FORM 10-Q |
ý | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
¨ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
Oasis Petroleum Inc. (Exact name of registrant as specified in its charter) |
Delaware | 80-0554627 | |
(State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) | |
1001 Fannin Street, Suite 1500 Houston, Texas | 77002 | |
(Address of principal executive offices) | (Zip Code) |
(281) 404-9500 (Registrant’s telephone number, including area code) |
Large accelerated filer | ý | Accelerated filer | ¨ |
Non-accelerated filer | o (Do not check if a smaller reporting company) | Smaller reporting company | ¨ |
Emerging growth company | ¨ |
Page | |
Oasis Petroleum Inc. Condensed Consolidated Balance Sheets (Unaudited) | |||||||
June 30, 2018 | December 31, 2017 | ||||||
(In thousands, except share data) | |||||||
ASSETS | |||||||
Current assets | |||||||
Cash and cash equivalents | $ | 17,072 | $ | 16,720 | |||
Accounts receivable, net | 378,080 | 363,580 | |||||
Inventory | 23,222 | 19,367 | |||||
Prepaid expenses | 5,874 | 7,631 | |||||
Derivative instruments | — | 344 | |||||
Intangible assets, net | 625 | — | |||||
Other current assets | 82 | 193 | |||||
Total current assets | 424,955 | 407,835 | |||||
Property, plant and equipment | |||||||
Oil and gas properties (successful efforts method) | 8,424,834 | 7,838,955 | |||||
Other property and equipment | 1,024,104 | 868,746 | |||||
Less: accumulated depreciation, depletion, amortization and impairment | (2,691,697 | ) | (2,534,215 | ) | |||
Total property, plant and equipment, net | 6,757,241 | 6,173,486 | |||||
Assets held for sale, net | 250,118 | — | |||||
Derivative instruments | 25 | 9 | |||||
Long-term inventory | 12,505 | 12,200 | |||||
Other assets | 20,491 | 21,600 | |||||
Total assets | $ | 7,465,335 | $ | 6,615,130 | |||
LIABILITIES AND STOCKHOLDERS’ EQUITY | |||||||
Current liabilities | |||||||
Accounts payable | $ | 29,988 | $ | 13,370 | |||
Revenues and production taxes payable | 246,215 | 213,995 | |||||
Accrued liabilities | 320,508 | 236,480 | |||||
Accrued interest payable | 36,971 | 38,963 | |||||
Derivative instruments | 194,810 | 115,716 | |||||
Advances from joint interest partners | 3,983 | 4,916 | |||||
Other current liabilities | 40 | 40 | |||||
Total current liabilities | 832,515 | 623,480 | |||||
Long-term debt | 2,757,481 | 2,097,606 | |||||
Deferred income taxes | 205,628 | 305,921 | |||||
Asset retirement obligations | 49,743 | 48,511 | |||||
Liabilities held for sale | 4,181 | — | |||||
Derivative instruments | 35,007 | 19,851 | |||||
Other liabilities | 6,529 | 6,182 | |||||
Total liabilities | 3,891,084 | 3,101,551 | |||||
Commitments and contingencies (Note 17) | |||||||
Stockholders’ equity | |||||||
Common stock, $0.01 par value: 450,000,000 shares authorized; 320,010,534 shares issued and 317,985,056 shares outstanding at June 30, 2018 and 270,627,014 shares issued and 269,295,466 shares outstanding at December 31, 2017 | 3,154 | 2,668 | |||||
Treasury stock, at cost: 2,025,478 and 1,331,548 shares at June 30, 2018 and December 31, 2017, respectively | (28,243 | ) | (22,179 | ) | |||
Additional paid-in capital | 3,062,861 | 2,677,217 | |||||
Retained earnings | 398,371 | 717,985 | |||||
Oasis share of stockholders’ equity | 3,436,143 | 3,375,691 | |||||
Non-controlling interests | 138,108 | 137,888 | |||||
Total stockholders’ equity | 3,574,251 | 3,513,579 | |||||
Total liabilities and stockholders’ equity | $ | 7,465,335 | $ | 6,615,130 |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
(In thousands, except per share data) | |||||||||||||||
Revenues | |||||||||||||||
Oil and gas revenues | $ | 395,921 | $ | 218,633 | $ | 759,592 | $ | 455,885 | |||||||
Purchased oil and gas sales | 57,578 | 8,091 | 75,615 | 35,722 | |||||||||||
Midstream revenues | 29,342 | 15,566 | 57,264 | 30,172 | |||||||||||
Well services revenues | 18,496 | 11,801 | 30,082 | 17,428 | |||||||||||
Total revenues | 501,337 | 254,091 | 922,553 | 539,207 | |||||||||||
Operating expenses | |||||||||||||||
Lease operating expenses | 44,141 | 44,665 | 88,922 | 88,537 | |||||||||||
Midstream operating expenses | 7,688 | 3,263 | 15,673 | 6,590 | |||||||||||
Well services operating expenses | 13,560 | 9,010 | 20,947 | 13,570 | |||||||||||
Marketing, transportation and gathering expenses | 22,833 | 12,039 | 43,846 | 22,990 | |||||||||||
Purchased oil and gas expenses | 57,165 | 7,980 | 75,163 | 35,982 | |||||||||||
Production taxes | 34,026 | 18,971 | 65,026 | 39,270 | |||||||||||
Depreciation, depletion and amortization | 153,570 | 125,291 | 302,835 | 251,957 | |||||||||||
Exploration expenses | 617 | 1,667 | 1,386 | 3,156 | |||||||||||
Impairment | 384,135 | 3,200 | 384,228 | 5,882 | |||||||||||
General and administrative expenses | 28,230 | 22,626 | 56,170 | 45,802 | |||||||||||
Total operating expenses | 745,965 | 248,712 | 1,054,196 | 513,736 | |||||||||||
Gain on sale of properties | 1,954 | — | 1,954 | — | |||||||||||
Operating income (loss) | (242,674 | ) | 5,379 | (129,689 | ) | 25,471 | |||||||||
Other income (expense) | |||||||||||||||
Net gain (loss) on derivative instruments | (120,285 | ) | 50,532 | (191,401 | ) | 106,607 | |||||||||
Interest expense, net of capitalized interest | (40,910 | ) | (36,838 | ) | (78,056 | ) | (73,159 | ) | |||||||
Loss on extinguishment of debt | (13,651 | ) | — | (13,651 | ) | — | |||||||||
Other income (expense) | 218 | (166 | ) | 35 | (150 | ) | |||||||||
Total other income (expense) | (174,628 | ) | 13,528 | (283,073 | ) | 33,298 | |||||||||
Income (loss) before income taxes | (417,302 | ) | 18,907 | (412,762 | ) | 58,769 | |||||||||
Income tax benefit (expense) | 101,001 | (2,339 | ) | 100,173 | (18,376 | ) | |||||||||
Net income (loss) including non-controlling interests | (316,301 | ) | 16,568 | (312,589 | ) | 40,393 | |||||||||
Less: Net income attributable to non-controlling interests | 3,903 | — | 7,025 | — | |||||||||||
Net income (loss) attributable to Oasis | $ | (320,204 | ) | $ | 16,568 | $ | (319,614 | ) | $ | 40,393 | |||||
Earnings (loss) attributable to Oasis per share: | |||||||||||||||
Basic (Note 15) | $ | (1.02 | ) | $ | 0.07 | $ | (1.06 | ) | $ | 0.17 | |||||
Diluted (Note 15) | (1.02 | ) | 0.07 | (1.06 | ) | 0.17 | |||||||||
Weighted average shares outstanding: | |||||||||||||||
Basic (Note 15) | 313,072 | 233,283 | 301,652 | 233,176 | |||||||||||
Diluted (Note 15) | 313,072 | 234,917 | 301,652 | 236,281 |
Attributable to Oasis | |||||||||||||||||||||||||||||
Common Stock | Treasury Stock | Additional Paid-in Capital | Retained Earnings | Non-controlling Interests | Total Stockholders’ Equity | ||||||||||||||||||||||||
Shares | Amount | Shares | Amount | ||||||||||||||||||||||||||
(In thousands) | |||||||||||||||||||||||||||||
Balance at December 31, 2017 | 269,295 | $ | 2,668 | 1,332 | $ | (22,179 | ) | $ | 2,677,217 | $ | 717,985 | $ | 137,888 | $ | 3,513,579 | ||||||||||||||
Permian Basin Acquisition issuance | 46,000 | 460 | — | — | 370,760 | — | — | 371,220 | |||||||||||||||||||||
Other (2017 issuance of common stock and Oasis Midstream common units) | — | — | — | — | 38 | — | (125 | ) | (87 | ) | |||||||||||||||||||
Equity-based compensation | 3,383 | 26 | — | — | 14,846 | — | 166 | 15,038 | |||||||||||||||||||||
Distributions to non-controlling interest owners | — | — | — | — | — | — | (6,846 | ) | (6,846 | ) | |||||||||||||||||||
Treasury stock - tax withholdings | (693 | ) | — | 693 | (6,064 | ) | — | — | — | (6,064 | ) | ||||||||||||||||||
Net income (loss) | — | — | — | — | — | (319,614 | ) | 7,025 | (312,589 | ) | |||||||||||||||||||
Balance at June 30, 2018 | 317,985 | $ | 3,154 | 2,025 | $ | (28,243 | ) | $ | 3,062,861 | $ | 398,371 | $ | 138,108 | $ | 3,574,251 |
Six Months Ended June 30, | |||||||
2018 | 2017 | ||||||
(In thousands) | |||||||
Cash flows from operating activities: | |||||||
Net income (loss) including non-controlling interests | $ | (312,589 | ) | $ | 40,393 | ||
Adjustments to reconcile net income (loss) including non-controlling interests to net cash provided by operating activities: | |||||||
Depreciation, depletion and amortization | 302,835 | 251,957 | |||||
Loss on extinguishment of debt | 13,651 | — | |||||
Gain on sale of properties | (1,954 | ) | — | ||||
Impairment | 384,228 | 5,882 | |||||
Deferred income taxes | (100,293 | ) | 18,376 | ||||
Derivative instruments | 191,401 | (106,607 | ) | ||||
Equity-based compensation expenses | 14,130 | 13,823 | |||||
Deferred financing costs amortization and other | 10,518 | 8,871 | |||||
Working capital and other changes: | |||||||
Change in accounts receivable, net | (5,866 | ) | (13,743 | ) | |||
Change in inventory | (4,721 | ) | (1,007 | ) | |||
Change in prepaid expenses | 573 | (264 | ) | ||||
Change in other current assets | 111 | 280 | |||||
Change in long-term inventory and other assets | (381 | ) | (8,768 | ) | |||
Change in accounts payable, interest payable and accrued liabilities | 40,849 | 11,158 | |||||
Change in other current liabilities | — | (10,490 | ) | ||||
Change in other liabilities | (476 | ) | — | ||||
Net cash provided by operating activities | 532,016 | 209,861 | |||||
Cash flows from investing activities: | |||||||
Capital expenditures | (536,959 | ) | (252,461 | ) | |||
Acquisitions | (524,255 | ) | — | ||||
Proceeds from sale of properties | 2,236 | 4,000 | |||||
Derivative settlements | (96,823 | ) | (8,899 | ) | |||
Advances from joint interest partners | (933 | ) | (1,781 | ) | |||
Net cash used in investing activities | (1,156,734 | ) | (259,141 | ) | |||
Cash flows from financing activities: | |||||||
Proceeds from Revolving Credit Facilities | 1,933,000 | 484,000 | |||||
Principal payments on Revolving Credit Facilities | (1,265,000 | ) | (429,000 | ) | |||
Repurchase of senior unsecured notes | (423,143 | ) | — | ||||
Proceeds from issuance of senior unsecured notes | 400,000 | — | |||||
Deferred financing costs | (6,790 | ) | — | ||||
Purchases of treasury stock | (6,064 | ) | (5,451 | ) | |||
Distributions to non-controlling interests | (6,846 | ) | — | ||||
Other | (87 | ) | (55 | ) | |||
Net cash provided by financing activities | 625,070 | 49,494 | |||||
Increase in cash and cash equivalents | 352 | 214 | |||||
Cash and cash equivalents: | |||||||
