Devon Energy Reports Second-Quarter 2016 Results
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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
“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
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
In
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
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
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
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
The Company now anticipates G&A expenses to decline to a range of
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
As previously announced in June, Devon expects its full-year 2016
upstream capital program to range between
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
Subsequent to quarter end, the Company announced an agreement to sell
its 50 percent interest in the Access Pipeline for CAD
Significant Liquidity and Financial Strength
Devon exited the second quarter with
The Company’s consolidated debt was
Cash Inflow Exceeds
In the second quarter of 2016 Devon had a reported net loss of
Adjusted earnings before interest, taxes, depreciation and amortization
(EBITDA) reached
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
Forward-Looking Statements
This press release includes "forward-looking statements" as defined
by the
The
About
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 | ) |
OTHER KEY STATISTICS | |||||||||||||||||||||||
(in millions) | Quarter Ended June 30, 2016 | ||||||||||||||||||||||
Devon U.S. |
EnLink | Eliminations | Total | ||||||||||||||||||||
Cash flow statement related items: | |||||||||||||||||||||||
Operating cash flow | $ | 225 | $ | 110 | $ | — | $ | 335 | |||||||||||||||
Capital expenditures | $ | (336 | ) | $ | (153 | ) | $ | — |
$ |
(489 |
) |
||||||||||||
Acquisitions of property, equipment and businesses | $ | (17 | ) | $ | 6 | $ | — |
$ |
(11 |
) |
|||||||||||||
EnLink distributions received (paid) | $ | 66 | $ | (140 | ) | $ | — |
$ |
(74 |
) |
|||||||||||||
Issuance of subsidiary units | $ | — | $ | 49 | $ | — | $ | 49 | |||||||||||||||
Balance sheet statement items: | |||||||||||||||||||||||
Net debt (1) |
$ | 7,630 | $ | 3,354 | $ | — | $ | 10,984 |
(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, 2016 | Six Months Ended June 30, 2016 | |||||||||
Exploration and development capital | $ | 221 | $ | 584 | ||||||
Capitalized G&A and interest | 73 | 160 | ||||||||
Acquisitions | 12 | 1,530 | ||||||||
Other | 7 | 13 | ||||||||
Devon capital expenditures (1) | $ | 313 | $ | 2,287 |
(1) Excludes $139 million and $684 million attributable to EnLink for the second quarter and first six months of 2016, respectively. |
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 2016 earnings.
(in millions, except per share amounts) | Quarter Ended June 30, 2016 | |||||||||||||||||||||||
Before-tax | After-tax |
After |
Per Share | |||||||||||||||||||||
Loss attributable to Devon (GAAP) | $ | (1,745 | ) | $ | (1,563 | ) | $ | (1,570 | ) | $ | (3.04 | ) | ||||||||||||
Adjustments: | ||||||||||||||||||||||||
Fair value changes in financial instruments and foreign currency | 205 | 134 | 130 | 0.25 | ||||||||||||||||||||
Restructuring and transaction costs | 24 | 16 | 16 | 0.03 | ||||||||||||||||||||
Deferred tax asset valuation allowance | — | 467 | 467 | 0.91 | ||||||||||||||||||||
Asset impairments | 1,497 | 990 | 990 | 1.91 | ||||||||||||||||||||
Core earnings (loss) attributable to Devon (Non-GAAP) | $ | (19 | ) | $ | 44 | $ | 33 | $ | 0.06 | |||||||||||||||
ADJUSTED EBITDA
We define Adjusted EBITDA, a non-GAAP financial measure, as EBITDA adjusted for certain items presented in the accompanying reconciliation. We believe that EBITDA is widely used by investors to measure a company’s performance without regard to items such as interest expense, taxes, depreciation and amortization, which can vary substantially from company to company depending upon accounting methods and book value of assets, capital structure and the method by which assets were acquired. In addition, Adjusted EBITDA generally excludes certain other items that management believes affect the comparability of operating results or are not related to Devon’s ongoing operations. Management uses Adjusted EBITDA to evaluate the company’s operational trends and performance relative to other oil and gas companies.
