Devon Energy Corp. (NYSE: DVN) today reported operational and
financial results for the fourth quarter and full-year 2016. Also
included within the release is the company’s guidance outlook for
the first quarter and full-year 2017.
Highlights
- Exceeded fourth-quarter production
expectations
- Achieved record-setting well
productivity in 2016
- Reduced operating expenses in U.S. by
42 percent from peak rates
- Attained $1.3 billion in annual cost
savings
- Delivered proved reserves growth at
attractive finding costs
- Improved growth outlook driven by
accelerated capital investment
“For Devon, 2016 was a transformational year,” said Dave Hager,
president and CEO. “We successfully reshaped our asset portfolio to
focus on our top two franchise assets, the STACK and Delaware
Basin, providing us a sustainable, multi-decade growth platform.
With these world-class assets, we delivered outstanding operational
performance throughout the year. Our drilling programs generated
the best well productivity in Devon’s 45-year history and we
maximized the value of every barrel produced with cost-reduction
efforts that reached $1.3 billion of annual savings.”
“We also took important steps during the year to strengthen our
investment-grade financial position with the timely completion of
our $3.2 billion asset divestiture program,” Hager said. “These
accretive transactions provided us with the financial capacity to
further accelerate investment across our best-in-class U.S.
resource plays in 2017 and beyond. This increased drilling activity
will continue to rapidly shift our production mix to higher-margin
products, positioning us to deliver peer-leading cash flow
expansion at today’s market prices.”
Fourth-Quarter Production Exceeds Midpoint Guidance
Devon’s reported oil production averaged 244,000 barrels per day
in the fourth quarter of 2016. With the shift to higher-margin
production, oil accounted for the largest component of the
company’s product mix at 45 percent of total volumes.
Total companywide production in the fourth quarter reached
537,000 oil-equivalent barrels (Boe) per day, exceeding the
midpoint of guidance by 2,000 Boe per day. In an effort to maximize
profitability, Devon chose to reject approximately 12,000 barrels
per day of ethane in the fourth quarter.
Record-Setting Well Productivity in U.S. Resource
Plays
The majority of the company’s production was attributable to its
U.S. resource plays, which averaged 396,000 Boe per day during the
fourth quarter. Production within the U.S. during 2016 benefited
from drilling activity that achieved the best new well productivity
in Devon’s 45-year history. Led by results from the STACK, Delaware
Basin and Eagle Ford assets, the company’s initial 90-day
production rates in the U.S. increased for the fourth consecutive
year, advancing more than 300 percent from 2012.
The substantial improvement in well productivity was driven by
activity focused in top resource plays, improved subsurface
reservoir characterization, leading-edge completion designs and
improvements in lateral placement.
In Canada, Devon’s heavy-oil operations also delivered
impressive results with net oil production averaging 139,000
barrels per day in the fourth quarter. Driven by the
industry-leading performance of the Jackfish complex, Canadian oil
production increased 14 percent compared to the fourth quarter of
2015.
Reserve Report Highlights Operational Excellence
Devon’s estimated proved reserves were 2.1 billion Boe on Dec.
31, 2016, a 3 percent increase compared to the company’s retained
asset portfolio in 2015. Proved developed reserves accounted for 80
percent of the total. At year-end, higher-margin, liquids reserves
totaled 1.1 billion Boe, or approximately 55 percent of total
reserves.
The most significant reserve growth came from the company’s U.S.
operations where proved reserves increased 7 percent to 1.6 billion
Boe. Devon’s capital programs within the U.S. added 275 million Boe
of reserves (extensions, discoveries and performance revisions)
during 2016. This represents a replacement rate of approximately
175 percent (on a retained asset basis). Excluding property
acquisition costs, these reserves were added at a finding cost of
only $5 per Boe added during the year. These attractive reserve
results in the U.S. were driven by new-well activity that achieved
record-setting productivity, a materially improved operating cost
structure and successful base production initiatives.
In Canada, the company’s heavy oil reserves amounted to 504
million Boe at year end. Beyond proved reserves, tremendous upside
exists with Devon’s top-tier Canadian assets, with more than 1.4
billion Boe of risked resource.
Lease Operating Costs Improve by 42 Percent in U.S. Resource
Plays
Devon continued to make progress lowering operating costs in the
fourth quarter. Lease operating expenses (LOE) totaled $367 million
for the quarter and were 4 percent below the midpoint of guidance.