Beginning of period | 16,720 | 11,226 | |||||
End of period | $ | 17,072 | $ | 11,440 | |||
Supplemental non-cash transactions: | |||||||
Change in accrued capital expenditures | $ | 90,040 | $ | 19,017 | |||
Change in asset retirement obligations | 5,407 | 1,759 | |||||
Issuance of shares in connection with the Permian Basin Acquisition | 371,220 | — | |||||
Installment notes from acquisition | — | 4,875 |
Exploration and Production Revenues | |||||||||||||||
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
(In thousands) | |||||||||||||||
Oil revenues | $ | 361,254 | $ | 194,005 | $ | 684,640 | $ | 402,599 | |||||||
Purchased oil sales | 53,707 | 7,905 | 71,695 | 35,536 | |||||||||||
Natural gas revenues | 23,059 | 15,119 | 50,021 | 34,652 | |||||||||||
Purchased gas sales | 496 | 186 | 545 | 186 | |||||||||||
NGL revenues | 11,608 | 9,509 | 24,931 | 18,634 | |||||||||||
Total exploration and production revenues | $ | 450,124 | $ | 226,724 | $ | 831,832 | $ | 491,607 |
Midstream Revenues(1) | |||||||||||||||
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
(In thousands) | |||||||||||||||
Crude oil and natural gas revenues | $ | 17,907 | $ | 3,187 | $ | 35,936 | $ | 11,739 | |||||||
Purchased oil sales | 3,375 | — | 3,375 | — | |||||||||||
Water revenues | 11,435 | 12,379 | 21,328 | 18,433 | |||||||||||
Total midstream revenues | $ | 32,717 | $ | 15,566 | $ | 60,639 | $ | 30,172 |
(1) | Represents midstream revenues excluding all intercompany revenues for work performed by the midstream services business segment for Oasis’s working interests that are eliminated in consolidation and are therefore not included in midstream services revenues. |
Well Services Revenues(1) | |||||||||||||||
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
(In thousands) | |||||||||||||||
Hydraulic fracturing service revenues | $ | 17,390 | $ | 11,057 | $ | 27,816 | $ | 16,213 | |||||||
Equipment rental revenues | 1,106 | 744 | 2,266 | 1,215 | |||||||||||
Total well services revenues | $ | 18,496 | $ | 11,801 | $ | 30,082 | $ | 17,428 |
(1) | Represents well services revenues excluding all intercompany revenues for work performed by the well services business segment for Oasis’s working interests that are eliminated in consolidation and are therefore not included in well services revenues. |
June 30, 2018 | December 31, 2017 | ||||||
(In thousands) | |||||||
Inventory | |||||||
Crude oil inventory | $ | 7,000 | $ | 10,427 | |||
Equipment and materials | 16,222 | 8,940 | |||||
Total inventory | $ | 23,222 | $ | 19,367 | |||
Long-term inventory | |||||||
Linefill in third-party pipelines | $ | 12,505 | $ | 12,200 | |||
Long-term inventory | $ | 12,505 | $ | 12,200 | |||
Total | $ | 35,727 | $ | 31,567 |
June 30, 2018 | December 31, 2017 | ||||||
(In thousands) | |||||||
Accounts receivable, net | |||||||
Trade accounts | $ | 250,740 | $ | 233,660 | |||
Joint interest accounts | 79,304 | 73,588 | |||||
Other accounts | 48,982 | 57,905 | |||||
Total | 379,026 | 365,153 | |||||
Allowance for doubtful accounts | (946 | ) | (1,573 | ) | |||
Total accounts receivable, net | $ | 378,080 | $ | 363,580 |
Fair value at June 30, 2018 | |||||||||||||||
Level 1 | Level 2 | Level 3 | Total | ||||||||||||
(In thousands) | |||||||||||||||
Assets: | |||||||||||||||
Money market funds | $ | 143 | $ | — | $ | — | $ | 143 | |||||||
Commodity derivative instruments (see Note 7) | — | 25 | — | 25 | |||||||||||
Total assets | $ | 143 | $ | 25 | $ | — | $ | 168 | |||||||
Liabilities: | |||||||||||||||
Commodity derivative instruments (see Note 7) | $ | — | $ | 229,817 | $ | — | $ | 229,817 | |||||||
Total liabilities | $ | — | $ | 229,817 | $ | — | $ | 229,817 |
Fair value at December 31, 2017 | |||||||||||||||
Level 1 | Level 2 | Level 3 | Total | ||||||||||||
(In thousands) | |||||||||||||||
Assets: | |||||||||||||||
Money market funds | $ | 142 | $ | — | $ | — | $ | 142 | |||||||
Commodity derivative instruments (see Note 7) | — | 353 | — | 353 | |||||||||||
Total assets | $ | 142 | $ | 353 | $ | — | $ | 495 | |||||||
Liabilities: | |||||||||||||||
Commodity derivative instruments (see Note 7) | $ | — | $ | 135,567 | $ | — | $ | 135,567 | |||||||
Total liabilities | $ | — | $ | 135,567 | $ | — | $ | 135,567 |
Commodity | Settlement Period | Derivative Instrument | Index | Volumes | Weighted Average Prices | Fair Value Asset (Liability) | ||||||||||||||||||||||||
Fixed Price Swaps | Basis Swaps | Sub-Floor | Floor | Ceiling | ||||||||||||||||||||||||||
(In thousands) | ||||||||||||||||||||||||||||||
Crude oil | 2018 | Fixed price swaps | NYMEX WTI | 7,745,000 | Bbl | $ | 53.02 | $ | (133,352 | ) | ||||||||||||||||||||
Crude oil | 2018 | Basis swaps | NYMEX WTI-ICE BRENT | 153,000 | Bbl | $ | (10.50 | ) | 471 | |||||||||||||||||||||
Crude oil | 2018 | Two-way collar | NYMEX WTI | 549,000 | Bbl | $ | 48.67 | $ | 53.07 | (9,479 | ) | |||||||||||||||||||
Crude oil | 2019 | Fixed price swaps | NYMEX WTI | 5,613,000 | Bbl | $ | 53.33 | (69,121 | ) | |||||||||||||||||||||
Crude oil | 2019 | Basis swaps | NYMEX WTI-ICE BRENT | 212,000 | Bbl | $ | (10.50 | ) | 353 | |||||||||||||||||||||
Crude oil | 2019 | Two-way collar | NYMEX WTI | 761,000 | Bbl | $ | 52.03 | $ | 69.03 | (2,500 | ) | |||||||||||||||||||
Crude oil | 2019 | Three-way collar | NYMEX WTI | 3,368,000 | Bbl | $ | 40.54 | $ | 51.03 | $ | 68.68 | (12,060 | ) | |||||||||||||||||
Crude oil | 2020 | Fixed price swaps | NYMEX WTI | 403,000 | Bbl | $ | 53.47 | (3,557 | ) | |||||||||||||||||||||
Crude oil | 2020 | Two-way collar | NYMEX WTI | 62,000 | Bbl | $ | 52.50 | $ | 71.25 | (30 | ) | |||||||||||||||||||
Crude oil | 2020 | Three-way collar | NYMEX WTI | 279,000 | Bbl | $ | 40.00 | $ | 50.56 | $ | 67.80 | (876 | ) | |||||||||||||||||
Natural gas | 2018 | Fixed price swaps | NYMEX HH | 6,440,000 | MMbtu | $ | 3.02 | 403 | ||||||||||||||||||||||
Natural gas | 2019 | Fixed price swaps | NYMEX HH | 1,353,000 | MMbtu | $ | 2.96 | (44 | ) | |||||||||||||||||||||
$ | (229,792 | ) |
Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||||
Statements of Operations Location | 2018 | 2017 | 2018 | 2017 | ||||||||||||
(In thousands) | ||||||||||||||||
Net gain (loss) on derivative instruments | $ | (120,285 | ) | $ | 50,532 | $ | (191,401 | ) | $ | 106,607 |
June 30, 2018 | ||||||||||||||
Commodity | Balance Sheet Location | Gross Recognized Asset/Liabilities | Gross Amount Offset | Net Recognized Fair Value Asset/Liabilities | ||||||||||
(In thousands) | ||||||||||||||
Derivatives assets: | ||||||||||||||
Commodity contracts | Derivative instruments — non-current assets | $ | 25 | $ | — | $ | 25 | |||||||
Total derivatives assets | $ | 25 | $ | — | $ | 25 | ||||||||
Derivatives liabilities: | ||||||||||||||
Commodity contracts | Derivative instruments — current liabilities | $ | 198,306 | $ | (3,496 | ) | $ | 194,810 | ||||||
Commodity contracts | Derivative instruments — non-current liabilities | 40,661 | (5,654 | ) | 35,007 | |||||||||
Total derivatives liabilities | $ | 238,967 | $ | (9,150 | ) | $ | 229,817 | |||||||
December 31, 2017 | ||||||||||||||
Commodity | Balance Sheet Location | Gross Recognized Assets/Liabilities | Gross Amount Offset | Net Recognized Fair Value Assets/Liabilities | ||||||||||
(In thousands) | ||||||||||||||
Derivatives assets: | ||||||||||||||
Commodity contracts | Derivative instruments — current assets | $ | 344 | $ | — | $ | 344 | |||||||
Commodity contracts | Derivative instruments — non-current assets | 9 | — | 9 | ||||||||||
Total derivatives assets | $ | 353 | $ | — | $ | 353 | ||||||||
Derivatives liabilities: | ||||||||||||||
Commodity contracts | Derivative instruments — current liabilities | $ | 117,629 | $ | (1,913 | ) | $ | 115,716 | ||||||
Commodity contracts | Derivative instruments — non-current liabilities | 20,035 | (184 | ) | 19,851 | |||||||||
Total derivatives liabilities | $ | 137,664 | $ | (2,097 | ) | $ | 135,567 |
June 30, 2018 | December 31, 2017 | ||||||
(In thousands) | |||||||
Proved oil and gas properties(1) | $ | 7,340,228 | $ | 7,058,782 | |||
Less: Accumulated depreciation, depletion, amortization and impairment | (2,532,668 | ) | (2,395,153 | ) | |||
Proved oil and gas properties, net | 4,807,560 | 4,663,629 | |||||
Unproved oil and gas properties | 1,084,606 | 780,173 | |||||
Other property and equipment | 1,024,104 | 868,746 | |||||
Less: Accumulated depreciation | (159,029 | ) | (139,062 | ) | |||
Other property and equipment, net | 865,075 | 729,684 | |||||
Total property, plant and equipment, net | $ | 6,757,241 | $ | 6,173,486 |
(1) | Included in the Company’s proved oil and gas properties are estimates of future asset retirement costs of $44.0 million and $39.9 million at June 30, 2018 and December 31, 2017, respectively. |
At February 14, 2018 | |||
(In thousands) | |||
Consideration paid to Forge Energy: | |||
Cash | $ | 549,770 | |
Common stock: 46,000,000 shares issued | 371,220 | ||
$ | 920,990 | ||
Recognized amounts of identifiable assets acquired and liabilities assumed: | |||
Proved developed properties | $ | 110,735 | |
Proved undeveloped properties | 167,170 | ||
Unproved lease acquisition costs | 644,040 | ||
Inventory | 293 | ||
Intangible assets | 1,000 | ||
Asset retirement obligations | (2,248 | ) | |
$ | 920,990 |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
(In thousands) | (In thousands) | ||||||||||||||
Unaudited | Unaudited | ||||||||||||||
Revenues | $ | 501,337 | $ | 262,991 | $ | 928,082 | $ | 553,073 | |||||||
Net income attributable to Oasis | (320,204 | ) | 23,877 | (315,073 | ) | 51,785 | |||||||||
Net income attributable to Oasis per share: | |||||||||||||||
Basic | $ | (1.02 | ) | $ | 0.09 | $ | (1.01 | ) | $ | 0.19 | |||||
Diluted | (1.02 | ) | 0.08 | (1.00 | ) | 0.18 |
June 30, 2018 | |||
(in thousands) | |||
Assets: | |||
Accounts receivable, net | $ | 273 | |
Oil and gas properties (successful efforts method) | 179,921 | ||
Less: accumulated depreciation, depletion, amortization and impairment | (61,652 | ) | |
Total assets held for sale, net | $ | 118,542 | |
Liabilities: | |||
Asset retirement obligations | 1,605 | ||
Total liabilities held for sale | $ | 1,605 |
June 30, 2018 | |||
(in thousands) | |||
Assets: | |||
Accounts receivable, net | $ | 601 | |
Inventory | 866 | ||
Oil and gas properties (successful efforts method) | 336,604 | ||
