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| 8-K - FORM 8-K EARNINGS RELEASE Q1 2018 - ROAN RESOURCES, INC. | form8-kq12018earningsrelea.htm |
Exhibit 99.1
LINN ENERGY REPORTS FIRST-QUARTER 2018 RESULTS
HOUSTON, May 3, 2018 - LINN Energy, Inc. (OTCQB: LNGG) (“LINN” or the “Company”) announces financial and operating results for the first quarter 2018 and highlights the following:
• | Announced strategic plan to separate into two public companies, Roan Resources (“Roan”) and Riviera Resources (“Riviera”) during mid-summer 2018 |
• | Completed strategic divesture program resulting in approximately $2 billion of closed asset sales |
• | Strong balance sheet with no debt and a first quarter ending cash balance of approximately $227 million |
• | Returned more than $600 million of capital to LINN shareholders through share repurchases |
• | Blue Mountain Midstream (“Blue Mountain”) anticipates commissioning the Chisholm Trail cryogenic plant by the end of the second quarter 2018 |
• | Outperformed guidance on production, operating expenses and adjusted EBITDAX for the quarter |
"We achieved several key strategic milestones in our mission to maximize value for our shareholders. First, we continue to perform exceptionally well operationally, meeting or exceeding guidance each of the past five quarters. Second, we completed our strategic divestiture program of ~$2 billion, allowing us to continue to repurchase shares including the $325 million tender offer completed in January. Third, we believe our shares are trading at a significant discount and are in progress to execute our separation plan this summer to unlock this value. Fourth, Blue Mountain is nearing the completion of its Chisholm Trail cryogenic plant in the Merge. It is truly impressive the amount of progress our organization and Board has accomplished this past year. I would like to thank our employees for their hard work in executing our vision and look forward to the bright futures of Roan and Riviera,” said Mark E. Ellis, LINN’s President and Chief Executive Officer.
Key Financial Results (1)
First Quarter | ||
$ in millions | 2018 | 2017 |
Average daily production (MMcfe/d) | 401 | 750 |
Oil, natural gas and NGL sales | $ 137 | $ 269 |
Income from continuing operations | $ 71 | $ 2,390 |
Loss from discontinued operations, net of income taxes | $ 0 | $ (0.5) |
Net income | $ 71 | $ 2,390 |
Adjusted EBITDAX (a non-GAAP financial measure) (2) | $ 40 | $ 114 |
LINN Adjusted EBITDAX for Roan (a non-GAAP financial measure)(3) | $ 37 | N/A |
Net cash provided by operating activities | $ 48 | $ 65 |
Oil and natural gas capital | $ 10 | $ 56 |
Total capital | $ 67 | $ 64 |
(1) | All amounts reflect continuing operations with the exception of net income. |
(2) | Excludes Adjusted EBITDAX from discontinued operations of approximately $15 million for the three months ended March 31, 2017. |
(3) | Represents the Adjusted EBITDAX for LINN’s 50% equity interest in Roan for the period from January 1, 2018, to March 31, 2018. See Schedule 1 below for a reconciliation of Adjusted EBITDA |
Strategic Update on the Separation
As previously announced, Company’s Board of Directors (“the Board”) believes the Company trades at a discount to its sum of the parts value and therefore determined to break the Company into separate stand-alone publically traded businesses to unlock this value. To execute this plan in a timely and tax efficient manner, the Board has decided to separate into two public companies, Roan Resources and Riviera Resources. The Board and management are focused on executing this value maximizing plan for shareholders by mid-summer 2018 and expect to provide financial and operational updates at or prior to the separation.
The Company has formed Riviera Resources, which will hold the following upstream assets: Hugoton, Michigan/Illinois, Arkoma, East Texas, North Louisiana, Drunkards Wash as well the assets of Blue Mountain and more than 100,000 net acres in the prospective NW Stack play. Riviera, upon completion of the separation, is expected to be an unlevered upstream and midstream business with highly economic organic investment opportunities. Riviera will be listed for trading on the OTC market under the ticker RVRA.
