72 | 776 | ||||||||||||||||||||
| Dividends paid on common stock | (33 | ) | (33 | ) | (65 | ) | (158 | ) | ||||||||||||||||
| Contributions from noncontrolling interests | 8 | 3 | 29 | 6 | ||||||||||||||||||||
| Distributions to noncontrolling interests | (82 | ) | (74 | ) | (163 | ) | (147 | ) | ||||||||||||||||
| Shares traded for tax withholdings | (3 | ) | (10 | ) | (64 | ) | (28 | ) | ||||||||||||||||
| Other | — | (5 | ) | (2 | ) | (6 | ) | |||||||||||||||||
| Net cash from financing activities | 91 | 90 | (33 | ) | 1,583 | |||||||||||||||||||
| Effect of exchange rate changes on cash | 8 | (12 | ) | — | 14 | |||||||||||||||||||
| Net change in cash and cash equivalents | 250 | 88 | 410 | (587 | ) | |||||||||||||||||||
| Cash and cash equivalents at beginning of period | 2,119 | 1,635 | 1,959 | 2,310 | ||||||||||||||||||||
| Cash and cash equivalents at end of period | $ | 2,369 | $ | 1,723 | $ | 2,369 | $ | 1,723 | ||||||||||||||||
| DEVON ENERGY CORPORATION | ||||||||||||
| FINANCIAL AND OPERATIONAL INFORMATION | ||||||||||||
| CONSOLIDATED BALANCE SHEETS | ||||||||||||
| (in millions) | June 30, | December 31, | ||||||||||
| 2017 | 2016 | |||||||||||
| Current assets: | ||||||||||||
| Cash and cash equivalents | $ | 2,369 | $ | 1,959 | ||||||||
| Accounts receivable | 1,248 | 1,356 | ||||||||||
| Assets held for sale | — | 193 | ||||||||||
| Other current assets | 469 | 264 | ||||||||||
| Total current assets | 4,086 | 3,772 | ||||||||||
| Property and equipment, at cost: | ||||||||||||
| Oil and gas, based on full cost accounting: | ||||||||||||
| Subject to amortization | 77,326 | 75,648 | ||||||||||
| Not subject to amortization | 3,048 | 3,437 | ||||||||||
| Total oil and gas | 80,374 | 79,085 | ||||||||||
| Midstream and other | 10,908 | 10,455 | ||||||||||
| Total property and equipment, at cost | 91,282 | 89,540 | ||||||||||
| Less accumulated depreciation, depletion and amortization | (74,460 | ) | (73,350 | ) | ||||||||
| Property and equipment, net | 16,822 | 16,190 | ||||||||||
| Goodwill | 3,964 | 3,964 | ||||||||||
| Other long-term assets | 1,942 | 1,987 | ||||||||||
| Total assets | $ | 26,814 | $ | 25,913 | ||||||||
| Current liabilities: | ||||||||||||
| Accounts payable | $ | 692 | $ | 642 | ||||||||
| Revenues and royalties payable | 949 | 908 | ||||||||||
| Other current liabilities | 891 | 1,066 | ||||||||||
| Total current liabilities | 2,532 | 2,616 | ||||||||||
| Long-term debt | 10,558 | 10,154 | ||||||||||
| Asset retirement obligations | 1,078 | 1,226 | ||||||||||
| Other long-term liabilities | 657 | 894 | ||||||||||
| Deferred income taxes | 659 | 648 | ||||||||||
| Stockholders’ equity: | ||||||||||||
| Common stock | 53 | 52 | ||||||||||
| Additional paid-in capital | 7,211 | 7,237 | ||||||||||
| Accumulated deficit | (656 | ) | (1,646 | ) | ||||||||
| Accumulated other comprehensive earnings | 291 | 284 | ||||||||||
| Total stockholders’ equity attributable to Devon | 6,899 | 5,927 | ||||||||||
| Noncontrolling interests | 4,431 | 4,448 | ||||||||||
| Total stockholders’ equity | 11,330 | 10,375 | ||||||||||
| Total liabilities and stockholders’ equity | $ | 26,814 | $ | 25,913 | ||||||||
| Common shares outstanding | 526 | 523 | ||||||||||
| DEVON ENERGY CORPORATION | ||||||||||||||||||||||||
| FINANCIAL AND OPERATIONAL INFORMATION | ||||||||||||||||||||||||
| CONSOLIDATING STATEMENTS OF OPERATIONS | ||||||||||||||||||||||||
| (in millions) | Quarter Ended June 30, 2017 | |||||||||||||||||||||||
|
Devon U.S. |
EnLink | Eliminations | Total | |||||||||||||||||||||
| Oil, gas and NGL sales | $ | 1,206 | $ | — | $ | — | $ | 1,206 | ||||||||||||||||