Other property and equipment | 11,865 | ||
Less: accumulated depreciation, depletion, amortization and impairment | (218,360 | ) | |
Total assets held for sale, net | $ | 131,576 | |
Liabilities: | |||
Asset retirement obligations | 2,576 | ||
Total liabilities held for sale | $ | 2,576 |
June 30, 2018 | December 31, 2017 | ||||||
(In thousands) | |||||||
Oasis Credit Facility | $ | 651,000 | $ | 70,000 | |||
OMP Credit Facility | 165,000 | 78,000 | |||||
Senior unsecured notes | |||||||
7.25% senior unsecured notes due February 1, 2019 | — | 54,275 | |||||
6.50% senior unsecured notes due November 1, 2021 | 71,835 | 395,501 | |||||
6.875% senior unsecured notes due March 15, 2022 | 901,480 | 937,080 | |||||
6.875% senior unsecured notes due January 15, 2023 | 366,094 | 366,094 | |||||
6.25% senior unsecured notes due May 1, 2026 | 400,000 | — | |||||
2.625% senior unsecured convertible notes due September 15, 2023 | 300,000 | 300,000 | |||||
Total principal of senior unsecured notes | 2,039,409 | 2,052,950 | |||||
Less: unamortized deferred financing costs on senior unsecured notes | (22,889 | ) | (22,956 | ) | |||
Less: unamortized debt discount on senior unsecured convertible notes | (75,039 | ) | (80,388 | ) | |||
Total long-term debt | $ | 2,757,481 | $ | 2,097,606 |
(In thousands) | |||
Balance at December 31, 2017 | $ | 48,799 | |
Liabilities incurred during period | 4,008 | ||
Liabilities settled during period | (1 | ) | |
Accretion expense during period(1) | 1,314 | ||
Revisions to estimates | 84 | ||
Liabilities held for sale(2) | (4,167 | ) | |
Balance at June 30, 2018 | $ | 50,037 |
(1) | Included in depreciation, depletion and amortization on the Company’s Condensed Consolidated Statements of Operations. |
(2) | Represents ARO related to the properties held for sale as of June 30, 2018 (see Note 10 - Divestitures and Assets Held for Sale). |
Risk-free interest rate | 2.08% - 2.31% | |
Oasis volatility | 72.88 | % |
Oasis initial value | $8.82 | |
Oasis stock price on date of grant | $9.27 |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||
(In thousands) | |||||||||||
Basic weighted average common shares outstanding | 313,072 | 233,283 | 301,652 | 233,176 | |||||||
Dilutive effect of restricted stock awards and PSUs(1) | — | 1,634 | — | 3,105 | |||||||
Diluted weighted average common shares outstanding | 313,072 | 234,917 | 301,652 | 236,281 |
(1) | No unvested stock awards were included in computing earnings (loss) per share for the three and six months ended June 30, 2018 because the effect was anti-dilutive. |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||
(In thousands) | |||||||||||
Restricted stock awards and PSUs | 7,515 | 4,369 | 7,440 | 2,957 |
Exploration and Production | Midstream Services | Well Services | Eliminations | Consolidated | |||||||||||||||
(In thousands) | |||||||||||||||||||
Three months ended June 30, 2018: | |||||||||||||||||||
Revenues from non-affiliates | $ | 450,124 | $ | 32,717 | $ | 18,496 | $ | — | $ | 501,337 | |||||||||
Inter-segment revenues | — | 39,710 | 41,418 | (81,128 | ) | — | |||||||||||||
Total revenues | 450,124 | 72,427 | 59,914 | (81,128 | ) | 501,337 | |||||||||||||
Operating income (loss) | (280,090 | ) | 37,894 | 8,028 | (8,506 | ) | (242,674 | ) | |||||||||||
Other income (expense) | (174,572 | ) | (79 | ) | 23 | — | (174,628 | ) | |||||||||||
Income (loss) before income taxes including non-controlling interests | $ | (454,662 | ) | $ | 37,815 | $ | 8,051 | $ | (8,506 | ) | $ | (417,302 | ) | ||||||
Three months ended June 30, 2017: | |||||||||||||||||||
Revenues from non-affiliates | $ | 226,724 | $ | 15,566 | $ | 11,801 | $ | — | $ | 254,091 | |||||||||
Inter-segment revenues | — | 24,746 | 21,650 | (46,396 | ) | — | |||||||||||||
Total revenues | 226,724 | 40,312 | 33,451 | (46,396 | ) | 254,091 | |||||||||||||
Operating income (loss) | (17,425 | ) | 23,103 | 1,950 | (2,249 | ) | 5,379 | ||||||||||||
Other income | 13,525 | 3 | — | — | 13,528 | ||||||||||||||
Income (loss) before income taxes | $ | (3,900 | ) | $ | 23,106 | $ | 1,950 | $ | (2,249 | ) | $ | 18,907 | |||||||
Six months ended June 30, 2018: | |||||||||||||||||||
Revenues from non-affiliates | $ | 831,832 | $ | 60,639 | $ | 30,082 | $ | — | $ | 922,553 | |||||||||
Inter-segment revenues | — | 76,350 | 74,721 | (151,071 | ) | — | |||||||||||||
Total revenues | 831,832 | 136,989 | 104,803 | (151,071 | ) | 922,553 | |||||||||||||
Operating income (loss) | (200,130 | ) | 70,132 | 16,178 | (15,869 | ) | (129,689 | ) | |||||||||||
Other expense | (282,717 | ) | (336 | ) | (20 | ) | — | (283,073 | ) | ||||||||||
Income (loss) before income taxes including non-controlling interests | $ | (482,847 | ) | $ | 69,796 | $ | 16,158 | $ | (15,869 | ) | $ | (412,762 | ) | ||||||
Six months ended June 30, 2017: | |||||||||||||||||||
Revenues from non-affiliates | $ | 491,607 | $ | 30,172 | $ | 17,428 | $ | — | $ | 539,207 | |||||||||
Inter-segment revenues | — | 47,781 | 37,003 | (84,784 | ) | — | |||||||||||||
Total revenues | 491,607 | 77,953 | 54,431 | (84,784 | ) | 539,207 | |||||||||||||
Operating income (loss) | (16,456 | ) | 43,865 | (1,641 | ) | (297 | ) | 25,471 | |||||||||||
Other income | 33,292 | 2 | 4 | — | 33,298 | ||||||||||||||
Income (loss) before income taxes | $ | 16,836 | $ | 43,867 | $ | (1,637 | ) | $ | (297 | ) | $ | 58,769 | |||||||
At June 30, 2018: | |||||||||||||||||||
Property, plant and equipment, net | $ | 6,129,083 | $ | 786,246 | $ | 44,319 | $ | (202,407 | ) | $ | 6,757,241 | ||||||||
Total assets(1) | 6,767,902 | 816,422 | 48,419 | (167,408 | ) | 7,465,335 | |||||||||||||
At December 31, 2017: | |||||||||||||||||||
Property, plant and equipment, net | $ | 5,663,323 | $ | 649,923 | $ | 46,779 | $ | (186,539 | ) | $ | 6,173,486 | ||||||||
Total assets(1) | 6,050,255 | 663,614 | 52,800 | (151,539 | ) | 6,615,130 |
(1) | Intercompany receivables (payables) for all segments were reclassified to capital contributions from (distributions to) parent and not included in total assets. |
June 30, 2018 | |||||||||||||||||||
Parent/ Issuer | Combined Guarantor Subsidiaries | Combined Non-guarantor Subsidiaries | Intercompany Eliminations | Consolidated | |||||||||||||||
(In thousands, except share data) | |||||||||||||||||||
ASSETS | |||||||||||||||||||
Current assets | |||||||||||||||||||
Cash and cash equivalents | $ | 175 | $ | 14,148 | $ | 2,749 | $ | — | $ | 17,072 | |||||||||
Accounts receivable, net | — | 375,323 | 2,757 | — | 378,080 | ||||||||||||||
Accounts receivable - affiliates | 328,675 | 50,210 | 54,533 | (433,418 | ) | — | |||||||||||||
Inventory | — | 23,130 | 92 | — | 23,222 | ||||||||||||||
Prepaid expenses | 209 | 5,307 | 358 | — | 5,874 | ||||||||||||||
Intangible assets, net | — | 625 | — | — | 625 | ||||||||||||||
Other current assets | — | 82 | — | — | 82 | ||||||||||||||
Total current assets | 329,059 | 468,825 | 60,489 | (433,418 | ) | 424,955 | |||||||||||||
Property, plant and equipment | |||||||||||||||||||
Oil and gas properties (successful efforts method) | — | 8,431,500 | — | (6,666 | ) | 8,424,834 | |||||||||||||
Other property and equipment | — | 210,233 | 813,881 | (10 | ) | 1,024,104 | |||||||||||||
Less: accumulated depreciation, depletion, amortization and impairment | — | (2,644,313 | ) | (47,384 | ) | — | (2,691,697 | ) | |||||||||||
Total property, plant and equipment, net | — | 5,997,420 | 766,497 | (6,676 | ) | 6,757,241 | |||||||||||||
Assets held for sale, net | — | 250,118 | — | — | 250,118 | ||||||||||||||
Investments in and advances to subsidiaries | 4,925,931 | 453,075 | — | (5,379,006 | ) | — | |||||||||||||
Derivative instruments | — | 25 | — | — | 25 | ||||||||||||||
Deferred income taxes | 203,764 | — | — | (203,764 | ) | — | |||||||||||||
Long-term inventory | — | 12,505 | — | — | 12,505 | ||||||||||||||
Other assets | — | 18,710 | 1,781 | — | 20,491 | ||||||||||||||
Total assets | $ | 5,458,754 | $ | 7,200,678 | $ | 828,767 | $ | (6,022,864 | ) | $ | 7,465,335 | ||||||||
LIABILITIES AND STOCKHOLDERS’ EQUITY | |||||||||||||||||||
Current liabilities | |||||||||||||||||||
Accounts payable | $ | — | $ | 26,861 | $ | 3,127 | $ | — | $ | 29,988 | |||||||||
Accounts payable - affiliates | 40,469 | 383,208 | 9,741 | (433,418 | ) | — | |||||||||||||
Revenues and production taxes payable | — | 245,924 | 291 | — | 246,215 | ||||||||||||||
Accrued liabilities | 68 | 262,553 | 57,887 | — | 320,508 | ||||||||||||||
Accrued interest payable | 36,192 | 674 | 105 | — | 36,971 | ||||||||||||||
Derivative instruments | — | 194,810 | — | — | 194,810 | ||||||||||||||
Advances from joint interest partners | — | 3,983 | — | — | 3,983 | ||||||||||||||
Other current liabilities | — | 40 | — | — | 40 | ||||||||||||||
Total current liabilities | 76,729 | 1,118,053 | 71,151 | (433,418 | ) | 832,515 | |||||||||||||
Long-term debt | 1,941,481 | 651,000 | 165,000 | — | 2,757,481 | ||||||||||||||
Deferred income taxes | — | 409,392 | — | (203,764 | ) | 205,628 | |||||||||||||
Asset retirement obligations | — | 48,310 | 1,433 | — | 49,743 | ||||||||||||||
Liabilities held for sale | — | 4,181 | — | — | 4,181 | ||||||||||||||
Derivative instruments | — | 35,007 | — | — | 35,007 | ||||||||||||||
Other liabilities | — | 6,529 | — | — | 6,529 | ||||||||||||||
Total liabilities | 2,018,210 | 2,272,472 | 237,584 | (637,182 | ) | 3,891,084 | |||||||||||||
Stockholders’ equity | |||||||||||||||||||
Capital contributions from affiliates | — | 3,642,698 | 213,179 | (3,855,877 | ) | — | |||||||||||||
Common stock, $0.01 par value: 450,000,000 shares authorized; 320,010,534 shares issued and 317,985,056 shares outstanding | 3,154 | — | — | — | 3,154 | ||||||||||||||
Treasury stock, at cost: 2,025,478 shares | (28,243 | ) | — | — | — | (28,243 | ) | ||||||||||||
Additional paid-in-capital | 3,062,861 | 9,067 | — | (9,067 | ) | 3,062,861 | |||||||||||||
Retained earnings | 402,772 | 1,138,333 | 34,037 | (1,176,771 | ) | 398,371 | |||||||||||||
Oasis share of stockholders’ equity | 3,440,544 | 4,790,098 | 247,216 | (5,041,715 | ) | 3,436,143 | |||||||||||||
Non-controlling interests | — | 138,108 | 343,967 | (343,967 | ) | 138,108 | |||||||||||||
Total stockholders’ equity | 3,440,544 | 4,928,206 | 591,183 | (5,385,682 | ) | 3,574,251 | |||||||||||||