1
Following the separation, LINN Energy, Inc., which currently trades on the OTC market under the ticker LNGG, will solely serve as a holding company for its 50 percent equity interest in Roan. The Company has executed a term sheet with Roan Holdings, LLC (the successor to Citizen Energy II, LLC) which is expected to result in the combination of LNGG’s 50 percent equity interest with Roan Holdings, LLC’s 50 percent equity interest. This will allow for the consolidation of 100 percent of the equity in Roan under LNGG, subject to due diligence and execution of definitive documentation, during the third quarter of this year. Roan Resources is preparing to up list to the NYSE or NASDAQ during 2018 under the ticker ROAN.
Completion of $2 Billion Strategic Divestiture Program
The Company successfully completed more than 20 separate divestitures this past year resulting in approximately $2 billion of closed asset sales. The sales far exceeded expectations with a significant premium to proved developed PV-10 value. In addition, the Company has elected to retain the previously marketed Drunkards Wash properties in Utah and those assets will become part of Riviera Resources.
Strong Balance Sheet
From its successful divestiture program in 2017 and 2018, the Company extinguished all outstanding debt. As of March 31, 2018, the Company had no borrowings outstanding under its $390 million revolving credit facility and had approximately $343 million available borrowing capacity inclusive of outstanding letters of credit. LINN has a first quarter ending cash balance of approximately $227 million and pending the closing of previously announced asset sales, forecasts to have approximately $330 million of cash on its balance sheet at the end of the second quarter of 2018. Additionally, on April 30, 2018, the Company’s borrowing base was increased to $425 million.
Share Repurchase Update
The Board continues to focus on returning capital to its shareholders and since our financial reorganization has repurchased approximately $605 million of its outstanding Class A common stock through the share repurchase program, recent tender offer and the employee liquidity program. The Company has also retired approximately $20 million of its Class A-2 shares related to the HoldCo profits interest.
Roan Resources Update
Roan Resources was formed in the second quarter of 2017 and is focused on the accelerated development of approximately 150,000 net acres in the prolific Merge/SCOOP/STACK play of Oklahoma.
During the first quarter, Roan operated six drilling rigs in the Merge and drilled 13 operated wells with lateral lengths ranging between one-to-two miles. Completion activity in the first quarter slowed from the fourth quarter 2017 pace while awaiting the start-up of Blue Mountain’s Chisholm Trail cryogenic plant. Net production averaged approximately 38,000 BOE/d and Roan ended the quarter with 11 drilled but uncompleted (“DUC”) wells. Roan expects the inventory of DUC wells to increase until processing capacity is expanded. Once the new plant is commissioned at the end of second quarter, Roan will fully resume completion activity to work down its DUC inventory and expects significant growth in the second half of 2018.
Roan was successful in reducing drill-times and improving geo-steering efforts during the quarter. An example of this includes the one-mile Orange Sherbet 17-10-6-2H well, which was drilled spud-to-TD in approximately 11 days, an improvement of seven days compared to its closest one-mile offset well drilled in 2017. Geo-steering improved Roan’s in-zone ratio to approximately 95% during the quarter.
Roan had impressive results in the quarter and highlights two of its pads in Grady County. On the Collins pad, the Collins 11-2-9-5-1XH had an initial production 30-day rate of 3,548 BOE/d and a 90-day rate of 2,544 BOE/d (74% liquids). A second well, the Collins 10-3-9-5-1XH, had an initial production 30-day rate of 3,228 BOE/d and a 90-day rate of 2,486 BOE/d (77% liquids) while producing more than 132,000 barrels of oil during its first 90 days. Both Collins wells are targeting the Mississippian formation from two-mile laterals. On the Griffin pad, the Griffin 26-23-10-5-1XH had an initial production 30-day rate of 2,478 BOE/d and a 90-day rate of 1,917 BOE/d (82% liquids) and the Griffin 26-35-10-5-1XH had an initial production 30-day rate of 1,812 BOE/d and a 90-day rate of 1,544 BOE/d (65% liquids). Both Griffin wells are targeting the Mississippian formation from 1.5-mile laterals.
In early April, Roan completed its spring 2018 borrowing base redetermination process for its senior secured revolving credit facility. All participating lenders consented to a borrowing base increase from $275 million to $425 million. As of March 31, 2018, approximately $205 million had been drawn on the revolver. Roan has no other outstanding debt.