The $1.1 billion sale of Access Pipeline in Canada added $28
million of incremental LOE during the quarter. The strong
fourth-quarter result was driven by the company’s U.S. asset
portfolio, where LOE costs improved by 42 percent from peak rates
in early 2015. The decrease in LOE was primarily driven by improved
power and water-handling infrastructure, reduced labor expense and
lower supply chain costs.
The company also maintained its significantly improved general
and administrative (G&A) cost structure in the fourth quarter.
Including capitalized costs, G&A expenses totaled $224 million,
a nearly 40 percent improvement compared to peak costs in late
2014. The significantly lower overhead costs were driven by lower
personnel expenses.
Cost Savings Reach $1.3 Billion in 2016
In aggregate, Devon’s cost-savings initiatives achieved $1.3
billion of operating and G&A expense reductions in 2016
compared to peak levels in 2014.
The company expects these cost savings to be sustainable in 2017
due to structural improvements and efficiency gains within its
field operations and corporate support groups.
EnLink Positioned to Deliver Double-Digit Growth in
2017
Devon’s midstream business generated $212 million of operating
profit in the fourth quarter, driven entirely by the company’s
strategic investment in EnLink Midstream. For the full-year 2016,
EnLink-related operating profit expanded to $879 million, a 6
percent improvement compared to 2015.
In 2017, with strong growth expected from EnLink, Devon projects
its midstream operating profits will advance to a range of $900
million to $950 million. Based on the midpoint of guidance, this
estimate represents approximately a 10 percent increase compared to
2016. EnLink’s growth is derived from an asset base that is
positioned in some of the most attractive markets in North America,
including the STACK, Midland Basin, Delaware Basin and an NGL
business that services end-user demand along the Gulf Coast.
Devon has a 64 percent ownership in EnLink’s general partner
(NYSE: ENLC) and a 24 percent interest in the limited partner
(NYSE: ENLK). In aggregate, the company’s ownership in EnLink has a
market value of approximately $4 billion and is expected to
generate cash distributions of around $270 million annually.
Fourth-Quarter 2016 Operations Report
For additional details on Devon’s E&P operations, please
refer to the company’s fourth-quarter 2016 operations report at
www.devonenergy.com. Highlights from the report include:
- Meramec drilling inventory increases by
40 percent
- Leonard Shale and Delaware Sands
resource potential expands
- Staggered spacing tests successful in
Eagle Ford
- Jackfish complex delivers record
production
- Barnett cash flow generation
accelerates
Divestitures and Hedging Position Enhance Strong Financial
Position
On Oct. 6, 2016, the company closed on the sale of its 50
percent interest in the Access Pipeline for USD $1.1 billion. This
accretive transaction officially completed Devon’s $3.2 billion
non-core asset divestiture program.
The majority of divestiture proceeds were utilized to retire
$2.5 billion of debt through tender offerings and repayments in the
second half of 2016. As a result of the debt-reduction efforts, the
company expects its recurring, go-forward financing costs to
decline by around $120 million annually, with no significant debt
maturities until mid-2021. Devon exited the fourth quarter with
investment-grade credit ratings and significant liquidity, which
consisted of $2 billion of cash on hand and an undrawn credit
facility of $3 billion.
In addition to an investment-grade balance sheet, Devon’s
financial position is bolstered by a significantly increased
commodity hedging position in 2017. The company currently has
approximately 50 percent of its estimated oil and gas production
hedged in the upcoming year and will continue to build out its
hedging position in the future.
Earnings Beat Wall Street Consensus by 20 Percent
Devon’s reported net earnings totaled $331 million or $0.63 per
diluted share in the fourth quarter. Adjusting for items securities
analysts typically exclude from their published estimates, the
company’s core earnings were $131 million or $0.25 per diluted
share in the fourth quarter. This strong earnings result exceeded
analyst consensus estimates by 20 percent.
The company’s significantly improved profitability in the fourth
quarter was attributable to higher commodity prices and an improved
cost structure. These factors also strengthened Devon’s operating
cash flow to $536 million in the fourth quarter. Combined with
proceeds received from asset sales, the company’s total cash
inflows for the quarter reached $1.8 billion.