Total liabilities and stockholders’ equity | $ | 5,458,754 | $ | 7,200,678 | $ | 828,767 | $ | (6,022,864 | ) | $ | 7,465,335 |
December 31, 2017 | |||||||||||||||||||
Parent/ Issuer | Combined Guarantor Subsidiaries | Combined Non-guarantor Subsidiaries | Intercompany Eliminations | Consolidated | |||||||||||||||
(In thousands, except share data) | |||||||||||||||||||
ASSETS | |||||||||||||||||||
Current assets | |||||||||||||||||||
Cash and cash equivalents | $ | 178 | $ | 15,659 | $ | 883 | $ | — | $ | 16,720 | |||||||||
Accounts receivable, net | — | 362,746 | 834 | — | 363,580 | ||||||||||||||
Accounts receivable - affiliates | 425,668 | 46,020 | 85,818 | (557,506 | ) | — | |||||||||||||
Inventory | — | 19,367 | — | — | 19,367 | ||||||||||||||
Prepaid expenses | 267 | 6,586 | 778 | — | 7,631 | ||||||||||||||
Derivative instruments | — | 344 | — | — | 344 | ||||||||||||||
Other current assets | — | 193 | — | — | 193 | ||||||||||||||
Total current assets | 426,113 | 450,915 | 88,313 | (557,506 | ) | 407,835 | |||||||||||||
Property, plant and equipment | |||||||||||||||||||
Oil and gas properties (successful efforts method) | — | 7,840,921 | — | (1,966 | ) | 7,838,955 | |||||||||||||
Other property and equipment | — | 214,818 | 653,928 | — | 868,746 | ||||||||||||||
Less: accumulated depreciation, depletion, amortization and impairment | — | (2,499,867 | ) | (34,348 | ) | — | (2,534,215 | ) | |||||||||||
Total property, plant and equipment, net | — | 5,555,872 | 619,580 | (1,966 | ) | 6,173,486 | |||||||||||||
Investments in and advances to subsidiaries | 4,790,976 | 422,132 | — | (5,213,108 | ) | — | |||||||||||||
Derivative instruments | — | 9 | — | — | 9 | ||||||||||||||
Deferred income taxes | 183,568 | — | — | (183,568 | ) | — | |||||||||||||
Long-term inventory | — | 12,200 | — | — | 12,200 | ||||||||||||||
Other assets | — | 19,587 | 2,013 | — | 21,600 | ||||||||||||||
Total assets | $ | 5,400,657 | $ | 6,460,715 | $ | 709,906 | $ | (5,956,148 | ) | $ | 6,615,130 | ||||||||
LIABILITIES AND STOCKHOLDERS’ EQUITY | |||||||||||||||||||
Current liabilities | |||||||||||||||||||
Accounts payable | $ | — | $ | 13,370 | $ | — | $ | — | $ | 13,370 | |||||||||
Accounts payable - affiliates | 34,382 | 511,486 | 11,638 | (557,506 | ) | — | |||||||||||||
Revenues and production taxes payable | — | 213,995 | — | — | 213,995 | ||||||||||||||
Accrued liabilities | 216 | 177,446 | 58,818 | — | 236,480 | ||||||||||||||
Accrued interest payable | 38,796 | 53 | 114 | — | 38,963 | ||||||||||||||
Derivative instruments | — | 115,716 | — | — | 115,716 | ||||||||||||||
Advances from joint interest partners | — | 4,916 | — | — | 4,916 | ||||||||||||||
Other current liabilities | — | 40 | — | — | 40 | ||||||||||||||
Total current liabilities | 73,394 | 1,037,022 | 70,570 | (557,506 | ) | 623,480 | |||||||||||||
Long-term debt | 1,949,606 | 70,000 | 78,000 | — | 2,097,606 | ||||||||||||||
Deferred income taxes | — | 489,489 | — | (183,568 | ) | 305,921 | |||||||||||||
Asset retirement obligations | — | 47,195 | 1,316 | — | 48,511 | ||||||||||||||
Derivative instruments | — | 19,851 | — | — | 19,851 | ||||||||||||||
Other liabilities | — | 6,182 | — | — | 6,182 | ||||||||||||||
Total liabilities | 2,023,000 | 1,669,739 | 149,886 | (741,074 | ) | 3,101,551 | |||||||||||||
Stockholders’ equity | |||||||||||||||||||
Capital contributions from affiliates | — | 3,264,691 | 234,935 | (3,499,626 | ) | — | |||||||||||||
Common stock, $0.01 par value: 450,000,000 shares authorized; 270,627,014 shares issued and 269,295,466 shares outstanding | 2,668 | — | — | — | 2,668 | ||||||||||||||
Treasury stock, at cost: 1,331,548 shares | (22,179 | ) | — | — | — | (22,179 | ) | ||||||||||||
Additional paid-in-capital | 2,677,217 | 8,922 | — | (8,922 | ) | 2,677,217 | |||||||||||||
Retained earnings | 719,951 | 1,379,475 | 11,639 | (1,393,080 | ) | 717,985 | |||||||||||||
Oasis share of stockholders’ equity | 3,377,657 | 4,653,088 | 246,574 | (4,901,628 | ) | 3,375,691 | |||||||||||||
Non-controlling interests | — | 137,888 | 313,446 | (313,446 | ) | 137,888 | |||||||||||||
Total stockholders’ equity | 3,377,657 | 4,790,976 | 560,020 | (5,215,074 | ) | 3,513,579 | |||||||||||||
Total liabilities and stockholders’ equity | $ | 5,400,657 | $ | 6,460,715 | $ | 709,906 | $ | (5,956,148 | ) | $ | 6,615,130 |
Three Months Ended June 30, 2018 | |||||||||||||||||||
Parent/ Issuer | Combined Guarantor Subsidiaries | Combined Non-guarantor Subsidiaries | Intercompany Eliminations | Consolidated | |||||||||||||||
(In thousands) | |||||||||||||||||||
Revenues | |||||||||||||||||||
Oil and gas revenues | $ | — | $ | 395,921 | $ | — | $ | — | $ | 395,921 | |||||||||
Purchased oil and gas sales | — | 57,578 | — | — | 57,578 | ||||||||||||||
Midstream revenues | — | 917 | 66,558 | (38,133 | ) | 29,342 | |||||||||||||
Well services revenues | — | 18,496 | — | — | 18,496 | ||||||||||||||
Total revenues | — | 472,912 | 66,558 | (38,133 | ) | 501,337 | |||||||||||||
Operating expenses | |||||||||||||||||||
Lease operating expenses | — | 57,615 | — | (13,474 | ) | 44,141 | |||||||||||||
Midstream operating expenses | — | 780 | 16,334 | (9,426 | ) | 7,688 | |||||||||||||
Well services operating expenses | — | 13,560 | — | — | 13,560 | ||||||||||||||
Marketing, transportation and gathering expenses | — | 28,653 | — | (5,820 | ) | 22,833 | |||||||||||||
Purchased oil and gas expenses | — | 57,165 | — | — | 57,165 | ||||||||||||||
Production taxes | — | 34,026 | — | — | 34,026 | ||||||||||||||
Depreciation, depletion and amortization | — | 150,554 | 6,659 | (3,643 | ) | 153,570 | |||||||||||||
Exploration expenses | — | 617 | — | — | 617 | ||||||||||||||
Impairment | — | 384,135 | — | — | 384,135 | ||||||||||||||
General and administrative expenses | 7,496 | 17,954 | 5,897 | (3,117 | ) | 28,230 | |||||||||||||
Total operating expenses | 7,496 | 745,059 | 28,890 | (35,480 | ) | 745,965 | |||||||||||||
Gain on sale of properties | — | 1,954 | — | — | 1,954 | ||||||||||||||
Operating income (loss) | (7,496 | ) | (270,193 | ) | 37,668 | (2,653 | ) | (242,674 | ) | ||||||||||
Other income (expense) | |||||||||||||||||||
Equity in earnings (loss) of subsidiaries | (278,014 | ) | 37,485 | — | 240,529 | — | |||||||||||||
Net loss on derivative instruments | — | (120,285 | ) | — | — | (120,285 | ) | ||||||||||||
Interest expense, net of capitalized interest | (33,135 | ) | (7,592 | ) | (183 | ) | — | (40,910 | ) | ||||||||||
Loss on extinguishment of debt | (13,651 | ) | — | — | — | (13,651 | ) | ||||||||||||
Other income | — | 218 | — | — | 218 | ||||||||||||||
Total other expense | (324,800 | ) | (90,174 | ) | (183 | ) | 240,529 | (174,628 | ) | ||||||||||
Income (loss) before income taxes | (332,296 | ) | (360,367 | ) | 37,485 | 237,876 | (417,302 | ) | |||||||||||
Income tax benefit | 12,092 | 88,909 | — | — | 101,001 | ||||||||||||||
Net income (loss) including non-controlling interests | (320,204 | ) | (271,458 | ) | 37,485 | 237,876 | (316,301 | ) | |||||||||||
Less: Net income attributable to non-controlling interests | — | 3,903 | 25,042 | (25,042 | ) | 3,903 | |||||||||||||
Net income (loss) attributable to Oasis | $ | (320,204 | ) | $ | (275,361 | ) | $ | 12,443 | $ | 262,918 | $ | (320,204 | ) |
Three Months Ended June 30, 2017 | |||||||||||||||
Parent/ Issuer | Combined Guarantor Subsidiaries | Intercompany Eliminations | Consolidated | ||||||||||||
(In thousands) | |||||||||||||||
Revenues | |||||||||||||||
Oil and gas revenues | $ | — | $ | 218,633 | $ | — | $ | 218,633 | |||||||
Purchased oil and gas sales | — | 8,091 | — | 8,091 | |||||||||||
Midstream revenues | — | 15,566 | — | 15,566 | |||||||||||
Well services revenues | — | 11,801 | — | 11,801 | |||||||||||
Total revenues | — | 254,091 | — | 254,091 | |||||||||||
Operating expenses | |||||||||||||||
Lease operating expenses | — | 44,665 | — | 44,665 | |||||||||||
Midstream operating expenses | — | 3,263 | — | 3,263 | |||||||||||
Well services operating expenses | — | 9,010 | — | 9,010 | |||||||||||
Marketing, transportation and gathering expenses | — | 12,039 | — | 12,039 | |||||||||||
Purchased oil and gas expenses | — | 7,980 | — | 7,980 | |||||||||||
Production taxes | — | 18,971 | — | 18,971 | |||||||||||
Depreciation, depletion and amortization | — | 125,291 | — | 125,291 | |||||||||||
Exploration expenses | — | 1,667 | — | 1,667 | |||||||||||
Impairment | — | 3,200 | — | 3,200 | |||||||||||
General and administrative expenses | 7,534 | 15,092 | — | 22,626 | |||||||||||
Total operating expenses | 7,534 | 241,178 | — | 248,712 | |||||||||||
Operating income (loss) | (7,534 | ) | 12,913 | — | 5,379 | ||||||||||
Other income (expense) | |||||||||||||||
Equity in earnings of subsidiaries | 38,875 | — | (38,875 | ) | — | ||||||||||
Net gain on derivative instruments | — | 50,532 | — | 50,532 | |||||||||||
Interest expense, net of capitalized interest | (33,006 | ) | (3,832 | ) | — | (36,838 | ) | ||||||||
Other expense | — | (166 | ) | — | (166 | ) | |||||||||
Total other income | 5,869 | 46,534 | (38,875 | ) | 13,528 | ||||||||||
Income (loss) before income taxes | (1,665 | ) | 59,447 | (38,875 | ) | 18,907 | |||||||||
Income tax benefit (expense) | 18,233 | (20,572 | ) | — | (2,339 | ) | |||||||||
Net income | $ | 16,568 | $ | 38,875 | $ | (38,875 | ) | $ | 16,568 |
Six Months Ended June 30, 2018 | |||||||||||||||||||
Parent/ Issuer | Combined Guarantor Subsidiaries | Combined Non-guarantor Subsidiaries | Intercompany Eliminations | Consolidated | |||||||||||||||
(In thousands) | |||||||||||||||||||
Revenues | |||||||||||||||||||
Oil and gas revenues | $ | — | $ | 759,592 | $ | — | $ | — | $ | 759,592 | |||||||||
Purchased oil and gas sales | — | 75,615 | — | — | 75,615 | ||||||||||||||
Midstream revenues | — | 2,067 | 127,979 | (72,782 | ) | 57,264 | |||||||||||||
Well services revenues | — | 30,082 | — | — | 30,082 | ||||||||||||||
Total revenues | — | 867,356 | 127,979 | (72,782 | ) | 922,553 | |||||||||||||
Operating expenses | |||||||||||||||||||
Lease operating expenses | — | 113,314 | — | (24,392 | ) | 88,922 | |||||||||||||
Midstream operating expenses | — | 1,526 | 33,450 | (19,303 | ) | 15,673 | |||||||||||||
Well services operating expenses | — | 20,947 | — | — | 20,947 | ||||||||||||||