Additional information on Roan can be found in the supplemental presentation located on LINN’s website.
2
Riviera Resources
Once formed, Riviera’s primary focus will be the development of its growth-oriented assets and efficiently operating more than 1.7 Tcfe of high quality producing assets, including sizable positions in Hugoton and Michigan. Its growth assets include more than 100,000 net acres in the prospective NW Stack play of Oklahoma with additional horizontal potential in East Texas, North Louisiana and Arkoma.
Non-operated horizontal development has significantly increased in the NW STACK where Riviera plans to commit additional non-operated capital and is evaluating deploying an operated drilling rig later this year. Building on the successful 2017 East Texas drilling program, the Company is conducting an in-depth resource assessment incorporating its recently acquired 3-D seismic data and Riviera plans to resume its drilling program in 2019. The Company estimates 2018 oil and gas capital for Riviera to be approximately $35 million.
Riviera’s midstream subsidiary, Blue Mountain, has more than 80,000 dedicated net acres in the heart of the liquids-rich Merge play. Blue Mountain is constructing a state-of-the-art, highly efficient cryogenic plant to expand its existing midstream business and anticipates the new plant to be operational by the end of the second quarter of 2018. Once at full capacity, Chisholm Trail and its related gathering is forecasted to generate annualized EBITDAX between $100 million and $125 million. With significant growth forecasted from Roan and other producers in the second half of 2018, Blue Mountain estimates a 2018 exit-rate throughput for the plant of 150 MMcf/d to 200 MMcf/d and expects to reach full capacity in 2019. With the forecasted growth from its currently dedicated acreage position, Blue Mountain anticipates the need to expand the cryogenic plant and continues to pursue additional producer dedications.
In connection with the separation, the Company will have a reduction in its workforce that will include approximately $35 million of severance expenses and will reduce the general and administrative run rate for Riviera to approximately $25 million to $30 million per year beginning in 2019, not including Blue Mountain Midstream.
First Quarter Actuals versus Guidance
Q1 Actuals | Q1 Guidance | |
Net Production (MMcfe/d) | 401 | 375 - 415 |
Natural gas (MMcf/d) | 266 | 257 - 284 |
Oil (Bbls/d) | 8,481 | 7,327 - 8,098 |
NGL (Bbls/d) | 14,124 | 12,426 - 13,734 |
Other revenues, net (in thousands) (1) | $ 10,406 | $ 13,000 - $ 15,000 |
Operating Costs (in thousands) | $ 75,430 | $ 72,000 - $ 81,000 |
Lease operating expenses | $ 47,884 | $ 43,000 - $ 48,000 |
Transportation expenses | $ 19,094 | $ 20,000 - $ 23,000 |
Taxes, other than income taxes | $ 8,452 | $ 9,000 - $ 10,000 |
General and administrative expenses (2) | $ 23,697 | $ 24,000 - $ 27,000 |
General and administrative severance expenses | $ 4,045 | $ 5,000 |
Targets (Mid-Point) (in thousands) | ||
Adjusted EBITDAX (3) | $ 40,044 | $ 39,000 |
Interest expense | $ 404 | $ 0 (4) |
Oil and natural gas capital | $ 10,064 | $ 7,000 |
Total capital | $ 66,928 | $ 60,000 |
Weighted Average NYMEX Differentials | ||
Natural gas (MMBtu) | ($ 0.35) | ($ 0.33) - ($ 0.29) |
Oil (Bbl) | ($ 3.00) | ($ 3.45) - ($ 3.12) |
NGL price as a % of NYMEX oil price | 35% | 39% - 43% |
(1) | Includes other revenues and margin on marketing activities |
(2) | Excludes share-based compensation expenses and severance expenses |
(3) | Includes a reduction to EBITDAX for estimated severance expenses, costs associated with managing assets divested during 2018, associated divestment costs, required transition services under purchase and sale agreements and estimated separation costs |
(4) | Excludes non cash amortization of deferred financing costs |
3
Second Quarter and Revised Full Year 2018 Guidance
Guidance estimates have been revised to include the previously marketed Drunkards Wash properties, and increased capital budget. The 2018 capital budget has been increased to $160 million, primarily driven by a $24 million increase at Blue Mountain Midstream for additional capital needed for incremental gathering related to third party dedications and pipeline interconnects.