| Oil, gas and NGL derivatives | 126 | — | — | 126 | ||||||||||||||||||||
| Marketing and midstream revenues | 833 | 1,264 | (170 | ) | 1,927 | |||||||||||||||||||
| Asset dispositions and other | 9 | 5 | — | 14 | ||||||||||||||||||||
| Total revenues and other | 2,174 | 1,269 | (170 | ) | 3,273 | |||||||||||||||||||
| Lease operating expenses | 399 | — | — | 399 | ||||||||||||||||||||
| Marketing and midstream operating expenses | 849 | 1,024 | (170 | ) | 1,703 | |||||||||||||||||||
| General and administrative expenses | 133 | 31 | — | 164 | ||||||||||||||||||||
| Production and property taxes | 59 | 12 | — | 71 | ||||||||||||||||||||
| Depreciation, depletion and amortization | 244 | 137 | — | 381 | ||||||||||||||||||||
| Other operating items | 22 | (9 | ) | — | 13 | |||||||||||||||||||
| Total operating expenses | 1,706 | 1,195 | (170 | ) | 2,731 | |||||||||||||||||||
| Operating income | 468 | 74 | — | 542 | ||||||||||||||||||||
| Net financing costs | 77 | 39 | — | 116 | ||||||||||||||||||||
| Other nonoperating items | (30 | ) | (2 | ) | — | (32 | ) | |||||||||||||||||
| Earnings before income taxes | 421 | 37 | — | 458 | ||||||||||||||||||||
| Income tax expense | 3 | 4 | — | 7 | ||||||||||||||||||||
| Net earnings | 418 | 33 | — | 451 | ||||||||||||||||||||
| Net earnings attributable to noncontrolling interests | — | 26 | — | 26 | ||||||||||||||||||||
| Net earnings attributable to Devon | $ | 418 | $ | 7 | $ | — | $ | 425 | ||||||||||||||||
| OTHER KEY STATISTICS | |||||||||||||||||||||||
| (in millions) | Quarter Ended June 30, 2017 | ||||||||||||||||||||||
|
Devon U.S. |
EnLink | Eliminations | Total | ||||||||||||||||||||
| Cash flow statement related items: | |||||||||||||||||||||||
| Operating cash flow | $ | 658 | $ | 152 | $ | — | $ | 810 | |||||||||||||||
| Divestitures of property and equipment | $ | 75 | $ | 1 | $ | — | $ | 76 | |||||||||||||||
| Capital expenditures | $ | (505 | ) | $ | (216 | ) | $ | — | $ | (721 | ) | ||||||||||||
| Debt activity, net | $ | — | $ | 184 | $ | — | $ | 184 | |||||||||||||||
| EnLink distributions received (paid) | $ | 67 | $ | (149 | ) | $ | — | $ | (82 | ) | |||||||||||||
| Issuance of subsidiary units | $ | — | $ | 17 | $ |
— |
$ | 17 | |||||||||||||||
| Balance sheet statement items: | |||||||||||||||||||||||
| Net debt (1) | $ | 4,503 | $ | 3,686 | $ |
— |
$ | 8,189 | |||||||||||||||
| (1) Net debt is a non-GAAP measure. For a reconciliation of the comparable GAAP measure, see "Non-GAAP Financial Measures" later in this release. | |||||||||||||||||||||||
| CAPITAL EXPENDITURES | ||||||||||
| (in millions) | Quarter Ended June 30, 2017 | Six Months Ended June 30, 2017 | ||||||||
| Exploration and development capital | $ | 430 | $ | 853 | ||||||
| Land and other acquisitions | 10 | 30 | ||||||||
|
Exploration and production (E&P) capital |
440 | 883 | ||||||||
| Capitalized G&A and interest | 73 | 149 | ||||||||
| Other | 26 | 40 | ||||||||
| Devon capital expenditures (1) | $ | 539 | $ | 1,072 | ||||||
| (1) Excludes $218 million and $466 million attributable to EnLink for the second quarter and first six months of 2017, respectively. | ||||||||||
DEVON ENERGY CORPORATION
FINANCIAL AND OPERATIONAL INFORMATION
NON-GAAP FINANCIAL MEASURES
This press release includes non-GAAP financial measures. These non-GAAP measures are not alternatives to GAAP measures, and you should not consider these non-GAAP measures in isolation or as a substitute for analysis of our results as reported under GAAP. Below is additional disclosure regarding each of the non-GAAP measures used in this press release, including reconciliations to their most directly comparable GAAP measure.