Marketing, transportation and gathering expenses | — | 55,325 | — | (11,479 | ) | 43,846 | |||||||||||||
Purchased oil and gas expenses | — | 75,163 | — | — | 75,163 | ||||||||||||||
Production taxes | — | 65,026 | — | — | 65,026 | ||||||||||||||
Depreciation, depletion and amortization | — | 296,781 | 13,023 | (6,969 | ) | 302,835 | |||||||||||||
Exploration expenses | — | 1,386 | — | — | 1,386 | ||||||||||||||
Impairment | — | 384,228 | — | — | 384,228 | ||||||||||||||
General and administrative expenses | 14,728 | 35,632 | 12,047 | (6,237 | ) | 56,170 | |||||||||||||
Total operating expenses | 14,728 | 1,049,328 | 58,520 | (68,380 | ) | 1,054,196 | |||||||||||||
Gain on sale of properties | — | 1,954 | — | — | 1,954 | ||||||||||||||
Operating income (loss) | (14,728 | ) | (180,018 | ) | 69,459 | (4,402 | ) | (129,689 | ) | ||||||||||
Other income (expense) | |||||||||||||||||||
Equity in earnings (loss) of subsidiaries | (245,850 | ) | 69,014 | — | 176,836 | — | |||||||||||||
Net loss on derivative instruments | — | (191,401 | ) | — | — | (191,401 | ) | ||||||||||||
Interest expense, net of capitalized interest | (65,581 | ) | (12,030 | ) | (445 | ) | — | (78,056 | ) | ||||||||||
Loss on extinguishment of debt | (13,651 | ) | — | — | — | (13,651 | ) | ||||||||||||
Other income | — | 35 | — | — | 35 | ||||||||||||||
Total other expense | (325,082 | ) | (134,382 | ) | (445 | ) | 176,836 | (283,073 | ) | ||||||||||
Income (loss) before income taxes | (339,810 | ) | (314,400 | ) | 69,014 | 172,434 | (412,762 | ) | |||||||||||
Income tax benefit | 20,196 | 79,977 | — | — | 100,173 | ||||||||||||||
Net income (loss) including non-controlling interests | (319,614 | ) | (234,423 | ) | 69,014 | 172,434 | (312,589 | ) | |||||||||||
Less: Net income attributable to non-controlling interests | — | 7,025 | 46,616 | (46,616 | ) | 7,025 | |||||||||||||
Net income (loss) attributable to Oasis | $ | (319,614 | ) | $ | (241,448 | ) | $ | 22,398 | $ | 219,050 | $ | (319,614 | ) |
Six Months Ended June 30, 2017 | |||||||||||||||
Parent/ Issuer | Combined Guarantor Subsidiaries | Intercompany Eliminations | Consolidated | ||||||||||||
(In thousands) | |||||||||||||||
Revenues | |||||||||||||||
Oil and gas revenues | $ | — | $ | 455,885 | $ | — | $ | 455,885 | |||||||
Purchased oil and gas sales | — | 35,722 | — | 35,722 | |||||||||||
Midstream revenues | — | 30,172 | — | 30,172 | |||||||||||
Well services revenues | — | 17,428 | — | 17,428 | |||||||||||
Total revenues | — | 539,207 | — | 539,207 | |||||||||||
Operating expenses | |||||||||||||||
Lease operating expenses | — | 88,537 | — | 88,537 | |||||||||||
Midstream operating expenses | — | 6,590 | — | 6,590 | |||||||||||
Well services operating expenses | — | 13,570 | — | 13,570 | |||||||||||
Marketing, transportation and gathering expenses | — | 22,990 | — | 22,990 | |||||||||||
Purchased oil and gas expenses | — | 35,982 | — | 35,982 | |||||||||||
Production taxes | — | 39,270 | — | 39,270 | |||||||||||
Depreciation, depletion and amortization | — | 251,957 | — | 251,957 | |||||||||||
Exploration expenses | — | 3,156 | — | 3,156 | |||||||||||
Impairment | — | 5,882 | — | 5,882 | |||||||||||
General and administrative expenses | 14,599 | 31,203 | — | 45,802 | |||||||||||
Total operating expenses | 14,599 | 499,137 | — | 513,736 | |||||||||||
Operating income (loss) | (14,599 | ) | 40,070 | — | 25,471 | ||||||||||
Other income (expense) | |||||||||||||||
Equity in earnings of subsidiaries | 87,978 | — | (87,978 | ) | — | ||||||||||
Net gain on derivative instruments | — | 106,607 | — | 106,607 | |||||||||||
Interest expense, net of capitalized interest | (65,857 | ) | (7,302 | ) | — | (73,159 | ) | ||||||||
Other expense | — | (150 | ) | — | (150 | ) | |||||||||
Total other income | 22,121 | 99,155 | (87,978 | ) | 33,298 | ||||||||||
Income before income taxes | 7,522 | 139,225 | (87,978 | ) | 58,769 | ||||||||||
Income tax benefit (expense) | 32,871 | (51,247 | ) | — | (18,376 | ) | |||||||||
Net income | $ | 40,393 | $ | 87,978 | $ | (87,978 | ) | $ | 40,393 |
Six Months Ended June 30, 2018 | |||||||||||||||||||
Parent/ Issuer | Combined Guarantor Subsidiaries | Combined Non-guarantor Subsidiaries | Intercompany Eliminations | Consolidated | |||||||||||||||
(In thousands) | |||||||||||||||||||
Cash flows from operating activities: | |||||||||||||||||||
Net income (loss) including non-controlling interests | $ | (319,614 | ) | $ | (234,423 | ) | $ | 69,014 | $ | 172,434 | $ | (312,589 | ) | ||||||
Adjustments to reconcile net income (loss) including non-controlling interests to net cash provided by operating activities: | |||||||||||||||||||
Equity in earnings (loss) of subsidiaries | 245,850 | (69,014 | ) | — | (176,836 | ) | — | ||||||||||||
Depreciation, depletion and amortization | — | 296,781 | 13,023 | (6,969 | ) | 302,835 | |||||||||||||
Loss on extinguishment of debt | 13,651 | — | — | — | 13,651 | ||||||||||||||
Gain on sale of properties | — | (1,954 | ) | — | — | (1,954 | ) | ||||||||||||
Impairment | — | 384,228 | — | — | 384,228 | ||||||||||||||
Deferred income taxes | (20,196 | ) | (80,097 | ) | — | — | (100,293 | ) | |||||||||||
Derivative instruments | — | 191,401 | — | — | 191,401 | ||||||||||||||
Equity-based compensation expenses | 13,340 | 624 | 166 | — | 14,130 | ||||||||||||||
Deferred financing costs amortization and other | 7,892 | 2,522 | 104 | — | 10,518 | ||||||||||||||
Working capital and other changes: | |||||||||||||||||||
Change in accounts receivable | 96,993 | (8,178 | ) | 29,407 | (124,088 | ) | (5,866 | ) | |||||||||||
Change in inventory | — | (4,629 | ) | (92 | ) | — | (4,721 | ) | |||||||||||
Change in prepaid expenses | 58 | 95 | 420 | — | 573 | ||||||||||||||
Change in other current assets | — | 111 | — | — | 111 | ||||||||||||||
Change in long-term inventory and other assets | — | (381 | ) | — | — | (381 | ) | ||||||||||||
Change in accounts payable, interest payable and accrued liabilities | 3,335 | (90,679 | ) | 4,105 | 124,088 | 40,849 | |||||||||||||
Change in other liabilities | — | (476 | ) | — | — | (476 | ) | ||||||||||||
Net cash provided by operating activities | 41,309 | 385,931 | 116,147 | (11,371 | ) | 532,016 | |||||||||||||
Cash flows from investing activities: | |||||||||||||||||||
Capital expenditures | — | (381,971 | ) | (154,988 | ) | — | (536,959 | ) | |||||||||||
Acquisitions | — | (524,255 | ) | — | — | (524,255 | ) | ||||||||||||
Proceeds from sale of properties | — | 2,236 | — | — | 2,236 | ||||||||||||||
Derivative settlements | — | (96,823 | ) | — | — | (96,823 | ) | ||||||||||||
Advances from joint interest partners | — | (933 | ) | — | — | (933 | ) | ||||||||||||
Net cash used in investing activities | — | (1,001,746 | ) | (154,988 | ) | — | (1,156,734 | ) | |||||||||||
Cash flows from financing activities: | |||||||||||||||||||
Proceeds from Revolving Credit Facilities | — | 1,820,000 | 113,000 | — | 1,933,000 | ||||||||||||||
Principal payments on Revolving Credit Facilities | — | (1,239,000 | ) | (26,000 | ) | — | (1,265,000 | ) | |||||||||||
Repurchase of senior unsecured notes | (423,143 | ) | — | — | — | (423,143 | ) | ||||||||||||
Proceeds from issuance of senior unsecured convertible notes | 400,000 | — | — | — | 400,000 | ||||||||||||||
Deferred financing costs | (6,524 | ) | (266 | ) | — | — | (6,790 | ) | |||||||||||
Purchases of treasury stock | (6,064 | ) | — | — | — | (6,064 | ) | ||||||||||||
Distributions to non-controlling interests | — | 48,911 | (55,757 | ) | — | (6,846 | ) | ||||||||||||
Investment in subsidiaries / capital contributions from parent | (5,619 | ) | (15,216 | ) | 9,464 | 11,371 | — | ||||||||||||
Other | 38 | (125 | ) | — | — | (87 | ) | ||||||||||||
Net cash provided by (used in) financing activities | (41,312 | ) | 614,304 | 40,707 | 11,371 | 625,070 | |||||||||||||
Increase (decrease) in cash and cash equivalents | (3 | ) | (1,511 | ) | 1,866 | — | 352 | ||||||||||||
Cash and cash equivalents at beginning of period | 178 | 15,659 | 883 | — | 16,720 | ||||||||||||||
Cash and cash equivalents at end of period | $ | 175 | $ | 14,148 | $ | 2,749 | $ | — | $ | 17,072 |
Six Months Ended June 30, 2017 | |||||||||||||||
Parent/ Issuer | Combined Guarantor Subsidiaries | Intercompany Eliminations | Consolidated | ||||||||||||
(In thousands) | |||||||||||||||
Cash flows from operating activities: | |||||||||||||||
Net income | $ | 40,393 | $ | 87,978 | $ | (87,978 | ) | $ | 40,393 | ||||||
Adjustments to reconcile net income to net cash provided by operating activities: | |||||||||||||||
Equity in earnings of subsidiaries | (87,978 | ) | — | 87,978 | — | ||||||||||
Depreciation, depletion and amortization | — | 251,957 | — | 251,957 | |||||||||||
Impairment | — | 5,882 | — | 5,882 | |||||||||||
Deferred income taxes | (32,871 | ) | 51,247 | — | 18,376 | ||||||||||
Derivative instruments | — | (106,607 | ) | — | (106,607 | ) | |||||||||
Equity-based compensation expenses | 13,395 | 428 | — | 13,823 | |||||||||||
Deferred financing costs amortization and other | 7,470 | 1,401 | — | 8,871 | |||||||||||
Working capital and other changes: | |||||||||||||||
Change in accounts receivable | 64,504 | (19,833 | ) | (58,414 | ) | (13,743 | ) | ||||||||
Change in inventory | — | (1,007 | ) | — | (1,007 | ) | |||||||||
Change in prepaid expenses | (389 | ) | 125 | — | (264 | ) | |||||||||
Change in other current assets | (3 | ) | 283 | — | 280 | ||||||||||
Change in long-term inventory and other assets | — | (8,768 | ) | — | (8,768 | ) | |||||||||
Change in accounts payable, interest payable and accrued liabilities | 6,185 | (53,441 | ) | 58,414 | 11,158 | ||||||||||
Change in other current liabilities | — | (10,490 | ) | — | (10,490 | ) | |||||||||
Net cash provided by operating activities | 10,706 | 199,155 | — | 209,861 | |||||||||||
Cash flows from investing activities: | |||||||||||||||
Capital expenditures | — | (252,461 | ) | — | (252,461 | ) | |||||||||
Proceeds from sale of properties | — | 4,000 | — | 4,000 | |||||||||||
Derivative settlements | — | (8,899 | ) | — | (8,899 | ) | |||||||||
Advances from joint interest partners | — | (1,781 | ) | — | (1,781 | ) | |||||||||
Net cash used in investing activities | — | (259,141 | ) | — | (259,141 | ) | |||||||||
Cash flows from financing activities: | |||||||||||||||