The guidance provided below excludes LINN’s 50 percent equity interest in Roan and has been adjusted for the timing of the previously announced asset sales that closed in the second quarter.
Q2 2018E | Revised Guidance FY 2018E | |
Net Production (MMcfe/d) | 295 - 325 | 310 - 350 |
Natural gas (MMcf/d) | 230 - 255 | 230 - 260 |
Oil (Bbls/d) | 1,650 - 1,750 | 3,000 - 3,500 |
NGL (Bbls/d) | 9,250 - 10,000 | 10,200 - 11,300 |
Other revenues, net (in thousands) (1) | $ 10,000 - $ 12,000 | $ 68,000 - $ 75,000 |
Costs (in thousands) | $ 48,000 - $ 54,000 | $ 215,000 - $ 238,000 |
Lease operating expenses | $ 24,000 - $ 27,000 | $ 115,000 - $ 127,000 |
Transportation expenses | $ 17,000 - $ 19,000 | $ 70,000 - $ 77,000 |
Taxes, other than income taxes | $ 7,000 - $ 8,000 | $ 30,000 - $ 34,000 |
General and administrative expenses (2) | $ 20,000 - $ 22,000 | $ 75,000 - $ 82,000 |
General and administrative severance expenses | $ 11,000 - $ 14,000 | $ 33,000 - $ 37,000 |
Costs per Mcfe (Mid-Point) | $ 1.81 | $ 1.89 |
Lease operating expenses | $ 0.90 | $ 1.01 |
Transportation expenses | $ 0.64 | $ 0.61 |
Taxes, other than income taxes | $ 0.27 | $ 0.27 |
Targets (Mid-Point) (in thousands) | ||
Adjusted EBITDAX (3) | $ 6,000 | $ 108,000 |
Interest expense (4) | — | — |
Oil and natural gas capital | $ 9,000 | $ 35,000 |
Total capital | $ 54,000 | $ 160,000 |
Weighted Average NYMEX Differentials | ||
Natural gas (MMBtu) | ($ 0.52) - ($ 0.43) | ($ 0.50) - ($ 0.40) |
Oil (Bbl) | ($ 2.90) - ($ 2.50) | ($ 3.10) - ($ 2.50) |
NGL price as a % of crude oil price | 30% - 34% | 32% - 36% |
Unhedged Commodity Price Assumptions | Apr | May | Jun | 2018E |
Natural gas (MMBtu) | $ 2.69 | $ 2.74 | $ 2.77 | $ 2.85 |
Oil (Bbl) | $ 65.56 | $ 68.38 | $ 68.40 | $ 65.97 |
NGL (Bbl) | $ 21.02 | $ 22.15 | $ 22.14 | $ 22.53 |
(1) | Includes other revenues and margin on marketing activities |
(2) | Excludes share-based compensation expenses and severance expenses |
(3) | Includes a reduction to EBITDAX for estimated severance expenses, costs associated with managing assets divested during 2018, associated divestment costs, required transition services under purchase and sale agreements and estimated separation costs |
(4) | Excludes non cash amortization of deferred financing costs |
4
Hedging Update
In April 2018, in connection with closing of the Altamont Bluebell sale, the Company unwound all 2018 and 2019 oil collars at a cost of approximately $20 million.
2018 | 2019 | |||
Natural Gas | Volume (MMMBtu/d) | Average Price (per MMBtu) | Volume (MMMBtu/d) | Average Price (per MMBtu) |
Swaps | 191 | $3.02 | 51 | $2.91 |
Oil | Volume (Bbls/d) | Average Price (per Bbl) | Volume (Bbls/d) | Average Price (per Bbl) |
Swaps | 1,500 | $54.07 | — | — |
Natural Gas Basis Differential | Volume (MMMBtu/d) | Average Price (per MMBtu) | Volume (MMMBtu/d) | Average Price (per MMBtu) |
NGPL TX-OK Basis Swaps | 10 | ($0.19) | — | — |
Earnings Call / Form 10‑Q
The Company will host a conference call Thursday, May 3, 2018 at 10 a.m. (Central) to discuss this strategic update and the Company’s first quarter 2018 results. There will be prepared remarks by Mark E. Ellis, President and Chief Executive Officer, David Rottino, LINN’s Executive Vice President and Chief Financial Officer and President and Chief Executive Officer of Riviera Resources, and Greg Harper, the President and Chief Executive Officer of Blue Mountain Midstream.