Devon Positioned to Deliver Peer-Leading Cash Flow
Expansion
Detailed forward-looking guidance for the first quarter and
full-year 2017 is provided later in the release. In 2017, Devon
expects to further accelerate activity in its U.S. resource plays
to as many as 20 operated rigs by year end. With this level of
planned activity, the company expects to invest between $2.0
billion and $2.3 billion of E&P capital in 2017, with nearly 90
percent of the capital devoted to U.S. resource plays.
Devon’s upstream capital plans are expected to drive 13 to 17
percent oil production growth in the U.S. during 2017 compared to
the fourth quarter of 2016, which marks the low point of Devon’s
production profile. This resumption of growth in high-margin
production will begin in the first quarter of 2017. The operational
momentum created by accelerated drilling activity in the STACK and
Delaware Basin in the upcoming year is expected to advance
light-oil production in the U.S. by approximately 20 percent in
2018 compared to 2017. This rapid growth in high-margin production,
combined with a significantly improved cost structure, positions
Devon to deliver peer-leading cash flow expansion at today’s market
prices.
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.
Finding cost, 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 fourth-quarter conference call will be held at 10 a.m.
Central (11 a.m. Eastern) on Wednesday, Feb. 15, 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
Quarter Ended Year Ended PRODUCTION NET OF
ROYALTIES December 31, December 31, 2016
2015 2016
2015
Oil and bitumen (MBbls/d) U. S. - Core 105 139 119 142 Heavy
Oil 139 121 131 111 Retained assets 244 260 250 253 Divested assets
— 18 10 22 Total 244 278 260 275
Natural gas liquids
(MBbls/d) U. S. - Core 90 115 103 110 Divested assets — 24 13
26 Total 90 139 116 136
Gas (MMcf/d) U. S. - Core 1,203
1,327 1,270 1,333 Heavy Oil 18 24 20 22 Retained assets 1,221 1,351
1,290 1,355 Divested assets — 232 123 255 Total 1,221 1,583 1,413
1,610
Oil equivalent (MBoe/d) U. S. - Core 396 475 434 474
Heavy Oil 141 126 134 115 Retained assets 537 601 568 589 Divested
assets — 80 43 91 Total 537 681 611 680
KEY
OPERATING STATISTICS BY REGION Quarter
Ended December 31, 2016 Avg. Production
Gross Wells Operated Rigs at (MBoe/d)
Drilled December 31, 2016 STACK 88 55 6 Delaware
Basin 54 15 3 Eagle Ford 60 29 — Heavy Oil 141 12 3 Barnett Shale
163 — — Rockies Oil 15 11 1 Other assets 16 11 — Total 537 133 13
Year Ended December 31, 2016
Avg. Production Gross Wells (MBoe/d)
Drilled STACK 93 133 Delaware Basin 60 58 Eagle Ford 76 63
Heavy Oil 134 25 Barnett Shale 169 — Rockies Oil 19 19 Other assets
17 28 Retained assets 568 326 Divested assets 43 14 Total 611 340
PRODUCTION TREND
2015 2016 Quarter 4 Quarter 1
Quarter 2 Quarter
3 Quarter 4 Oil and bitumen
(MBbls/d) STACK 9 15 19 21 19 Delaware Basin 42 38 36 31 29
Eagle Ford 60 59 41 33 34 Heavy Oil 121 126 121 137 139 Barnett
Shale 1 1 1 1 1 Rockies Oil 15 17 15 11 11 Other assets 12 12 11 11
11 Retained assets 260 268 244 245 244 Divested assets 18 17 15 6 —
Total 278 285 259 251 244
Natural gas liquids (MBbls/d)
STACK 24 30 30 23 21 Delaware Basin 11 12 13 12 10 Eagle Ford 27 24
17 13 11 Barnett Shale 49 46 46 44 43 Rockies Oil 1 1 1 1 1 Other
assets 3 2 3 3 4 Retained assets 115 115 110 96 90 Divested assets
