OKLAHOMA CITY, Feb. 18, 2019 /PRNewswire/ -- Continental Resources, Inc. (NYSE: CLR) (the Company) today announced full-year 2018 and fourth quarter 2018 operating and financial results.
Logo - http://photos.prnewswire.com/prnh/20120327/DA76602LOGO
The Company reported full-year 2018 net income of $988.3 million, or $2.64 per diluted share. The Company's net income includes certain items typically excluded by the investment community in published estimates, the result of which is referred to as "adjusted net income." Typically excluded items in aggregate represented $77.9 million, or $0.20 per diluted share. Adjusted net income for full-year 2018 was $1.07 billion, or $2.84 per diluted share (non-GAAP). Net cash provided by operating activities for full-year 2018 was $3.46 billion and EBITDAX was $3.62 billion (non-GAAP).
The Company reported net income of $197.7 million, or $0.53 per diluted share, for the quarter ended December 31, 2018. In fourth quarter 2018, typically excluded items in aggregate represented $3.9 million, or $0.01 per diluted share, of Continental's reported net income. Adjusted net income for fourth quarter 2018 was $201.7 million, or $0.54 per diluted share (non-GAAP). Net cash provided by operating activities for fourth quarter 2018 was $955.3 million and EBITDAX was $850.6 million (non-GAAP).
Adjusted net income, adjusted net income per share, free cash flow, EBITDAX, net debt, net sales prices and cash general and administrative (G&A) expenses per barrel of oil equivalent (Boe) presented herein are non-GAAP financial measures. Definitions and explanations for how these measures relate to the most directly comparable U.S. generally accepted accounting principles (GAAP) financial measures are provided at the conclusion of this press release. Also presented at the end of this press release is the Company's calculation of return on capital employed for 2018.
"2018 was a breakout year of performance for Continental with significant cash flow generation and debt reduction, as well as corporate returns that compare favorably against our peers and are competitive with other industries," said Harold Hamm, Chairman and Chief Executive Officer. "In 2019, we will continue to deliver strong corporate returns coupled with growth that can adjust to various market conditions."
Production Update: 4Q18 Oil Production up 14% over 3Q18
Full-year 2018 production increased 23% over full-year 2017, averaging 298,190 Boe per day. 2018 oil production increased 21% over 2017, averaging 168,177 barrels of oil (Bo) per day. 2018 natural gas production averaged 780.1 million cubic feet (MMcf) per day.
Fourth quarter 2018 production increased 9% over third quarter 2018 and 13% over fourth quarter 2017, averaging 324,001 Boe per day. Fourth quarter 2018 oil production increased 14% over third quarter 2018 and 11% over fourth quarter 2017, averaging 186,934 Bo per day. Fourth quarter 2018 natural gas production averaged 822.4 MMcf per day.
The following table provides the Company's average daily production by region for the periods presented.
4Q | 3Q | 4Q | FY | FY | ||||||
Boe per day | 2018 | 2018 | 2017 | 2018 | 2017 | |||||
North Region: | ||||||||||
North Dakota Bakken | 177,358 | 161,008 | 158,640 | 161,231 | 125,577 | |||||
Montana Bakken | 6,478 | 6,635 | 6,958 | 6,569 | 7,415 | |||||
Other | 9,077 | 9,015 | 9,965 | 9,125 | 10,182 | |||||
South Region: | ||||||||||
SCOOP | 67,244 | 63,270 | 62,242 | 64,339 | 60,693 | |||||
STACK | 62,947 | 56,129 | 47,914 | 56,055 | 36,220 | |||||
Other(1) | 897 | 847 | 1,266 | 871 | 2,550 | |||||
Total | 324,001 | 296,904 | 286,985 | 298,190 | 242,637 |
(1) Producing properties comprising approximately 1,700 Boe per day of the Company's Arkoma production were sold in September 2017. |
Bakken: 183,836 Boepd Average Daily 4Q18 Production; up 10% over 3Q18
The Company's full-year 2018 Bakken production increased 26% over 2017, averaging 167,800 Boe per day. The Company's fourth quarter 2018 Bakken production increased 10% over third quarter 2018 and 11% over fourth quarter 2017, averaging 183,836 Boe per day. During the quarter, the Company completed 52 gross (34 net) operated wells with first production flowing at an average initial 24-hour rate per well of 2,800 Boe per day.
"Continental has entered a new era of optimized full field development in the Bakken where technology and operational efficiencies have uplifted performance across the play," said Jack Stark, President. "As we look to 2019 and beyond, the Bakken will continue to underpin Continental's sustainable, value-driven and oil-weighted growth."