Investors and analysts are invited to participate in the call by dialing (844) 625-4392, or (409) 497-0988 for international calls using Conference ID: 7288377. Interested parties may also listen over the internet at www.linnenergy.com. A replay of the call will be available on the company’s website or by phone until May 17, 2018. The number for the replay is (855) 859-2056 or (404) 537-3406 for international calls using Conference ID: 7288377.
Supplemental information can be found at the following link on our website: http://ir.linnenergy.com/presentations.cfm
About LINN Energy
LINN Energy, Inc. was formed in February 2017 as the reorganized successor to LINN Energy, LLC. Headquartered in Houston, Texas, the Company’s current focus is the development of the Merge/SCOOP/STACK in Oklahoma through its equity interest in Roan Resources LLC, as well as through its midstream operations in that area. Additionally, the Company is pursuing emerging horizontal opportunities in Oklahoma, North Louisiana and East Texas, while continuing to add value by efficiently operating and applying new technology to a diverse set of long-life producing assets.
Forward-Looking Statements
Statements made in this press release that are not historical facts are “forward-looking statements.” These statements are based on certain assumptions and expectations made by the Company which reflect management’s experience, estimates and perception of historical trends, current conditions, and anticipated future developments. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company, which may cause actual results to differ materially from those implied or anticipated in the forward-looking statements. These include risks relating to financial and operational performance and results of the Company and Roan Resources LLC, timing of and ability to execute planned separation transactions and asset sales, continued low or further declining commodity prices and demand for oil, natural gas and natural gas liquids, ability to hedge future production, ability to replace reserves and efficiently develop current reserves, the capacity and utilization of midstream facilities and the regulatory environment. These and other important factors could cause actual results to differ materially from those anticipated or implied in the forward-looking statements. Please read “Risk Factors” in the Company’s Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q and other public filings. We undertake no obligation to publicly update any forward-looking statements, whether as a result of new information or future events.
CONTACTS: LINN Energy, Inc.
Investors:
Jim Frew – Investor Relations
(281) 840-4110
ir@linnenergy.com
5
Consolidated Balance Sheets (Unaudited)
March 31, 2018 | December 31, 2017 | ||||||
(in thousands) | |||||||
ASSETS | |||||||
Current assets: | |||||||
Cash and cash equivalents | $ | 227,196 | $ | 464,508 | |||
Accounts receivable – trade, net | 130,527 | 140,485 | |||||
Derivative instruments | 7,287 | 9,629 | |||||
Restricted cash | 77,263 | 56,445 | |||||
Other current assets | 65,213 | 79,771 | |||||
Assets held for sale | 92,492 | 106,963 | |||||
Total current assets | 599,978 | 857,801 | |||||
Noncurrent assets: | |||||||
Oil and natural gas properties (successful efforts method) | 778,091 | 950,083 | |||||
Less accumulated depletion and amortization | (48,142 | ) | (49,619 | ) | |||
729,949 | 900,464 | ||||||
Other property and equipment | 533,078 | 480,729 | |||||
Less accumulated depreciation | (36,326 | ) | (28,658 | ) | |||
496,752 | 452,071 | ||||||
Derivative instruments | 936 | 469 | |||||
Deferred income taxes | 162,709 | 198,417 | |||||
Equity method investments | 490,503 | 464,926 | |||||