24 22 21 8 — Total 139 137 131 104 90
Gas (MMcf/d) STACK 253
306 289 292 284 Delaware Basin 82 84 99 92 89 Eagle Ford 152 144
103 85 90 Heavy Oil 24 15 28 18 18 Barnett Shale 786 768 757 730
710 Rockies Oil 38 32 31 19 17 Other assets 16 17 14 13 13 Retained
assets 1,351 1,366 1,321 1,249 1,221 Divested assets 232 215 206 75
— Total 1,583 1,581 1,527 1,324 1,221
Oil equivalent
(MBoe/d) STACK 75 96 97 92 88 Delaware Basin 66 63 65 59 54
Eagle Ford 113 107 76 61 60 Heavy Oil 126 129 126 140 141 Barnett
Shale 181 175 173 166 163 Rockies Oil 23 23 21 16 15 Other assets
17 18 16 16 16 Retained assets 601 611 574 550 537 Divested assets
80 74 70 27 — Total 681 685 644 577 537
BENCHMARK PRICES (average prices)
Quarter 4
December YTD 2016 2015
2016 2015 Oil
($/Bbl) - West Texas Intermediate (Cushing) $ 49.21 $ 42.15 $ 43.36
$ 48.87 Natural Gas ($/Mcf) - Henry Hub $ 2.98 $ 2.27 $ 2.46 $ 2.67
REALIZED PRICES Quarter Ended December 31,
2016 Oil /Bitumen NGL Gas Total
(Per Bbl) (Per Bbl) (Per Mcf) (Per
Boe) United States $ 46.74 $ 13.81 $ 2.37 $ 22.78 Canada $
25.90 N/M N/M $ 25.39
Realized price without hedges $ 34.90 $ 13.81 $ 2.34 $ 23.47 Cash
settlements $ — $ (0.31 ) $ (0.11 ) $ (0.30 ) Realized
price, including cash settlements $ 34.90 $ 13.50 $
2.23 $ 23.17
Quarter Ended December 31,
2015 Oil /Bitumen NGL Gas Total
(Per Bbl) (Per Bbl) (Per Mcf) (Per
Boe) United States $ 38.04 $ 8.81 $ 1.76 $ 17.90 Canada $ 18.03
N/M
N/M
$ 17.62 Realized price without hedges $ 29.31 $ 8.81
$ 1.75 $ 17.85 Cash settlements $ 24.36 $ — $ 0.70
$ 11.59 Realized price, including cash settlements $
53.67 $ 8.81 $ 2.45 $ 29.44
Year Ended December 31, 2016 Oil /Bitumen NGL
Gas Total (Per Bbl) (Per Bbl) (Per
Mcf) (Per Boe) United States $ 38.92 $ 9.81 $
1.84 $ 18.34 Canada $ 20.53 N/M N/M
$ 20.07 Realized price without hedges $ 29.65 $ 9.81
$ 1.84 $ 18.72 Cash settlements $ (0.43 ) $ (0.11 ) $ 0.07 $
(0.05 ) Realized price, including cash settlements $ 29.22 $
9.70 $ 1.91 $ 18.67
Year Ended
December 31, 2015 Oil /Bitumen NGL Gas
Total (Per Bbl) (Per Bbl) (Per Mcf)
(Per Boe) United States $ 44.01 $ 9.32 $ 2.17
$ 21.12 Canada $ 25.14 N/M
N/M
$ 24.46 Realized price without hedges $ 36.39 $ 9.32
$ 2.14 $ 21.68 Cash settlements $ 20.72 $ — $ 0.57
$ 9.74 Realized price, including cash settlements $
57.11 $ 9.32 $ 2.71 $ 31.42
CONSOLIDATED STATEMENTS OF EARNINGS (in
millions, except per share amounts)
Quarter Ended Year
Ended December 31, December 31,
2016 2015 2016
2015 Oil, gas and NGL sales $ 1,159 $
1,118 $ 4,182 $ 5,382 Oil, gas and NGL derivatives (171 ) 77 (201 )
503 Marketing and midstream revenues 1,820 1,691 6,323 7,260 Asset
dispositions and other 542 —
1,893 — Total revenues and other 3,350
2,886 12,197 13,145
Lease operating expenses 367 479 1,582 2,104 Marketing and
midstream operating expenses 1,608 1,481 5,492 6,420 General and
administrative expenses 163 194 645 855 Production and property
taxes 55 73 275 388 Depreciation, depletion and amortization 372
641 1,792 3,129 Asset impairments 124 5,341 4,975 20,820
Restructuring and transaction costs 1 78 267 78 Other operating
items 23 24 64 78
Total operating expenses 2,713 8,311
15,092 33,872 Operating income
(loss) 637 (5,425 ) (2,895 ) (20,727 ) Net financing costs 334 139
904 517 Other nonoperating items (72 ) (22 )
78 24 Earnings (loss) before income taxes 375
(5,542 ) (3,877 ) (21,268 ) Income tax expense (benefit) 55