STACK: Another Over-Pressured Condensate Unit Outperforms Parent Type Curve
The Company's fourth quarter 2018 STACK production increased 12% over third quarter 2018 and 31% over fourth quarter 2017, averaging 62,947 Boe per day. During the quarter, the Company completed 19 gross (9 net) operated wells with first production flowing at an average initial 24-hour rate per well of 3,645 Boe per day.
The Company recently completed another outstanding Meramec unit in the over-pressured condensate window of STACK. The Boden unit flowed at an impressive combined initial 24-hour rate of 14,071 Boe per day, averaging 1,197 Bo per day per well and 20,961 Mcf per day per well.
"Recent results from the Boden unit further validate Continental's optimized density development and the high quality of the over-pressured Meramec that underlies our acreage position in STACK," said Gary Gould, Senior Vice President of Production & Resource Development.
SCOOP: SpringBoard on Pace to Add 10% to CLR Net Oil Production (3Q18-3Q19)
The Company's fourth quarter 2018 SCOOP production increased 6% over third quarter 2018 and 8% over fourth quarter 2017, averaging 67,244 Boe per day. The Company completed 17 gross (14 net) operated wells with first production in fourth quarter 2018. The Company's fourth quarter 2018 SCOOP oil production increased 47% over fourth quarter 2017, reflecting the decision made in early 2018 to shift to the Company's oil-weighted assets.
As previously announced in the Company's Project SpringBoard conference call, Project SpringBoard is expected to add 10%, or 16,500 barrels of oil per day, to the Company's total net oil production from third quarter 2018 to third quarter 2019. In fourth quarter 2018, Project SpringBoard production growth was on pace, producing an average 5,260 barrels of oil per day. The Company currently has 45 gross operated wells waiting on completion in Project SpringBoard with 18 gross operated wells in the Springer reservoir and 27 gross operated wells in the Woodford and Sycamore reservoirs. Approximately 12 rigs will be focused on Project SpringBoard in 2019, with approximately 7 rigs targeting the Springer and approximately 5 rigs targeting the Woodford and Sycamore.
Financial Update
"Continental's 2018 performance signals a structural transition to free cash flow generation through low cost operations and development," said John Hart, Chief Financial Officer. "Over the next five years, we are targeting free cash flow generation, continued debt reduction and an average 12.5% compound annual production growth rate to drive strong corporate returns and continued shareholder value."
As of December 31, 2018, the Company's balance sheet included approximately $282.7 million in cash and cash equivalents, $5.77 billion in total debt and $5.49 billion in net debt (non-GAAP). The Company anticipates further reducing net debt to $5 billion late in 2019.
For full-year 2018, the Company's average net sales prices excluding the effects of derivative positions were $59.19 per barrel of oil and $3.01 per Mcf of gas, or $41.25 per Boe. The Company remains unhedged on oil. Production expense per Boe was $3.59 for full-year 2018, a record annual low for the Company and well within annual guidance of $3.50 to $3.75.
Non-acquisition capital expenditures for full-year 2018 totaled approximately $2.8 billion, including $2.4 billion in exploration and development drilling and completion, $276.4 million in leasehold and minerals, and $198.8 million in workovers, recompletions and other.
In fourth quarter 2018, the Company's average net sales prices excluding the effects of derivative positions were $50.06 per barrel of oil and $3.26 per Mcf of gas, or $37.13 per Boe. Production expense per Boe was $3.50 for fourth quarter 2018.
Non-acquisition capital expenditures for fourth quarter 2018 totaled approximately $742.6 million, including $611.0 million in exploration and development drilling and completion, $59.0 million in leasehold and minerals, and $72.6 million in workovers, recompletions and other.
The Company's 2019 guidance remains as announced on February 13, 2019 and can be found at the conclusion of this press release.
CLR's Five Year Vision Targets
Over the next five years, the Company is targeting an average 12.5% compound annual production growth rate from existing inventory. The Company is also targeting an average annual free cash flow of $500 million per year at $60 per barrel WTI. Individual years may vary above or below these targets depending on the timing of future projects.
In addition to cash flow generation, the Company expects ROCE to remain strong over the next five years, competing against other energy companies as well as other industries. The Company is targeting average annual ROCE of approximately 14.5% per year over the five years at $60 per barrel WTI.
The Company expects capital allocation between its North and South assets to be reasonably consistent with the historical norm of approximately 50% to 60% in the North and approximately 40% to 50% in the South.
The Company's operating expenses on a per Boe basis are expected to remain relatively consistent or improve. Additionally, the Company expects oil and gas differentials to improve with continued infrastructure directed toward coastal markets, which will allow the Company to benefit from access to both premium domestic and global markets.