Other noncurrent assets | 5,983 | 6,975 | |||||
660,131 | 670,787 | ||||||
Total noncurrent assets | 1,886,832 | 2,023,322 | |||||
Total assets | $ | 2,486,810 | $ | 2,881,123 | |||
LIABILITIES AND EQUITY | |||||||
Current liabilities: | |||||||
Accounts payable and accrued expenses | $ | 264,973 | $ | 253,975 | |||
Derivative instruments | 16,931 | 10,103 | |||||
Other accrued liabilities | 38,948 | 58,617 | |||||
Liabilities held for sale | 42,891 | 43,302 | |||||
Total current liabilities | 363,743 | 365,997 | |||||
Noncurrent liabilities: | |||||||
Derivative instruments | 4,682 | 2,849 | |||||
Asset retirement obligations and other noncurrent liabilities | 104,730 | 160,720 | |||||
Total noncurrent liabilities | 109,412 | 163,569 | |||||
Equity: | |||||||
Class A common stock | 76 | 84 | |||||
Additional paid-in capital | 1,478,365 | 1,899,642 | |||||
Retained earnings | 502,684 | 432,860 | |||||
Total common stockholders’ equity | 1,981,125 | 2,332,586 | |||||
Noncontrolling interests | 32,530 | 18,971 | |||||
Total equity | 2,013,655 | 2,351,557 | |||||
Total liabilities and equity | $ | 2,486,810 | $ | 2,881,123 | |||
6
Consolidated Balance Sheets - Continued (Unaudited)
7
Consolidated Statements of Operations (Unaudited)
Successor | Predecessor | |||||||||||
Three Months Ended March 31, 2018 | One Month Ended March 31, 2017 | Two Months Ended February 28, 2017 | ||||||||||
(in thousands, except per share and per unit amounts) | ||||||||||||
Revenues and other: | ||||||||||||
Oil, natural gas and natural gas liquids sales | $ | 136,876 | $ | 80,325 | $ | 188,885 | ||||||
Gains (losses) on oil and natural gas derivatives | (15,030 | ) | (11,959 | ) | 92,691 | |||||||
Marketing revenues | 46,267 | 2,914 | 6,636 | |||||||||
Other revenues | 5,894 | 2,028 | 9,915 | |||||||||
174,007 | 73,308 | 298,127 | ||||||||||
Expenses: | ||||||||||||
Lease operating expenses | 47,884 | 24,630 | 49,665 | |||||||||
Transportation expenses | 19,094 | 13,723 | 25,972 | |||||||||
Marketing expenses | 41,755 | 2,539 | 4,820 | |||||||||
General and administrative expenses | 44,779 | 10,411 | 71,745 | |||||||||
Exploration costs | 1,202 | 55 | 93 | |||||||||
Depreciation, depletion and amortization | 28,465 | 19,914 | 47,155 | |||||||||
Taxes, other than income taxes | 8,452 | 7,077 | 14,877 | |||||||||
(Gains) losses on sale of assets and other, net | (106,075 | ) | 484 | 829 | ||||||||
85,556 | 78,833 | 215,156 | ||||||||||
Other income and (expenses): | ||||||||||||
Interest expense, net of amounts capitalized | (404 | ) | (4,200 | ) | (16,725 | ) | ||||||
Earnings from equity method investments | 25,345 | 39 | 157 | |||||||||
Other, net | (169 | ) | (388 | ) | (149 | ) | ||||||
24,772 | (4,549 | ) | (16,717 | ) | ||||||||
Reorganization items, net | (1,951 | ) | (2,565 | ) | 2,331,189 | |||||||
Income (loss) from continuing operations before income taxes | 111,272 | (12,639 | ) | 2,397,443 | ||||||||
Income tax expense (benefit) | 40,174 | (5,315 | ) | (166 | ) | |||||||
Income (loss) from continuing operations | 71,098 | (7,324 | ) | 2,397,609 | ||||||||
Income (loss) from discontinued operations, net of income taxes | — | 68 | (548 | ) | ||||||||
Net income (loss) | 71,098 | (7,256 | ) | 2,397,061 | ||||||||
Net income attributable to noncontrolling interests | 1,274 | — | — | |||||||||
Net income (loss) attributable to common stockholders/unitholders | $ | 69,824 | $ | (7,256 | ) | $ | 2,397,061 | |||||
Income (loss) per share/unit attributable to common stockholders/unitholders: | ||||||||||||
Income (loss) from continuing operations per share/unit – Basic | $ | 0.88 | $ | (0.08 | ) | $ | 6.80 | |||||
Income (loss) from continuing operations per share/unit – Diluted | $ | 0.86 | $ | (0.08 | ) | $ | 6.80 | |||||