(630 ) (173 ) (6,065 ) Net earnings
(loss) 320 (4,912 ) (3,704 ) (15,203 ) Net earnings (loss)
attributable to noncontrolling interests (11 ) (380 )
(402 ) (749 ) Net earnings (loss) attributable to
Devon $ 331 $ (4,532 ) $ (3,302 ) $ (14,454 ) Net earnings
(loss) per share attributable to Devon: Basic $ 0.63 $ (11.12 ) $
(6.52 ) $ (35.55 ) Diluted $ 0.63 $ (11.12 ) $ (6.52 ) $ (35.55 )
Weighted average common shares outstanding: Basic 524 413
513 412 Diluted 527 413 513 412
CONSOLIDATED
STATEMENTS OF CASH FLOWS (in millions)
Quarter Ended
Year Ended December 31, December 31,
2016 2015 2016
2015 Cash flows from operating
activities: Net earnings (loss) $ 320 $ (4,912 ) $ (3,704 ) $
(15,203 ) Adjustments to reconcile net earnings (loss) to net cash
from operating activities:
Depreciation, depletion and amortization 372 641 1,792 3,129 Asset
impairments 124 5,341 4,975 20,820 Gains and losses on asset sales
(536 ) — (1,887 ) — Deferred income tax expense (benefit) 27 (480 )
(273 ) (5,828 ) Derivatives and other financial instruments 27 (132
) 386 (738 ) Cash settlements on derivatives and financial
instruments (9 ) 775 (142 ) 2,688 Asset retirement obligation
accretion 17 19 75 75 Amortization of stock-based compensation 31
44 194 181 Other 334 37 303 281 Net change in working capital (189
) (404 ) (8 ) (311 ) Change in long-term other assets 26 74 36 285
Change in long-term other liabilities (8 ) 68
(1 ) (6 ) Net cash from operating activities
536 1,071 1,746 5,373
Cash flows from investing activities: Capital expenditures
(671 ) (1,079 ) (2,330 ) (5,308 ) Acquisitions of property,
equipment and businesses — (577 ) (1,641 ) (1,107 ) Divestitures of
property and equipment 1,229 72 3,118 107 Other (26 )
(8 ) (19 ) (16 ) Net cash from investing activities
532 (1,592 ) (872 ) (6,324 )
Cash flows from financing activities: Borrowings of long-term debt,
net of issuance costs 483 1,444 2,145 4,772 Repayments of long-term
debt (1,687 ) (861 ) (4,409 ) (2,634 ) Net short-term debt
repayments — 625 (626 ) (307 ) Early retirement of debt (183 ) —
(265 ) — Issuance of common stock — — 1,469 — Sale of subsidiary
units — — — 654 Issuance of subsidiary units 57 12 892 25 Dividends
paid on common stock (31 ) (100 ) (221 ) (396 ) Contributions from
noncontrolling interests 17 4 168 16 Distributions to
noncontrolling interests (80 ) (68 ) (304 ) (254 ) Other (4
) — (13 ) (18 ) Net cash from financing
activities (1,428 ) 1,056 (1,164 )
1,858 Effect of exchange rate changes on cash
(66 ) (12 ) (61 ) (77 ) Net change in cash and
cash equivalents (426 ) 523 (351 ) 830 Cash and cash equivalents at
beginning of period 2,385 1,787
2,310 1,480 Cash and cash equivalents at end
of period $ 1,959 $ 2,310 $ 1,959 $ 2,310
CONSOLIDATED
BALANCE SHEETS (in millions)
December 31, December
31, 2016 2015 Current
assets: Cash and cash equivalents $ 1,959 $ 2,310 Accounts
receivable 1,356 1,105 Assets held for sale 193 — Other current
assets 264 606 Total current assets
3,772 4,021 Property and equipment, at
cost: Oil and gas, based on full cost accounting: Subject to
amortization 75,648 78,190 Not subject to amortization 3,437
2,584 Total oil and gas 79,085 80,774
Midstream and other 10,455 10,380 Total
property and equipment, at cost 89,540 91,154 Less accumulated
depreciation, depletion and amortization (73,350 )