The Company's five year vision is underpinned by the depth and quality of current inventory. The Company estimates less than 30% of current inventory is to be developed under this five year vision. The five year inventory is projected to deliver a 60% blended average rate of return (ROR) at $60 per barrel WTI.
The following table provides the Company's production results, per-unit operating costs, results of operations and certain non-GAAP financial measures for the periods presented. Average net sales prices exclude any effect of derivative transactions. Per-unit expenses have been calculated using sales volumes.
Three months ended December 31, | Year ended December 31, | ||||||
2018 | 2017 | 2018 | 2017 | ||||
Average daily production: | |||||||
Crude oil (Bbl per day) | 186,934 | 168,066 | 168,177 | 138,455 | |||
Natural gas (Mcf per day) | 822,402 | 713,518 | 780,083 | 625,093 | |||
Crude oil equivalents (Boe per day) | 324,001 | 286,985 | 298,190 | 242,637 | |||
Average net sales prices (non-GAAP), excluding effect from derivatives: (1) | |||||||
Crude oil ($/Bbl) | $50.06 | $51.16 | $59.19 | $45.70 | |||
Natural gas ($/Mcf) | $3.26 | $3.30 | $3.01 | $2.93 | |||
Crude oil equivalents ($/Boe) | $37.13 | $38.27 | $41.25 | $33.65 | |||
Production expenses ($/Boe) | $3.50 | $3.17 | $3.59 | $3.66 | |||
Production taxes (% of net crude oil and gas sales) | 8.2% | 7.3% | 7.9% | 7.0% | |||
DD&A ($/Boe) | $16.41 | $17.93 | $17.09 | $18.89 | |||
Total general and administrative expenses ($/Boe) (2) | $1.65 | $2.30 | $1.69 | $2.16 | |||
Net income attributable to Continental Resources (in thousands) (3) | $197,738 | $841,914 | $988,317 | $789,447 | |||
Diluted net income per share attributable to Continental Resources | $0.53 | $2.25 | $2.64 | $2.11 | |||
Adjusted net income (non-GAAP) (in thousands) (1) | $201,686 | $153,660 | $1,066,237 | $190,803 | |||
Adjusted diluted net income per share (non-GAAP) (1) | $0.54 | $0.41 | $2.84 | $0.51 | |||
Net cash provided by operating activities (in thousands) | $955,267 | $731,125 | $3,456,008 | $2,079,106 | |||
EBITDAX (non-GAAP) (in thousands) (1) | $850,640 | $837,887 | $3,623,373 | $2,363,617 | |||
(1) Net sales prices, adjusted net income, adjusted diluted net income per share, and EBITDAX represent non-GAAP financial measures. Further information about these non-GAAP financial measures as well as reconciliations to the most directly comparable U.S. GAAP financial measures are provided at the end of this press release. | |||||||||||||||
(2) Total general and administrative expense is comprised of cash general and administrative expense and non-cash equity compensation expense. Cash general and administrative expense per Boe was $1.18, $1.80, $1.25, and $1.64 for 4Q 2018, 4Q 2017, FY 2018 and FY 2017, respectively. Non-cash equity compensation expense per Boe was $0.47, $0.50, $0.44, and $0.52 for 4Q 2018, 4Q 2017, FY 2018 and FY 2017, respectively. | |||||||||||||||
(3) In December 2017, the Tax Cuts and Jobs Act was signed into law, which among other things reduced the U.S. federal corporate income tax rate from 35% to 21% effective January 1, 2018. In accordance with U.S. GAAP, the Company remeasured its deferred income tax assets and liabilities as of December 31, 2017 to reflect the reduced tax rate, which resulted in a one-time increase in net income of approximately $713.7 million ($1.91 per diluted share) for the three and twelve months ended December 31, 2017. | |||||||||||||||
Fourth Quarter Earnings Conference Call
Continental plans to host a conference call to discuss fourth quarter and full-year 2018 results on Tuesday, February 19, 2019 at 12:00 p.m. ET (11:00 a.m. CT). Those wishing to listen to the conference call may do so via the Company's website at www.CLR.com or by phone:
Time and date: | 12 p.m. ET, Tuesday, February 19, 2019 |
Dial-in: | 844-309-6572 |
Intl. dial-in: | 484-747-6921 |
Conference ID: | 5856777 |
A replay of the call will be available for 14 days on the Company's website or by dialing:
Replay number: | 855-859-2056 or 404-537-3406 |
Intl. replay: | 800-585-8367 |
Conference ID: | 5856777 |
Continental plans to publish a fourth quarter and full-year 2018 summary presentation to its website at www.CLR.com prior to the start of its conference call on February 19, 2019.