Income (loss) from discontinued operations per share/unit – Basic | $ | — | $ | — | $ | (0.01 | ) | |||||
Income (loss) from discontinued operations per share/unit – Diluted | $ | — | $ | — | $ | (0.01 | ) | |||||
Net income (loss) per share/unit – Basic | $ | 0.88 | $ | (0.08 | ) | $ | 6.79 | |||||
Net income (loss) per share/unit – Diluted | $ | 0.86 | $ | (0.08 | ) | $ | 6.79 | |||||
Weighted average shares/units outstanding – Basic | 78,975 | 89,848 | 352,792 | |||||||||
Weighted average shares/units outstanding – Diluted | 80,332 | 89,848 | 352,792 | |||||||||
8
Consolidated Statements of Cash Flows (Unaudited)
Successor | Predecessor | |||||||||||
Three Months Ended March 31, 2018 | One Month Ended March 31, 2017 | Two Months Ended February 28, 2017 | ||||||||||
(in thousands) | ||||||||||||
Cash flow from operating activities: | ||||||||||||
Net income (loss) | $ | 71,098 | $ | (7,256 | ) | $ | 2,397,061 | |||||
Adjustments to reconcile net income (loss) to net cash provided by operating activities: | ||||||||||||
(Income) loss from discontinued operations | — | (68 | ) | 548 | ||||||||
Depreciation, depletion and amortization | 28,465 | 19,914 | 47,155 | |||||||||
Deferred income taxes | 40,660 | (5,034 | ) | (166 | ) | |||||||
Total (gains) losses on derivatives, net | 15,030 | 11,959 | (92,691 | ) | ||||||||
Cash settlements on derivatives | (4,494 | ) | 5,782 | (11,572 | ) | |||||||
Share-based compensation expenses | 17,037 | 4,177 | 50,255 | |||||||||
Amortization and write-off of deferred financing fees | 404 | 3 | 1,338 | |||||||||
(Gains) losses on sale of assets and other, net | (131,330 | ) | 345 | 1,069 | ||||||||
Reorganization items, net | — | — | (2,359,364 | ) | ||||||||
Changes in assets and liabilities: | ||||||||||||
(Increase) decrease in accounts receivable – trade, net | 5,415 | 26,614 | (7,216 | ) | ||||||||
(Increase) decrease in other assets | 14,176 | (2,553 | ) | 528 | ||||||||
Increase (decrease) in accounts payable and accrued expenses | 15,711 | (43,476 | ) | 20,949 | ||||||||
Increase (decrease) in other liabilities | (24,362 | ) | 4,187 | 2,801 | ||||||||
Net cash provided by operating activities – continuing operations | 47,810 | 14,594 | 50,695 | |||||||||
Net cash provided by operating activities – discontinued operations | — | 3,166 | 8,781 | |||||||||
Net cash provided by operating activities | 47,810 | 17,760 | 59,476 | |||||||||
Cash flow from investing activities: | ||||||||||||
Development of oil and natural gas properties | (26,024 | ) | (19,779 | ) | (50,597 | ) | ||||||
Purchases of other property and equipment | (46,110 | ) | (2,466 | ) | (7,409 | ) | ||||||
Proceeds from sale of properties and equipment and other | 232,394 | 326 | (166 | ) | ||||||||
Net cash provided by (used in) investing activities – continuing operations | 160,260 | (21,919 | ) | (58,172 | ) | |||||||
Net cash used in investing activities – discontinued operations | — | (465 | ) | (584 | ) | |||||||
Net cash provided by (used in) investing activities | 160,260 | (22,384 | ) | (58,756 | ) | |||||||
9
Consolidated Statements of Cash Flows - Continued (Unaudited)
Successor | Predecessor | |||||||||||
Three Months Ended March 31, 2018 | One Month Ended March 31, 2017 | Two Months Ended February 28, 2017 | ||||||||||
(in thousands) | ||||||||||||
Cash flow from financing activities: | ||||||||||||
Proceeds from rights offerings, net | — | — | 514,069 | |||||||||
Repurchases of shares | (367,830 | ) | — | — | ||||||||
Proceeds from borrowings | — | 30,000 | — | |||||||||
Repayments of debt | — | (96,250 | ) | (1,038,986 | ) | |||||||
Payment to holders of claims under the Predecessor’s second lien notes | — | — | (30,000 | ) | ||||||||
Distributions to noncontrolling interests | (8,007 | ) | — | — | ||||||||