Proceeds from Oasis Credit Facility | — | 484,000 | — | 484,000 | |||||||||||
Principal payments on Oasis Credit Facility | — | (429,000 | ) | — | (429,000 | ) | |||||||||
Purchases of treasury stock | (5,451 | ) | — | — | (5,451 | ) | |||||||||
Investment in subsidiaries / capital contributions from parent | (5,188 | ) | 5,188 | — | — | ||||||||||
Other | (55 | ) | — | — | (55 | ) | |||||||||
Net cash provided by (used in) financing activities | (10,694 | ) | 60,188 | — | 49,494 | ||||||||||
Increase in cash and cash equivalents | 12 | 202 | — | 214 | |||||||||||
Cash and cash equivalents at beginning of period | 166 | 11,060 | — | 11,226 | |||||||||||
Cash and cash equivalents at end of period | $ | 178 | $ | 11,262 | $ | — | $ | 11,440 |
• | our business strategy; |
• | estimated future net reserves and present value thereof; |
• | timing and amount of future production of oil and natural gas; |
• | drilling and completion of wells; |
• | estimated inventory of wells remaining to be drilled and completed; |
• | costs of exploiting and developing our properties and conducting other operations; |
• | availability of drilling, completion and production equipment and materials; |
• | availability of qualified personnel; |
• | owning and operating a midstream company, including ownership interests in a master limited partnership; |
• | owning and operating a well services company; |
• | infrastructure for produced and flowback water gathering and disposal; |
• | gathering, transportation and marketing of oil and natural gas, both in the Williston and Delaware Basins and other regions in the United States; |
• | property acquisitions, including our recent acquisition of oil and gas properties in the Delaware Basin; |
• | integration and benefits of property acquisitions or the effects of such acquisitions on our cash position and levels of indebtedness; |
• | the amount, nature and timing of capital expenditures; |
• | availability and terms of capital; |
• | our financial strategy, budget, projections, execution of business plan and operating results; |
• | cash flows and liquidity; |
• | oil and natural gas realized prices; |
• | general economic conditions; |
• | operating environment, including inclement weather conditions; |
• | effectiveness of risk management activities; |
• | competition in the oil and natural gas industry; |
• | counterparty credit risk; |
• | environmental liabilities; |
• | governmental regulation and the taxation of the oil and natural gas industry; |
• | developments in oil-producing and natural gas-producing countries; |
• | technology; |
• | uncertainty regarding future operating results; |
• | plans, objectives, expectations and intentions contained in this report that are not historical; and |
• | certain factors flagged elsewhere in this Form 10-Q. |
• | commodity prices for oil and natural gas; |
• | transportation capacity; |
• | availability and cost of services; and |
• | availability of qualified personnel. |
• | We produced 79,437 barrels of oil equivalent per day (“Boepd”) in the second quarter of 2018; |
• | We completed and placed on production 37 gross (27.8 net) operated wells, including 35 gross (25.8 net) operated wells in the Williston Basin and 2 gross (2.0 net) operated wells in the Delaware Basin, in the second quarter of 2018; |
• | Our oil differentials have decreased to $2.42 off of NYMEX West Texas Intermediate crude oil index price (“NYMEX WTI”) in the second quarter of 2018, an approximate 34% decrease from the second quarter of 2017; |
• | Lease operating expenses per barrels of oil equivalent (“Boe”) decreased over 23% to $6.11 per Boe in the second quarter of 2018 compared to $7.92 per Boe in the second quarter of 2017; |
• | We entered into or closed numerous agreements to sell non-core assets since December 2017 for total proceeds of $360 million, which represent approximately 5.0 MBoepd of net production and approximately 80,000 net acres; and |
• | Net cash provided by operating activities was $303.7 million for the three months ended June 30, 2018. Adjusted EBITDA, a non-GAAP financial measure, was $241.2 million for the three months ended June 30, 2018. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to net income (loss) including non-controlling interests and net cash provided by operating activities, see “Non-GAAP Financial Measures” below. |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
2018 | 2017 | Change | 2018 | 2017 | Change | ||||||||||||||||||
Operating results (in thousands) | |||||||||||||||||||||||
Revenues | |||||||||||||||||||||||
Oil revenues | $ | 361,255 | $ | 194,005 | $ | 167,250 | $ | 684,641 | $ | 402,599 | $ | 282,042 | |||||||||||
Natural gas revenues | 34,666 | 24,628 | 10,038 | 74,951 | 53,286 | 21,665 | |||||||||||||||||
Purchased oil and gas sales | 57,578 | 8,091 | 49,487 | 75,615 | 35,722 | 39,893 | |||||||||||||||||
Midstream revenues | 29,342 | 15,566 | 13,776 | 57,264 | 30,172 | 27,092 | |||||||||||||||||
Well services revenues | 18,496 | 11,801 | 6,695 | 30,082 | 17,428 | 12,654 | |||||||||||||||||
Total revenues | $ | 501,337 | $ | 254,091 | $ | 247,246 | $ | 922,553 | $ | 539,207 | $ | 383,346 | |||||||||||
Production data | |||||||||||||||||||||||
Oil (MBbl) | 5,517 | 4,349 | 1,168 | 10,802 | 8,785 | 2,017 | |||||||||||||||||
Natural gas (MMcf) | 10,268 | 7,725 | 2,543 | 20,045 | 15,237 | 4,808 | |||||||||||||||||
Oil equivalents (MBoe) | 7,229 | 5,637 | 1,592 | 14,142 | 11,324 | 2,818 | |||||||||||||||||
Average daily production (Boepd) | 79,437 | 61,943 | 17,494 | 78,135 | 62,564 | 15,571 | |||||||||||||||||
Average sales prices | |||||||||||||||||||||||
Oil, without derivative settlements (per Bbl) | $ | 65.47 | $ | 44.61 | $ | 20.86 | $ | 63.38 | $ | 45.83 | $ | 17.55 | |||||||||||
Oil, with derivative settlements (per Bbl)(1) | 54.53 | 44.35 | 10.18 | 54.36 | 44.79 | 9.57 | |||||||||||||||||
Natural gas, without derivative settlements (per Mcf)(2) | 3.38 | 3.19 | 0.19 | 3.74 | 3.50 | 0.24 | |||||||||||||||||
Natural gas, with derivative settlements (per Mcf)(1)(2) | 3.43 | 3.21 | 0.22 | 3.77 | 3.51 | 0.26 |
(1) | Realized prices include gains or losses on cash settlements for our commodity derivatives, which do not qualify for or were not designated as hedging instruments for accounting purposes. Cash settlements represent the cumulative gains and losses on our derivative instruments for the periods presented and do not include a recovery of costs that were paid to acquire or modify the derivative instruments that were settled. |
(2) | Natural gas prices include the value for natural gas and natural gas liquids. |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
2018 | 2017 | Change | 2018 | 2017 | Change | ||||||||||||||||||
(In thousands, except per Boe of production) | |||||||||||||||||||||||
Operating expenses | |||||||||||||||||||||||
Lease operating expenses | $ | 44,141 | $ | 44,665 | $ | (524 | ) | $ | 88,922 | $ | 88,537 | $ | 385 | ||||||||||
Midstream operating expenses | 7,688 | 3,263 | 4,425 | 15,673 | 6,590 | 9,083 | |||||||||||||||||
Well services operating expenses(1) | 13,560 | 9,010 | 4,550 | 20,947 | 13,570 | 7,377 | |||||||||||||||||
Marketing, transportation and gathering expenses | 22,833 | 12,039 | 10,794 | 43,846 | 22,990 | 20,856 | |||||||||||||||||
Purchased oil and gas expenses | 57,165 | 7,980 | 49,185 | 75,163 | 35,982 | 39,181 | |||||||||||||||||
Production taxes | 34,026 | 18,971 | 15,055 | 65,026 | 39,270 | 25,756 | |||||||||||||||||
Depreciation, depletion and amortization | 153,570 | 125,291 | 28,279 | 302,835 | 251,957 | 50,878 | |||||||||||||||||
Exploration expenses | 617 | 1,667 | (1,050 | ) | 1,386 | 3,156 | (1,770 | ) | |||||||||||||||
Impairment | 384,135 | 3,200 | 380,935 | 384,228 | 5,882 | 378,346 | |||||||||||||||||
General and administrative expenses(1) | 28,230 | 22,626 | 5,604 | 56,170 | 45,802 | 10,368 | |||||||||||||||||
Total operating expenses | 745,965 | 248,712 | 497,253 | 1,054,196 | 513,736 | 540,460 | |||||||||||||||||
Gain on sale of properties | 1,954 | — | 1,954 | 1,954 | — | 1,954 | |||||||||||||||||
Operating income (loss) | (242,674 | ) | 5,379 | (248,053 | ) | (129,689 | ) | 25,471 | (155,160 | ) | |||||||||||||
Other income (expense) | |||||||||||||||||||||||
Net gain (loss) on derivative instruments | (120,285 | ) | 50,532 | (170,817 | ) | (191,401 | ) | 106,607 | (298,008 | ) | |||||||||||||
Interest expense, net of capitalized interest | (40,910 | ) | (36,838 | ) | (4,072 | ) | (78,056 | ) | (73,159 | ) | (4,897 | ) | |||||||||||
Loss on extinguishment of debt | (13,651 | ) | — | (13,651 | ) | (13,651 | ) | — | (13,651 | ) | |||||||||||||
Other income (expense) | 218 | (166 | ) | 384 | 35 | (150 | ) | 185 | |||||||||||||||
Total other income (expense) | (174,628 | ) | 13,528 | (188,156 | ) | (283,073 | ) | 33,298 | (316,371 | ) | |||||||||||||
Income (loss) before income taxes | (417,302 | ) | 18,907 | (436,209 | ) | (412,762 | ) | 58,769 | (471,531 | ) | |||||||||||||
Income tax benefit (expense) | 101,001 | (2,339 | ) | 103,340 | 100,173 | (18,376 | ) | 118,549 | |||||||||||||||
Net income (loss) including non-controlling interests | (316,301 | ) | 16,568 | (332,869 | ) | (312,589 | ) | 40,393 | (352,982 | ) | |||||||||||||
Less: Net income attributable to non-controlling interests | 3,903 | — | 3,903 | 7,025 | — | 7,025 | |||||||||||||||||
Net income (loss) attributable to Oasis | $ | (320,204 | ) | $ | 16,568 | $ | (336,772 | ) | $ | (319,614 | ) | $ | 40,393 | $ | (360,007 | ) | |||||||
Costs and expenses (per Boe of production) | |||||||||||||||||||||||
Lease operating expenses | $ | 6.11 | $ | 7.92 | $ | (1.81 | ) | $ | 6.29 | $ | 7.82 | $ | (1.53 | ) | |||||||||
Marketing, transportation and gathering expenses | 3.16 | 2.14 | 1.02 | 3.10 | 2.03 | 1.07 | |||||||||||||||||
Production taxes | 4.71 | 3.37 | 1.34 | 4.60 | 3.47 | 1.13 | |||||||||||||||||
Depreciation, depletion and amortization | 21.24 | 22.23 | (0.99 | ) | 21.41 | 22.25 | (0.84 | ) | |||||||||||||||
General and administrative expenses(1) | 3.91 | 4.01 | (0.10 | ) | 3.97 | 4.04 | (0.07 | ) |
(1) | For the three and six months ended June 30, 2017, well services operating expenses have been adjusted to include $0.9 million and $1.6 million, respectively, for certain well services direct field labor compensation expenses which were previously recognized in general and administrative expenses on our Condensed Consolidated Statements of Operations. |