(72,086 ) Property and equipment, net 16,190
19,068 Goodwill 3,964 5,032 Other long-term assets
1,987 1,330 Total assets $ 25,913 $
29,451 Current liabilities: Accounts payable $ 642 $
906 Revenues and royalties payable 908 763 Short-term debt — 976
Other current liabilities 1,066 650
Total current liabilities 2,616 3,295
Long-term debt 10,154 12,056 Asset retirement obligations 1,226
1,370 Other long-term liabilities 894 853 Deferred income taxes 648
888 Stockholders’ equity: Common stock 52 42 Additional paid-in
capital 7,237 4,996 Retained earnings (accumulated deficit) (1,646
) 1,781 Accumulated other comprehensive earnings 284
230 Total stockholders’ equity attributable to Devon
5,927 7,049 Noncontrolling interests 4,448
3,940 Total stockholders’ equity 10,375
10,989 Total liabilities and stockholders’ equity $ 25,913
$ 29,451 Common shares outstanding 523 418
CONSOLIDATING STATEMENTS OF OPERATIONS (in
millions)
Quarter Ended December 31, 2016
Devon U.S.& Canada
EnLink Eliminations Total Oil, gas and NGL
sales $ 1,159 $ — $ — $ 1,159 Oil, gas and NGL derivatives (171 ) —
— (171 ) Marketing and midstream revenues 758 1,225 (163 ) 1,820
Asset dispositions and other 558 (16 )
— 542 Total revenues and other 2,304
1,209 (163 ) 3,350 Lease
operating expenses 367 — — 367 Marketing and midstream operating
expenses 769 1,002 (163 ) 1,608 General and administrative expenses
133 30 — 163 Production and property taxes 48 7 — 55 Depreciation,
depletion and amortization 241 131 — 372 Asset impairments 124 — —
124 Restructuring and transaction costs 1 — — 1 Other operating
items 23 — — 23
Total operating expenses 1,706 1,170
(163 ) 2,713 Operating income 598 39 —
637 Net financing costs 284 50 — 334 Other nonoperating items
(92 ) 20 — (72 ) Earnings
(loss) before income taxes 406 (31 ) — 375 Income tax expense
(benefit) 56 (1 ) — 55
Net earnings (loss) 350 (30 ) — 320 Net loss attributable to
noncontrolling interests — (11 ) —
(11 ) Net earnings (loss) attributable to Devon $ 350
$ (19 ) $ — $ 331
OTHER KEY STATISTICS
(in millions)
Quarter Ended December 31, 2016
Devon U.S.& Canada
EnLink Eliminations Total Cash flow
statement related items: Operating cash flow $ 383 $ 153 $ — $
536 Capital expenditures $ (432 ) $ (239 ) $ — $ (671 )
Divestitures of property and equipment $ 1,141 $ 88 $ — $ 1,229
Repayments of long-term debt $ (1,254 ) $ (433 ) $ — $ (1,687 )
EnLink distributions received (paid) $ 66 $ (146 ) $ — $ (80 )
Issuance of subsidiary units $ — $ 57 $ — $ 57
Balance
sheet statement items: Net debt (1) $ 4,911 $ 3,284 $ — $ 8,195
(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 December
31, 2016 Year Ended December 31, 2016 Exploration and
development capital(1) $ 363 $ 1,166 Capitalized G&A and
interest 78 308 Acquisitions 36 1,595 Other 20 40
Devon capital expenditures(2) $ 497 $ 3,109 (1) Exploration
and development capital in this table is presented before
capitalized G&A and interest. The full-year amount excludes a
$95 million positive revision to future asset retirement
obligations, which is included in costs incurred. The fourth
quarter and full-year amounts include $8 million and $32 million
for abandonment expenditures paid during each respective period,
which are not included in costs incurred. (2) Excludes $266
and $1,082 million attributable to EnLink for the fourth quarter
and year end of 2016, respectively.