CORE EARNINGS
Devon’s reported net earnings include items of income and expense that are typically excluded by securities analysts in their published estimates of the company’s financial results. Accordingly, the company also uses the measures of core earnings and core earnings per share attributable to Devon. Devon believes these non-GAAP measures facilitate comparisons of its performance to earnings estimates published by securities analysts. Devon also believes these non-GAAP measures can facilitate comparisons of its performance between periods and to the performance of its peers. The following table summarizes the effects of these items on second-quarter 2017 earnings.
| (in millions, except per share amounts) | Quarter Ended June 30, 2017 | |||||||||||||||||||||||
| Before-tax | After-tax |
After |
Per Diluted |
|||||||||||||||||||||
| Earnings attributable to Devon (GAAP) | $ | 458 | $ | 451 | $ | 425 | $ | 0.80 | ||||||||||||||||
| Adjustments: | ||||||||||||||||||||||||
| Fair value changes in financial instruments and foreign currency | (148 | ) | (109 | ) | (109 | ) | (0.21 | ) | ||||||||||||||||
| Deferred tax asset valuation allowance | — | (128 | ) | (128 | ) | (0.23 | ) | |||||||||||||||||
| Gains and losses on asset sales | (11 | ) | (9 | ) | (7 | ) | (0.01 | ) | ||||||||||||||||
| Early retirement of debt | (9 | ) | (7 | ) | (4 | ) | (0.01 | ) | ||||||||||||||||
| Core earnings attributable to Devon (Non-GAAP) | $ | 290 | $ | 198 | $ | 177 | $ | 0.34 | ||||||||||||||||
NET DEBT
Devon defines net debt as debt less cash and cash equivalents and net debt attributable to the consolidation of EnLink Midstream as presented in the following table. Devon believes that netting these sources of cash against debt and adjusting for EnLink net debt provides a clearer picture of the future demands on cash from Devon to repay debt.
| (in millions) | June 30, 2017 | |||||||||||||||||
| Devon U.S. & Canada | EnLink | Devon Consolidated | ||||||||||||||||
| Total debt (GAAP) | $ | 6,861 | $ | 3,697 | $ | 10,558 | ||||||||||||
| Less cash and cash equivalents | (2,358 | ) | (11 | ) | (2,369 | ) | ||||||||||||
| Net debt (Non-GAAP) | $ | 4,503 | $ | 3,686 | $ | 8,189 | ||||||||||||
UPSTREAM CASH FLOW
Devon defines upstream cash flow as cash flow from operations less EnLink cash flow from operations, less cash flow from divested assets and debt repayments, plus distributions received from EnLink. Devon believes upstream cash flow is relevant because it provides a clearer picture of cash flow generation ability from Devon’s retained upstream assets and its investment in EnLink.
| (in billions) | |||||
| Year Ended December 31, 2016 | |||||
| Consolidated cash flow from operations (GAAP) | $ | 1.8 | |||
| Less: EnLink cash flow from operations | 0.7 | ||||
| Devon cash flow from operations | 1.1 | ||||
| Less: cash flow from divested assets | 0.2 | ||||
| Less: cash flow associated with debt repayments | 0.3 | ||||
| Add: EnLink distributions received | 0.3 | ||||
| Upstream cash flow (Non-GAAP) | $ | 0.9 | |||
| DEVON ENERGY CORPORATION | |||||||||||||||
| FORWARD LOOKING GUIDANCE | |||||||||||||||
| PRODUCTION GUIDANCE | |||||||||||||||
| Quarter 3 | Full Year | ||||||||||||||
| Low | High | Low | High | ||||||||||||
| Oil and bitumen (MBbls/d) | |||||||||||||||
| U.S. |
117 |
122 |
119 | 123 | |||||||||||
| Heavy Oil | 117 | 122 | 130 | 135 | |||||||||||
| Total |
234 |
244 |
249 | 258 | |||||||||||
| Natural gas liquids (MBbls/d) | |||||||||||||||
| Total |
96 |
101 |
95 | 100 | |||||||||||
| Gas (MMcf/d) | |||||||||||||||
| U.S. |
1,160 |
1,190 |
1,160 | 1,200 | |||||||||||
| Heavy Oil | 13 | 15 | 14 | 16 | |||||||||||
| Total |
1,173 |
1,205 |
1,174 | 1,216 | |||||||||||
| Oil equivalent (MBoe/d) | |||||||||||||||
| U.S. |
407 |
421 |
407 | 423 | |||||||||||
| Heavy Oil | 119 | 125 | 132 | 138 | |||||||||||