Upcoming Conferences
Members of Continental's management team expect to participate in the following investment conference:
March 25-26, 2019 Scotia Howard Weil 47th Annual Energy Conference – New Orleans, LA
Presentation materials for the conference mentioned above will be available on the Company's web site at www.CLR.com prior to the start of the Company's presentation at such conference.
About Continental Resources
Continental Resources (NYSE: CLR) is a top 10 independent oil producer in the U.S. Lower 48 and a leader in America's energy renaissance. Based in Oklahoma City, Continental is the largest leaseholder and the largest producer in the nation's premier oil field, the Bakken play of North Dakota and Montana. The Company also has significant positions in Oklahoma, including its SCOOP Woodford and SCOOP Springer discoveries and the STACK plays. With a focus on the exploration and production of oil, Continental has unlocked the technology and resources vital to American energy independence and our nation's leadership in the new world oil market. In 2019, the Company will celebrate 52 years of operations. For more information, please visit www.CLR.com.
Cautionary Statement for the Purpose of the "Safe Harbor" Provisions of the Private Securities Litigation Reform Act of 1995
This press release includes "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements included in this press release other than statements of historical fact, including, but not limited to, forecasts or expectations regarding the Company's business and statements or information concerning the Company's future operations, performance, financial condition, production and reserves, schedules, plans, timing of development, rates of return, budgets, costs, business strategy, objectives, and cash flows are forward-looking statements. When used in this press release, the words "could," "may," "believe," "anticipate," "intend," "estimate," "expect," "project," "budget," "target," "plan," "continue," "potential," "guidance," "strategy," and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words.
Forward-looking statements are based on the Company's current expectations and assumptions about future events and currently available information as to the outcome and timing of future events. Although the Company believes these assumptions and expectations are reasonable, they are inherently subject to numerous business, economic, competitive, regulatory and other risks and uncertainties, most of which are difficult to predict and many of which are beyond the Company's control. No assurance can be given that such expectations will be correct or achieved or that the assumptions are accurate. The risks and uncertainties include, but are not limited to, commodity price volatility; the geographic concentration of our operations; financial market and economic volatility; the inability to access needed capital; the risks and potential liabilities inherent in crude oil and natural gas drilling and production and the availability of insurance to cover any losses resulting therefrom; difficulties in estimating proved reserves and other reserves-based measures; declines in the values of our crude oil and natural gas properties resulting in impairment charges; our ability to replace proved reserves and sustain production; the availability or cost of equipment and oilfield services; leasehold terms expiring on undeveloped acreage before production can be established; our ability to project future production, achieve targeted results in drilling and well operations and predict the amount and timing of development expenditures; the availability and cost of transportation, processing and refining facilities; legislative and regulatory changes adversely affecting our industry and our business, including initiatives related to hydraulic fracturing; increased market and industry competition, including from alternative fuels and other energy sources; and the other risks described under Part I, Item 1A. Risk Factors and elsewhere in the Company's Annual Report on Form 10-K for the year ended December 31, 2017, and once filed, for the year ended December 31, 2018, registration statements and other reports filed from time to time with the SEC, and other announcements the Company makes from time to time.
Readers are cautioned not to place undue reliance on forward-looking statements, which speak only as of the date on which such statement is made. Should one or more of the risks or uncertainties described in this press release occur, or should underlying assumptions prove incorrect, the Company's actual results and plans could differ materially from those expressed in any forward-looking statements. All forward-looking statements are expressly qualified in their entirety by this cautionary statement. Except as otherwise required by applicable law, the Company undertakes no obligation to publicly correct or update any forward-looking statement whether as a result of new information, future events or circumstances after the date of this report, or otherwise.
Readers are cautioned that initial production rates are subject to decline over time and should not be regarded as reflective of sustained production levels. In particular, production from horizontal drilling in shale oil and natural gas resource plays and tight natural gas plays that are stimulated with extensive pressure fracturing are typically characterized by significant early declines in production rates.
We use the term "EUR" or "estimated ultimate recovery" to describe potentially recoverable oil and natural gas hydrocarbon quantities. We include these estimates to demonstrate what we believe to be the potential for future drilling and production on our properties. These estimates are by their nature much more speculative than estimates of proved reserves and require substantial capital spending to implement recovery. Actual locations drilled and quantities that may be ultimately recovered from our properties will differ substantially. EUR data included herein remain subject to change as more well data is analyzed.
Investor Contact: | Media Contact: | |
Rory Sabino | Kristin Thomas | |
Vice President, Investor Relations | Senior Vice President, Public Relations | |
405-234-9620 | 405-234-9480 | |
Lucy Guttenberger | ||
Senior Investor Relations Associate | ||
405-774-5878 | ||