COSTS
INCURRED Total (in millions)
Year Ended December
31, 2016 2015
Property acquisition costs: Proved properties $ 237 $ 195 Unproved
properties 1,358 717 Exploration costs 394 587 Development costs
1,143 3,671 Costs Incurred $ 3,132 $ 5,170
United States Year Ended December 31,
2016 2015 Property acquisition costs: Proved
properties $ 237 $ 193 Unproved properties 1,356 634 Exploration
costs 345 478 Development costs 1,034 3,269 Costs
Incurred $ 2,972 $ 4,574
Canada Year Ended
December 31, 2016 2015 Property
acquisition costs: Proved properties $ — $ 2 Unproved properties 2
83 Exploration costs 49 109 Development costs 109 402
Costs Incurred $ 160 $ 596
RESERVES
RECONCILIATION Total
Oil / Bitumen(MMBbls)
Gas(Bcf)
NGL(MMBbls)
Total(MMBoe)
As of December 31, 2015: Proved developed 444 5,707 411
1,806 Proved undeveloped 340 114 17 376
Total Proved 784 5,821
428 2,182 Revisions due to prices 3
(103 ) (13 ) (27 ) Revisions other than price (18 ) 638 48 137
Extensions and discoveries 38 280 42 126 Purchase of reserves 8 33
7 20 Production (95 ) (517 ) (42 ) (223 ) Sale of reserves (25 )
(521 ) (45 ) (157 )
As of December 31, 2016: Proved
developed 367 5,377 387 1,649 Proved undeveloped 328 254
38 409
Total Proved 695
5,631 425 2,058
United States
Oil / Bitumen(MMBbls)
Gas(Bcf)
NGL(MMBbls)
Total(MMBoe)
As of December 31, 2015: Proved developed 203 5,694 411
1,563 Proved undeveloped 39 114 17 75
Total Proved 242 5,808
428 1,638 Revisions due to prices (18 )
(103 ) (13 ) (48 ) Revisions other than price (2 ) 628 48 151
Extensions and discoveries 36 280 42 124 Purchase of reserves 8 33
7 20 Production (47 ) (510 ) (42 ) (174 ) Sale of reserves (25 )
(521 ) (45 ) (157 )
As of December 31, 2016: Proved
developed 160 5,361 387 1,439 Proved undeveloped 34 254
38 115
Total Proved 194
5,615 425 1,554
Canada
Oil / Bitumen(MMBbls)
Gas(Bcf)
NGL(MMBbls)
Total(MMBoe)
As of December 31, 2015: Proved developed 241 13 — 243
Proved undeveloped 301 — — 301
Total
Proved 542 13 —
544
Revisions due to prices 21 — — 21 Revisions other than price
(16 ) 10 — (14 ) Extensions and discoveries 2 — — 2 Production (48
) (7 ) — (49 )
As of December 31, 2016: Proved
developed 207 16 — 210 Proved undeveloped 294 — —
294
Total Proved 501 16
—
504
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
fourth-quarter 2016 earnings.
(in millions, except per share amounts)
Quarter Ended December 31, 2016 Before-tax
After-tax
AfterNoncontrollingInterests
Per Share Earnings attributable to
Devon (GAAP) $ 375 $ 320 $ 331 $ 0.63 Adjustments: Gains and losses
on asset sales (539 ) (455 ) (462 ) (0.87 ) Asset impairments 145
107 100 0.19 Deferred tax asset valuation allowance — (16 ) (16 )
(0.03 ) Restructuring and transaction costs 1 1 1 — Fair value
changes in financial instruments and foreign currency 69 62 59 0.11
Early retirement of debt 185 118
118 0.22 Core earnings attributable to Devon
(Non-GAAP) $ 236 $ 137 $ 131 $ 0.25
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)
December 31, 2016
Devon U.S. & Canada EnLink
Devon Consolidated Total debt (GAAP) $
6,859 $ 3,295 $ 10,154 Less cash and cash equivalents (1,948
) (11 ) (1,959 ) Net debt (Non-GAAP) $ 4,911 $
3,284 $ 8,195
FINDING COST
Finding cost is defined as costs incurred less acquisitions
costs. Devon believes finding cost is relevant because it provides
additional insight into costs associated with current year
exploration and development activities. Certain securities analysts
also use this methodology to measure Devon’s performance. It should
be noted that the actual costs of reserves added through Devon’s
drilling program will differ, sometimes significantly, from the
direct comparison of capital spent and reserves added in any given
period due to the timing of capital expenditures and reserves
bookings.