Cash settlements of RSUs | (48,701 | ) | — | — | ||||||||
Other | (26 | ) | 17,658 | (6,015 | ) | |||||||
Net cash used in financing activities – continuing operations | (424,564 | ) | (48,592 | ) | (560,932 | ) | ||||||
Net cash used in financing activities – discontinued operations | — | — | — | |||||||||
Net cash used in financing activities | (424,564 | ) | (48,592 | ) | (560,932 | ) | ||||||
Net decrease in cash, cash equivalents and restricted cash | (216,494 | ) | (53,216 | ) | (560,212 | ) | ||||||
Cash, cash equivalents and restricted cash: | ||||||||||||
Beginning | 520,953 | 144,022 | 704,234 | |||||||||
Ending | $ | 304,459 | $ | 90,806 | $ | 144,022 | ||||||
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Schedule 1 - Adjusted EBITDAX (Non-GAAP Measure)
The non-GAAP financial measure of adjusted EBITDAX, as defined by the Company, may not be comparable to similarly titled measures used by other companies. Therefore, this non-GAAP measure should be considered in conjunction with net income (loss) and other performance measures prepared in accordance with GAAP. Adjusted EBITDAX should not be considered in isolation or as a substitute for GAAP.
Adjusted EBITDAX is a measure used by Company management to evaluate the Company’s operational performance and for comparisons to the Company’s industry peers. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results.
The following presents a reconciliation of net income (loss) to adjusted EBITDAX:
Three Months Ended March 31, | |||||||
2018 | 2017 | ||||||
(in thousands) | |||||||
Net income | $ | 71,098 | $ | 2,389,805 | |||
Plus (less): | |||||||
Income from discontinued operations | — | 480 | |||||
Interest expense | 404 | 20,925 | |||||
Income tax expense (benefit) | 40,174 | (5,481 | ) | ||||
Depreciation, depletion and amortization | 28,465 | 67,069 | |||||
Exploration costs | 1,202 | 148 | |||||
EBITDAX | 141,343 | 2,472,946 | |||||
Plus (less): | |||||||
Noncash (gains) losses on oil and natural gas derivatives | 10,536 | (86,522 | ) | ||||
Accrued settlements on oil derivative contracts related to current production period (1) | 633 | 1,302 | |||||
Share-based compensation expenses | 17,037 | 54,432 | |||||
Earnings from equity method investments | (25,345 | ) | (196 | ) | |||
(Gains) losses on sale of assets and other, net (2) | (106,111 | ) | 170 | ||||
Reorganization items, net (3) | 1,951 | (2,328,624 | ) | ||||
Adjusted EBITDAX | $ | 40,044 | $ | 113,508 | |||
(1) | Represent amounts related to oil derivative contracts that settled during the respective period (contract terms had expired) but cash had not been received as of the end of the period. |
(2) | Primarily represent gains or losses on the sales of assets and gains or losses on inventory valuation. |
(3) | Represent costs and income directly associated with the Company’s filing for voluntary reorganization under Chapter 11 of the U.S. Bankruptcy Code since the petition date, and also include adjustments to reflect the carrying value of certain liabilities subject to compromise at their estimated allowed claim amounts, as such adjustments are determined. |
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Schedule 1 – Adjusted EBITDAX (Non-GAAP Measure) - Continued
Roan Resources LLC Adjusted EBITDAX
Three Months Ended March 31, 2018 | |||
(in thousands) | |||
Net income | $ | 20,688 | |
Plus (less): | |||
Interest expense | 900 | ||
Depreciation, depletion and amortization | 11,773 | ||
Exploration costs | 250 | ||
EBITDAX | 33,611 | ||
Noncash losses on oil and natural gas derivatives | 2,738 | ||
Share-based compensation expenses | 1,146 | ||
Adjusted EBITDAX | $ | 37,495 | |
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