| Total |
526 |
546 |
539 | 561 | |||||||||||
| PRICE REALIZATIONS GUIDANCE | ||||||||||||||||||||||||
| Quarter 3 | Full Year | |||||||||||||||||||||||
| Low | High | Low | High | |||||||||||||||||||||
| Oil and bitumen - % of WTI | ||||||||||||||||||||||||
| U.S. | 88 | % | 98 | % | 88 | % | 98 | % | ||||||||||||||||
| Canada | 58 | % | 68 | % | 53 | % | 63 | % | ||||||||||||||||
| NGL - realized price | $ | 12 | $ | 15 | $ | 13 | $ | 16 | ||||||||||||||||
| Natural gas - % of Henry Hub | 75 | % | 85 | % | 76 | % | 86 | % | ||||||||||||||||
| DEVON ENERGY CORPORATION | ||||||||||||||||||||||||
| FORWARD LOOKING GUIDANCE | ||||||||||||||||||||||||
| OTHER GUIDANCE ITEMS | ||||||||||||||||||||||||
| Quarter 3 | Full Year | |||||||||||||||||||||||
| ($ millions, except %) | Low | High | Low | High | ||||||||||||||||||||
| Marketing & midstream operating profit | $ | 225 | $ | 245 | $ | 900 | $ | 950 | ||||||||||||||||
| Lease operating expenses | $ |
360 |
$ |
410 |
$ | 1,500 | $ | 1,600 | ||||||||||||||||
| General & administrative expenses | $ | 150 | $ | 170 | $ | 630 | $ | 690 | ||||||||||||||||
| Production and property taxes | $ | 65 | $ | 75 | $ | 275 | $ | 325 | ||||||||||||||||
| Depreciation, depletion and amortization | $ | 375 | $ | 425 | $ | 1,550 | $ | 1,650 | ||||||||||||||||
| Other operating items | $ | 10 | $ | 20 | $ | 40 | $ | 50 | ||||||||||||||||
| Net financing costs | $ | 125 | $ | 135 | $ | 485 | $ | 535 | ||||||||||||||||
| Current income tax rate | 5.0 | % | 15.0 | % | 5.0 | % | 10.0 | % | ||||||||||||||||
| Deferred income tax rate | 20.0 | % | 30.0 | % | 20.0 | % | 30.0 | % | ||||||||||||||||
| Total income tax rate | 25.0 | % | 45.0 | % | 25.0 | % | 40.0 | % | ||||||||||||||||
| Net earnings attributable to noncontrolling interests | $ | 10 | $ | 20 | $ | 50 | $ | 100 | ||||||||||||||||
| CAPITAL EXPENDITURES GUIDANCE | ||||||||||||||||||||
| Quarter 3 | Full Year | |||||||||||||||||||
| (in millions) | Low | High | Low | High | ||||||||||||||||
| Exploration and production | $ | 550 | $ | 600 | $ | 1,900 | $ | 2,200 | ||||||||||||
| Capitalized G&A | 55 | 65 | 200 | 250 | ||||||||||||||||
| Capitalized interest | 15 | 20 | 60 | 90 | ||||||||||||||||
| Other | 10 | 20 | 25 | 50 | ||||||||||||||||
| Devon capital expenditures (1) | $ | 630 | $ | 705 | $ | 2,185 | $ | 2,590 | ||||||||||||
| (1) Excludes capital expenditures related to EnLink. | ||||||||||||||||||||
| DEVON ENERGY CORPORATION | |||||||||||||||||||||||
| FORWARD LOOKING GUIDANCE | |||||||||||||||||||||||
| Oil Commodity Hedges | |||||||||||||||||||||||
| Price Swaps | Price Collars | ||||||||||||||||||||||
| Period | Volume (Bbls/d) |
Weighted
Price |
Volume |
Weighted |
Weighted |
||||||||||||||||||
| Q3-Q4 2017 | 78,914 | $ | 54.00 | 69,750 | $ | 45.59 | $ | 57.75 | |||||||||||||||
| Q1-Q4 2018 | 15,292 | $ | 51.19 | 22,421 | $ | 45.96 | $ | 55.96 | |||||||||||||||
| Oil Basis Swaps | ||||||||||||||
| Period | Index | Volume (Bbls/d) |
Weighted Average Differential to |
|||||||||||
| Q3-Q4 2017 | Western Canadian Select | 85,114 | $ | (14.46 | ) | |||||||||
| Q1-Q4 2018 | Western Canadian Select | 48,036 | $ | (15.04 | ) | |||||||||
| Q3-Q4 2017 | Midland Sweet | 20,000 | $ | (0.41 | ) | |||||||||
| Natural Gas Commodity Hedges | |||||||||||||||||||||||
| Price Swaps | Price Collars | ||||||||||||||||||||||
| Period |
Volume |
Weighted |
Volume |
Weighted |
Weighted |
||||||||||||||||||
| Q3-Q4 2017 | 237,500 | $ | 3.24 | 437,500 | $ | 3.03 | $ | 3.42 | |||||||||||||||
| Q1-Q4 2018 | 120,107 | $ | 3.13 | 87,070 | $ | 3.09 | $ | 3.41 | |||||||||||||||
Devon’s oil derivatives settle against the average of the prompt month NYMEX West Texas Intermediate futures price. Devon’s natural gas derivatives settle against the Inside FERC first of the month Henry Hub index. Commodity hedge positions are shown as of July 27, 2017.