(in millions)
Year Ended December 31,
2016 United States Costs Incurred (GAAP) $ 2,972 Less:
Acquisition costs 1,593 Finding cost (Non-GAAP) $ 1,379
Revisions other than price 151 Extensions and discoveries
124 Total 275 Finding cost per BOE (Non-GAAP)
$ 5.01
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 millions)
Year Ended December 31,
2016 Consolidated cash flow from operations (GAAP) $ 1,746
Less: EnLink cash flow from operations 666 Devon cash flow
from operations 1,080 Less: cash flow from divested assets
150 Less: cash associated with debt repayments 265 Add: EnLink
distributions received 265 Upstream cash flow (Non-GAAP) $
930
DEVON ENERGY CORPORATION
FORWARD-LOOKING GUIDANCE
PRODUCTION GUIDANCE Quarter 1 Full Year
Low High Low
High Oil and bitumen (MBbls/d) U.S. 114
118 119 123 Heavy Oil 133 138 130 135 Total 247 256 249 258
Natural gas liquids (MBbls/d) Total 88 93 95 100
Gas
(MMcf/d) U.S. 1,190 1,220 1,160 1,200 Heavy Oil 14 18 14 16
Total 1,204 1,238 1,174 1,216
Oil equivalent (MBoe/d) U.S.
400 414 407 423 Heavy Oil 135 141 132 138 Total 535 555 539 561
PRICE REALIZATIONS
GUIDANCE Quarter 1 Full Year Low
High Low
High Oil and bitumen - % of WTI U.S. 88 % 98 % 88 % 98 %
Canada 45 % 55 % 48 % 58 % NGL - realized price $ 12 $ 15 $ 12 $ 15
Natural gas - % of Henry Hub 78 % 88 % 78 % 88 %
OTHER GUIDANCE ITEMS Quarter
1 Full Year ($ millions, except %)
Low
High Low
High Marketing & midstream operating profit $ 200 $ 220
$ 900 $ 950 Lease operating expenses $ 350 $ 400 $ 1,500 $ 1,600
General & administrative expenses - Devon $ 130 $ 150 $ 500 $
550 General & administrative expenses - EnLink $ 35 $ 45 $ 130
$ 140 Production and property taxes $ 75 $ 85 $ 275 $ 325
Depreciation, depletion and amortization $ 375 $ 425 $ 1,650 $
1,750 Other operating items $ 15 $ 25 $ 70 $ 80 Net financing costs
$ 125 $ 135 $ 485 $ 535 Current income tax rate 5.0 % 15.0 % 5.0 %
15.0 % Deferred income tax rate 20.0 % 30.0 %
20.0 % 30.0 % Total income tax rate 25.0 %
45.0 % 25.0 % 45.0 % Net earnings attributable
to noncontrolling interests $ — $ 5 $ 50 $ 100
CAPITAL EXPENDITURES GUIDANCE
Quarter 1 Full Year (in millions)
Low
High Low
High Exploration and development $ 450 $ 500 $ 2,000 $ 2,300
Capitalized G&A 55 65 200 250 Capitalized interest 15 20 60 90
Other 5 10 25 50 Devon capital
expenditures (1) $ 525 $ 595 $ 2,285 $ 2,690 (1) Excludes
capital expenditures related to EnLink.
COMMODITY HEDGES Oil Commodity
Hedges Price Swaps Price Collars Period Volume
(Bbls/d)
WeightedAverage Price($/Bbl)
Volume(Bbls/d)
WeightedAverage FloorPrice ($/Bbl)
WeightedAverage CeilingPrice ($/Bbl)
Q1-Q4 2017 73,760 $ 54.33 56,259 $ 45.45 $ 58.11 Q1-Q4 2018 4,096 $
54.31 7,685 $ 47.77 $ 57.77
Oil Basis
Swaps Period Index Volume (Bbls/d)
Weighted Average Differential toWTI
($/Bbl)
Q1-Q4 2017 Western Canadian Select 26,910 $ (15.24 ) Q1-Q4 2017
Midland Sweet 17,534 $ (0.41 )
Natural Gas Commodity
Hedges Price Swaps Price Collars Period
Volume(MMBtu/d)
WeightedAverage Price($/MMBtu)
Volume(MMBtu/d)
WeightedAverage FloorPrice ($/MMBtu)
WeightedAverage CeilingPrice ($/MMBtu)
Q1-Q4 2017 209,863 $ 3.16 360,425 $ 2.99 $ 3.40 Q1-Q4 2018 44,500 $
3.32 33,904 $ 3.29 $ 3.64
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 February
7, 2017.
View source
version on businesswire.com: http://www.businesswire.com/news/home/20170214006351/en/
Devon Energy CorporationInvestor ContactsScott Coody,
405-552-4735Chris Carr, 405-228-2496Media ContactJohn
Porretto, 405-228-7506
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