Six Months Ended June 30, | |||||||
2018 | 2017 | ||||||
(In thousands) | |||||||
Net cash provided by operating activities | $ | 532,016 | $ | 209,861 | |||
Net cash used in investing activities | (1,156,734 | ) | (259,141 | ) | |||
Net cash provided by financing activities | 625,070 | 49,494 | |||||
Increase in cash and cash equivalents | $ | 352 | $ | 214 |
Three Months Ended | Six Months Ended June 30, 2018 | ||||||||||
March 31, 2018 | June 30, 2018 | ||||||||||
(In thousands) | |||||||||||
Capital expenditures: | |||||||||||
E&P | $ | 176,937 | $ | 280,008 | $ | 456,945 | |||||
Well services | 4,262 | 939 | 5,201 | ||||||||
Other capital expenditures(1) | 6,287 | 5,434 | 11,721 | ||||||||
Total capital expenditures before acquisitions and midstream | 187,486 | 286,381 | 473,867 | ||||||||
Midstream | 88,794 | 68,626 | 157,420 | ||||||||
Total capital expenditures before acquisitions | 276,280 | 355,007 | 631,287 | ||||||||
Acquisitions | 890,948 | 3,527 | 894,475 | ||||||||
Total capital expenditures(2) | $ | 1,167,228 | $ | 358,534 | $ | 1,525,762 |
(1) | Other capital expenditures include such items as administrative capital and capitalized interest. |
(2) | Total capital expenditures reflected in the table above differs from the amounts for capital expenditures and acquisitions shown in the statements of cash flows in our condensed consolidated financial statements because amounts reflected in the table include changes in accrued liabilities from the previous reporting period for capital expenditures, while the amounts presented in the statements of cash flows are presented on a cash basis. |
• | a prohibition against incurring debt, subject to permitted exceptions; |
• | a prohibition against making dividends, distributions and redemptions, subject to permitted exceptions; |
• | a prohibition against making investments, loans and advances, subject to permitted exceptions; |
• | restrictions on creating liens and leases on our assets and our subsidiaries, subject to permitted exceptions; |
• | restrictions on merging and selling assets outside the ordinary course of business; |
• | restrictions on use of proceeds, investments, transactions with affiliates or change of principal business; |
• | a provision limiting oil and natural gas derivative financial instruments; |
• | a requirement that we maintain a ratio of consolidated EBITDAX (as defined in the Oasis Credit Facility) to consolidated Interest Expense (as defined in the Oasis Credit Facility) of no less than 2.5 to 1.0 for the four quarters ended on the last day of each quarter; |
• | a requirement that we maintain a Current Ratio (as defined in the Oasis Credit Facility) of consolidated current assets (including unused borrowing base committed capacity and with exclusions as described in the Oasis Credit Facility) to consolidated current liabilities (with exclusions as described in the Oasis Credit Facility) of no less than 1.0 to 1.0 as of the last day of any fiscal quarter; and |
• | if the Aggregate Elected Commitment Amounts (as defined in the Oasis Credit Facility) exceed $1,350.0 million, a requirement that we maintain a ratio of total debt (as defined in the Oasis Credit Facility) to consolidated EBITDAX (as defined in the Oasis Credit Facility) of no greater than 4.25 to 1.0 for the first two full fiscal quarters ending after the first date on which they exceed $1,350.0 million and no greater than 4.0 to 1.0 for each fiscal quarter thereafter. |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
(In thousands) | |||||||||||||||
Interest expense | $ | 40,910 | $ | 36,838 | $ | 78,056 | $ | 73,159 | |||||||
Capitalized interest | 4,227 | 2,816 | 8,678 | 5,636 | |||||||||||
Amortization of deferred financing costs | (1,937 | ) | (1,709 | ) | (3,698 | ) | (3,399 | ) | |||||||
Amortization of debt discount | (2,731 | ) | (2,480 | ) | (5,349 | ) | (4,835 | ) | |||||||
Cash Interest | $ | 40,469 | $ | 35,465 | $ | 77,687 | $ | 70,561 |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
(In thousands) | |||||||||||||||
Net income (loss) including non-controlling interests | $ | (316,301 | ) | $ | 16,568 | $ | (312,589 | ) | $ | 40,393 | |||||
Gain on sale of properties | (1,954 | ) | — | (1,954 | ) | — | |||||||||
Loss on extinguishment of debt | 13,651 | — | 13,651 | — | |||||||||||
Net (gain) loss on derivative instruments | 120,285 | (50,532 | ) | 191,401 | (106,607 | ) | |||||||||
Derivative settlements(1) | (59,849 | ) | (939 | ) | (96,823 | ) | (8,899 | ) | |||||||
Interest expense, net of capitalized interest | 40,910 | 36,838 | 78,056 | 73,159 | |||||||||||
Depreciation, depletion and amortization | 153,570 | 125,291 | 302,835 | 251,957 | |||||||||||
Impairment | 384,135 | 3,200 | 384,228 | 5,882 | |||||||||||
Exploration expenses | 617 | 1,667 | 1,386 | 3,156 | |||||||||||
Equity-based compensation expenses | 7,376 | 7,115 | 14,130 | 13,823 | |||||||||||
Income tax (benefit) expense | (101,001 | ) | 2,339 | (100,173 | ) | 18,376 | |||||||||
Other non-cash adjustments | (226 | ) | (213 | ) | (17 | ) | 699 | ||||||||
Adjusted EBITDA | 241,213 | 141,334 | 474,131 | 291,939 | |||||||||||
Adjusted EBITDA attributable to non-controlling interests | 5,148 | — | 9,452 | — | |||||||||||
Adjusted EBITDA attributable to Oasis | 236,065 | 141,334 | 464,679 | 291,939 | |||||||||||
Cash Interest | (40,469 | ) | (35,465 | ) | (77,687 | ) | (70,561 | ) | |||||||
Capital expenditures(2) | (358,534 | ) | (172,975 | ) | (1,525,762 | ) | (282,770 | ) | |||||||
Capitalized interest | 4,227 | 2,816 | 8,678 | 5,636 | |||||||||||
Free Cash Flow | $ | (158,711 | ) | $ | (64,290 | ) | $ | (1,130,092 | ) | $ | (55,756 | ) | |||
Net cash provided by operating activities | $ | 303,657 | $ | 102,062 | $ | 532,016 | $ | 209,861 | |||||||
Derivative settlements(1) | (59,849 | ) | (939 | ) | (96,823 | ) | (8,899 | ) | |||||||
Interest expense, net of capitalized interest | 40,910 | 36,838 | 78,056 | 73,159 | |||||||||||
Exploration expenses | 617 | 1,667 | 1,386 | 3,156 | |||||||||||
Deferred financing costs amortization and other | (5,043 | ) | (3,931 | ) | (10,518 | ) | (8,871 | ) | |||||||
Current tax expense | 120 | — | 120 | — | |||||||||||
Changes in working capital | (38,973 | ) | 5,850 | (30,089 | ) | 22,834 | |||||||||
Other non-cash adjustments | (226 | ) | (213 | ) | (17 | ) | 699 | ||||||||
Adjusted EBITDA | 241,213 | 141,334 | 474,131 | 291,939 | |||||||||||
Adjusted EBITDA attributable to non-controlling interests | 5,148 | — | 9,452 | — | |||||||||||
Adjusted EBITDA attributable to Oasis | 236,065 | 141,334 | 464,679 | 291,939 | |||||||||||
Cash Interest | (40,469 | ) | (35,465 | ) | (77,687 | ) | (70,561 | ) | |||||||
Capital expenditures(2) | (358,534 | ) | (172,975 | ) | (1,525,762 | ) | (282,770 | ) | |||||||
Capitalized interest | 4,227 | 2,816 | 8,678 | 5,636 | |||||||||||
Free Cash Flow | $ | (158,711 | ) | $ | (64,290 | ) | $ | (1,130,092 | ) | $ | (55,756 | ) |
(1) | Cash settlements represent the cumulative gains and losses on our derivative instruments for the periods presented and do not include a recovery of costs that were paid to acquire or modify the derivative instruments that were settled. |
(2) | Capital expenditures (including acquisitions) reflected in the table above differ from the amounts shown in the statements of cash flows in our condensed consolidated financial statements because amounts reflected in the table include changes in accrued liabilities from the previous reporting period for capital expenditures, while the amounts presented in the statement of cash flows are presented on a cash basis. Acquisitions totaled $3.5 million and $2.2 million for the three months ended June 30, 2018 and 2017, respectively, and $894.5 million and $4.8 million for the six months ended June 30, 2018 and 2017, respectively. |
Exploration and Production | |||||||||||||||
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
(In thousands) | |||||||||||||||
Income (loss) before income taxes including non-controlling interests | $ | (454,662 | ) | $ | (3,900 | ) | $ | (482,847 | ) | $ | 16,836 | ||||
Gain on sale of properties | (1,954 | ) | — | (1,954 | ) | — | |||||||||
Loss on extinguishment of debt | 13,651 | — | 13,651 | — | |||||||||||
Net (gain) loss on derivative instruments | 120,285 | (50,532 | ) | 191,401 | (106,607 | ) | |||||||||
Derivative settlements(1) | (59,849 | ) | (939 | ) | (96,823 | ) | (8,899 | ) | |||||||
Interest expense, net of capitalized interest | 40,727 | 36,838 | 77,611 | 73,159 | |||||||||||
Depreciation, depletion and amortization | 149,250 | 122,785 | 294,454 | 247,193 | |||||||||||
Impairment | 384,135 | 3,200 | 384,228 | 5,882 | |||||||||||
Exploration expenses | 617 | 1,667 | 1,386 | 3,156 | |||||||||||
Equity-based compensation expenses | 7,012 | 6,897 | 13,463 | 13,395 | |||||||||||
Other non-cash adjustments | (226 | ) | (213 | ) | (17 | ) | 699 | ||||||||
Adjusted EBITDA | $ | 198,986 | $ | 115,803 | $ | 394,553 | $ | 244,814 |
(1) | Cash settlements represent the cumulative gains and losses on our derivative instruments for the periods presented and do not include a recovery of costs that were paid to acquire or modify the derivative instruments that were settled. |
Midstream Services | |||||||||||||||
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
(In thousands) | |||||||||||||||
Income before income taxes including non-controlling interests | $ | 37,815 | $ | 23,106 | $ | 69,796 | $ | 43,867 | |||||||
Interest expense, net of capitalized interest | 183 | — | 445 | — | |||||||||||
Depreciation, depletion and amortization | 6,900 | 3,753 | 13,529 | 7,211 | |||||||||||
Equity-based compensation expenses | 409 | 365 | 780 | 713 | |||||||||||
Adjusted EBITDA | $ | 45,307 | $ | 27,224 | $ | 84,550 | $ | 51,791 |
Well Services | |||||||||||||||
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
(In thousands) | |||||||||||||||
Income (loss) before income taxes including non-controlling interests | $ | 8,051 | $ | 1,950 | $ | 16,158 | $ | (1,637 | ) | ||||||
Depreciation, depletion and amortization | 3,930 | 3,057 | 7,619 | 6,222 | |||||||||||
Equity-based compensation expenses | 409 | 338 | 795 | 734 | |||||||||||