(in millions) | Quarter Ended June 30, 2016 | |||||
Net loss (GAAP) | $ | (1,563 | ) | |||
Net financing costs | 163 | |||||
Income taxes | (182 | ) | ||||
Depreciation, depletion and amortization and impairments | 1,981 | |||||
Asset retirement obligation accretion | 21 | |||||
EBITDA | 420 | |||||
Restructuring and transaction costs | 24 | |||||
Fair value changes in financial instruments and foreign currency | 205 | |||||
Adjusted EBITDA (Non-GAAP) | $ | 649 | ||||
NET DEBT AND ADJUSTED 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. Adjusted net debt is net debt further adjusted for the estimated proceeds Devon expects to receive from the asset divestitures that have closed or will close in the third quarter of 2016. Devon believes that netting these sources of cash, including the estimated asset sale proceeds, 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, 2016 | |||||||||||||||||
Devon U.S. & Canada | EnLink | Devon Consolidated | ||||||||||||||||
Total debt (GAAP) | $ | 9,343 | $ | 3,364 | $ | 12,707 | ||||||||||||
Less cash and cash equivalents | (1,713 | ) | (10 | ) | (1,723 | ) | ||||||||||||
Net debt (non-GAAP) | 7,630 | 3,354 | 10,984 | |||||||||||||||
Proceeds from assets sales | (2,932 | ) | — | (2,932 | ) | |||||||||||||
Adjusted net debt (Non-GAAP) | $ | 4,698 | $ | 3,354 | $ | 8,052 |
DEVON ENERGY CORPORATION | ||||||||||||||||
FORWARD LOOKING GUIDANCE | ||||||||||||||||
PRODUCTION GUIDANCE | Quarter 3 | Full Year | ||||||||||||||
Low | High | Low | High | |||||||||||||
Oil and bitumen (MBbls/d) | ||||||||||||||||
U. S. | 106 | 111 | 117 | 122 | ||||||||||||
Heavy Oil | 131 | 136 | 126 | 131 | ||||||||||||
Retained assets | 237 | 247 | 243 | 253 | ||||||||||||
Divested assets | 3 | 7 | 8 | 10 | ||||||||||||
Total | 240 | 254 | 251 | 263 | ||||||||||||
Natural gas liquids (MBbls/d) | ||||||||||||||||
U. S. | 101 | 105 | 105 | 109 | ||||||||||||
Divested assets | 5 | 10 | 12 | 14 | ||||||||||||
Total | 106 | 115 | 117 | 123 | ||||||||||||
Gas (MMcf/d) | ||||||||||||||||
U. S. | 1,200 | 1,230 | 1,245 | 1,275 | ||||||||||||
Heavy Oil | 14 | 18 | 15 | 20 | ||||||||||||
Retained assets | 1,214 | 1,248 | 1,260 | 1,295 | ||||||||||||
Divested assets | 70 | 80 | 120 | 125 | ||||||||||||
Total | 1,284 | 1,328 | 1,380 | 1,420 | ||||||||||||
Oil equivalent (MBoe/d) | ||||||||||||||||
U. S. | 407 | 421 | 430 | 444 | ||||||||||||
Heavy Oil | 133 | 139 | 128 | 134 | ||||||||||||
Retained assets | 540 | 560 | 558 | 578 | ||||||||||||
Divested assets | 20 | 30 | 40 | 45 | ||||||||||||
Total | 560 | 590 | 598 | 623 |
PRICE REALIZATIONS GUIDANCE | Quarter 3 | Full Year | ||||||||||||||||||||||
Low | High | Low | High | |||||||||||||||||||||
Oil and bitumen - % of WTI | ||||||||||||||||||||||||
U. S. | 86 | % | 96 | % | 83 | % | 93 | % | ||||||||||||||||
Canada | 47 | % | 57 | % | 38 | % | 48 | % | ||||||||||||||||
NGL - realized price | $ | 8 | $ | 12 | $ | 8 | $ | 12 | ||||||||||||||||
Natural gas - % of Henry Hub | 78 | % | 88 | % | 73 | % | 83 | % |
OTHER GUIDANCE ITEMS | Quarter 3 | Full Year | ||||||||||||||||||||||
($ millions, except %) | Low | High | Low | High | ||||||||||||||||||||
Marketing & midstream operating profit | $ | 200 | $ | 220 | $ | 825 | $ | 875 | ||||||||||||||||
Lease operating expenses | $ | 380 | $ | 420 | $ | 1,600 | $ | 1,700 | ||||||||||||||||
General & administrative expenses | $ | 135 | $ | 155 | $ | 600 | $ | 650 | ||||||||||||||||
Production and property taxes | $ | 70 | $ | 80 | $ | 285 | $ | 315 | ||||||||||||||||
Depreciation, depletion and amortization | $ | 425 | $ | 475 | $ | 1,900 | $ | 2,100 | ||||||||||||||||
Other operating items | $ | 15 | $ | 20 | $ | 50 | $ | 75 | ||||||||||||||||
Net financing costs (1) | $ | 160 | $ | 170 | $ | 650 | $ | 700 | ||||||||||||||||
Current income tax rate | 0.0 | % | 0.0 | % | 0.0 | % | 0.0 | % | ||||||||||||||||
Deferred income tax rate | 35.0 | % | 45.0 | % | 35.0 | % | 45.0 | % | ||||||||||||||||
Total income tax rate | 35.0 | % | 45.0 | % | 35.0 | % | 45.0 | % | ||||||||||||||||
Net earnings attributable to noncontrolling interests | $ | — | $ | — | $ | — | $ | — |
(1) Full year 2016 includes $50 million of non-cash accretion on EnLink’s installment purchase obligations. |
CAPITAL EXPENDITURES GUIDANCE | Quarter 3 | Full Year | ||||||||||||||||||
(in millions) | Low | High | Low | High | ||||||||||||||||
Exploration and development | $ | 275 | $ | 325 | $ | 1,100 | $ | 1,300 | ||||||||||||
Capitalized G&A | 50 | 60 | 200 | 250 | ||||||||||||||||
Capitalized interest | 10 | 20 | 40 | 50 | ||||||||||||||||
Other | 5 | 15 | 30 | 45 | ||||||||||||||||
Devon capital expenditures (2) | $ | 340 | $ | 420 | $ | 1,370 | $ | 1,645 |
(2) Excludes capital expenditures related to EnLink. |
COMMODITY HEDGES | ||||||||||||||||||||||||||||||||
Oil Commodity Hedges | ||||||||||||||||||||||||||||||||
Price Swaps | Price Collars | Call Options Sold | ||||||||||||||||||||||||||||||
Period |
Volume |
Weighted |
Volume |
Weighted |
Weighted |
Volume |
Weighted |
|||||||||||||||||||||||||
Q3-2016 | 33,000 | $ | 48.37 | 65,000 | $ | 40.37 | $ | 46.91 | 18,500 | $ | 55.00 | |||||||||||||||||||||
Q4-2016 | 30,000 | $ | 48.58 | 20,000 | $ | 40.85 | $ | 50.85 | 18,500 | $ | 55.00 | |||||||||||||||||||||
Q1-Q4 2017 | 6,470 | $ | 51.24 | 10,115 | $ | 46.44 | $ | 56.44 | - | - |
Oil Basis Swaps | |||||||||||||
Period | Index | Volume (Bbls/d) |
Weighted Average Differential to |
||||||||||
Q3-2016 | Western Canadian Select | 50,000 | (13.45 | ) | |||||||||
Q4-2016 | Western Canadian Select | 33,000 | (13.40 | ) |
Natural Gas Commodity Hedges | ||||||||||||||||||||||||||||||||
Price Swaps | Price Collars | Call Options Sold | ||||||||||||||||||||||||||||||
Period |
Volume |
Weighted |
Volume |
Weighted |
Weighted |
Volume |
Weighted |
|||||||||||||||||||||||||
Q3-2016 | 140,000 | $ | 2.78 | 105,000 | $ | 2.57 | $ | 2.85 | 400,000 | $ | 2.80 | |||||||||||||||||||||
Q4-2016 | 155,000 | $ | 2.83 | 305,000 | $ | 2.71 | $ | 2.92 | 400,000 | $ | 2.80 | |||||||||||||||||||||
Q1-Q4 2017 | 99,329 | $ | 3.03 | 62,315 | $ | 3.01 | $ | 3.31 | - | - | ||||||||||||||||||||||
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
View source version on businesswire.com: http://www.businesswire.com/news/home/20160802006880/en/
Source:
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