Adjusted EBITDA | $ | 12,390 | $ | 5,345 | $ | 24,572 | $ | 5,319 |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
(In thousands, except per share data) | |||||||||||||||
Net income (loss) attributable to Oasis | $ | (320,204 | ) | $ | 16,568 | $ | (319,614 | ) | $ | 40,393 | |||||
Gain on sale of properties | (1,954 | ) | — | (1,954 | ) | — | |||||||||
Loss on extinguishment of debt | 13,651 | — | 13,651 | — | |||||||||||
Net (gain) loss on derivative instruments | 120,285 | (50,532 | ) | 191,401 | (106,607 | ) | |||||||||
Derivative settlements(1) | (59,849 | ) | (939 | ) | (96,823 | ) | (8,899 | ) | |||||||
Impairment | 384,135 | 3,200 | 384,228 | 5,882 | |||||||||||
Amortization of deferred financing costs | 1,937 | 1,709 | 3,698 | 3,399 | |||||||||||
Amortization of debt discount | 2,731 | 2,480 | 5,349 | 4,835 | |||||||||||
Other non-cash adjustments | (226 | ) | (213 | ) | (17 | ) | 699 | ||||||||
Tax impact(2) | (109,356 | ) | 16,575 | (118,571 | ) | 37,679 | |||||||||
Adjusted Net Income (Loss) Attributable to Oasis | $ | 31,150 | $ | (11,152 | ) | $ | 61,348 | $ | (22,619 | ) | |||||
Diluted earnings (loss) attributable to Oasis per share | $ | (1.02 | ) | $ | 0.07 | $ | (1.06 | ) | $ | 0.20 | |||||
Gain on sale of properties | (0.01 | ) | — | (0.01 | ) | — | |||||||||
Loss on extinguishment of debt | 0.04 | — | 0.04 | — | |||||||||||
Net (gain) loss on derivative instruments | 0.38 | (0.22 | ) | 0.63 | (0.46 | ) | |||||||||
Derivative settlements(1) | (0.19 | ) | — | (0.32 | ) | (0.04 | ) | ||||||||
Impairment | 1.23 | 0.01 | 1.26 | 0.03 | |||||||||||
Amortization of deferred financing costs | 0.01 | 0.01 | 0.01 | 0.01 | |||||||||||
Amortization of debt discount | 0.01 | 0.01 | 0.02 | 0.02 | |||||||||||
Other non-cash adjustments | — | — | — | — | |||||||||||
Tax impact(2) | (0.35 | ) | 0.07 | (0.37 | ) | 0.16 | |||||||||
Adjusted Diluted Earnings (Loss) Attributable to Oasis Per Share | $ | 0.10 | $ | (0.05 | ) | $ | 0.20 | $ | (0.08 | ) | |||||
Diluted weighted average shares outstanding(3) | 315,664 | 233,283 | 304,859 | 233,176 | |||||||||||
Effective tax rate applicable to adjustment items | 23.7 | % | 37.4 | % | 23.7 | % | 37.4 | % |
(1) | Cash settlements represent the cumulative gains and losses on our derivative instruments for the periods presented and do not include a recovery of costs that were paid to acquire or modify the derivative instruments that were settled. |
(2) | The tax impact is computed utilizing our effective tax rate applicable to the adjustments for certain non-cash and non-recurring items. |
(3) | No unvested stock awards were included in computing Adjusted Diluted Loss Attributable to Oasis Per Share for the three and six months ended June 30, 2017 because the effect was anti-dilutive due to Adjusted Net Loss. For the three and six months ended June 30, 2018, we included 2,592,000 and 3,207,000 of unvested stock awards in computing Adjusted Diluted Income Attributable to Oasis Per Share for the three and six months ended June 30, 2018, respectively, due to the dilutive effect under the treasury stock method. |
Commodity | Settlement Period | Derivative Instrument | Index | Volumes | Weighted Average Prices | Fair Value Asset (Liability) | ||||||||||||||||||||||||
Fixed Price Swaps | Basis Swaps | Sub-Floor | Floor | Ceiling | ||||||||||||||||||||||||||
(In thousands) | ||||||||||||||||||||||||||||||
Crude oil | 2018 | Fixed price swaps | NYMEX WTI | 7,745,000 | Bbl | $ | 53.02 | $ | (133,352 | ) | ||||||||||||||||||||
Crude oil | 2018 | Basis swaps | NYMEX WTI-ICE BRENT | 153,000 | Bbl | $ | (10.50 | ) | 471 | |||||||||||||||||||||
Crude oil | 2018 | Two-way collar | NYMEX WTI | 549,000 | Bbl | $ | 48.67 | $ | 53.07 | (9,479 | ) | |||||||||||||||||||
Crude oil | 2019 | Fixed price swaps | NYMEX WTI | 5,613,000 | Bbl | $ | 53.33 | (69,121 | ) | |||||||||||||||||||||
Crude oil | 2019 | Basis swaps | NYMEX WTI-ICE BRENT | 212,000 | Bbl | $ | (10.50 | ) | 353 | |||||||||||||||||||||
Crude oil | 2019 | Two-way collar | NYMEX WTI | 761,000 | Bbl | $ | 52.03 | $ | 69.03 | (2,500 | ) | |||||||||||||||||||
Crude oil | 2019 | Three-way collar | NYMEX WTI | 3,368,000 | Bbl | $ | 40.54 | $ | 51.03 | $ | 68.68 | (12,060 | ) | |||||||||||||||||
Crude oil | 2020 | Fixed price swaps | NYMEX WTI | 403,000 | Bbl | $ | 53.47 | (3,557 | ) | |||||||||||||||||||||
Crude oil | 2020 | Two-way collar | NYMEX WTI | 62,000 | Bbl | $ | 52.50 | $ | 71.25 | (30 | ) | |||||||||||||||||||
Crude oil | 2020 | Three-way collar | NYMEX WTI | 279,000 | Bbl | $ | 40.00 | $ | 50.56 | $ | 67.80 | (876 | ) | |||||||||||||||||
Natural gas | 2018 | Fixed price swaps | NYMEX HH | 6,440,000 | MMbtu | $ | 3.02 | 403 | ||||||||||||||||||||||
Natural gas | 2019 | Fixed price swaps | NYMEX HH | 1,353,000 | MMbtu | $ | 2.96 | (44 | ) | |||||||||||||||||||||
$ | (229,792 | ) |
Period | Total Number of Shares Exchanged(1) | Average Price Paid per Share | Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs | Maximum Number (or Approximate Dollar Value) of Shares that May Be Purchased Under the Plans or Programs | |||||||||
April 1 - April 30, 2018 | 955 | $ | 7.97 | — | — | ||||||||
May 1 - May 31, 2018 | 314 | 10.89 | — | — | |||||||||
June 1 - June 30, 2018 | 2,404 | 13.19 | — | — | |||||||||
Total | 3,673 | $ | 11.63 | — | — |
(1) | Represents shares that employees surrendered back to us to pay tax withholdings upon the vesting of restricted stock awards. These repurchases were not part of a publicly announced program to repurchase shares of our common stock, nor do we have a publicly announced program to repurchase shares of our common stock. |
Exhibit No. | Description of Exhibit | |
Conformed version of Amended and Restated Certificate of Incorporation of Oasis Petroleum Inc., as amended by amendment filed on July 25, 2018. | ||
Seventh Supplemental Indenture (to the Indenture dated as of February 2, 2011) dated as of April 27, 2018 among the Company, the Guarantors and U.S. Bank National Association, as trustee (filed as Exhibit 4.2 to the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2018 and incorporated herein by reference). | ||
Eighth Supplemental Indenture (to the Indenture dated as of November 10, 2011) dated as of April 27, 2018 among the Company, the Guarantors and U.S. Bank National Association, as trustee (filed as Exhibit 4.3 to the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2018 and incorporated herein by reference). | ||
Indenture, dated as of May 14, 2018, among the Company, the Guarantors and U.S. Bank National Association, as trustee (filed as Exhibit 4.1 to the Company’s Current Report on Form 8-K on May 18, 2018 and incorporated herein by reference). | ||
Eighth Supplemental Indenture, dated as of May 14, 2018, among the Company, the Guarantors and U.S. Bank National Association, as trustee (filed as Exhibit 4.2 to the Company’s Current Report on Form 8-K on May 18, 2018 and incorporated herein by reference). | ||
Ninth Supplemental Indenture, dated as of May 14, 2018, among the Company, the Guarantors and U.S. Bank National Association, as trustee (filed as Exhibit 4.3 to the Company’s Current Report on Form 8-K on May 18, 2018 and incorporated herein by reference). | ||
Twelfth Amendment to Second Amended and Restated Credit Agreement, dated as of April 19, 2018, by and among Oasis Petroleum North America LLC, as borrower, the guarantors party thereto, Wells Fargo Bank, N.A., as administrative agent, and the lenders party thereto (filed as Exhibit 10.2 to the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2018 and incorporated herein by reference). | ||
Form of Restricted Stock Award Grant Notice | ||
Form of Restricted Stock Award Agreement | ||
Sarbanes-Oxley Section 302 certification of Principal Executive Officer. | ||
Sarbanes-Oxley Section 302 certification of Principal Financial Officer. | ||
Sarbanes-Oxley Section 906 certification of Principal Executive Officer. | ||
Sarbanes-Oxley Section 906 certification of Principal Financial Officer. | ||
101.INS(a) | XBRL Instance Document. | |
101.SCH(a) | XBRL Schema Document. | |
101.CAL(a) | XBRL Calculation Linkbase Document. | |
101.DEF(a) | XBRL Definition Linkbase Document. | |
101.LAB(a) | XBRL Labels Linkbase Document. | |
101.PRE(a) | XBRL Presentation Linkbase Document. |
(a) | Filed herewith. |
(b) | Furnished herewith. |
OASIS PETROLEUM INC. | |||||||
Date: | August 7, 2018 | By: | /s/ Thomas B. Nusz | ||||
Thomas B. Nusz | |||||||
Chairman and Chief Executive Officer (Principal Executive Officer) |
By: | /s/ Michael H. Lou | ||||||
Michael H. Lou | |||||||
Executive Vice President and Chief Financial Officer (Principal Financial Officer and Principal Accounting Officer) |
OASIS PETROLEUM INC. |
By: /s/ Thomas B. Nusz___________ |
Name: Thomas B. Nusz |
Title: President and Chief Executive Officer |
Service Provider: | ||
Date of Grant: | ___, 20___(“Date of Grant”) | |
Number of Shares of Restricted Stock Granted: | (the “Restricted Stock Award”) | |
Vesting Schedule: | The restrictions on the Restricted Stock Award will expire and the Shares of Restricted Stock granted pursuant to the Agreement will become transferable, except to the extent provided in Section 11 of the Agreement, and nonforfeitable: |
Vesting Date | Vesting Percentage of Restricted Stock Award |
provided, however, that such restrictions will expire on such dates only if you remain in the employ of or a service provider to the Company or its Subsidiaries continuously from the Date of Grant through the applicable vesting date. |
Attachments: | Appendix A – Oasis Petroleum Inc. Amended and Restated 2010 Long Term Incentive Plan Appendix B – Restricted Stock Award Agreement |
1. | I have reviewed this quarterly report on Form 10-Q of Oasis Petroleum Inc. (the “registrant”); |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
a. | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
b. | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
c. | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
d. | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5. | The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
a. | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
b. | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
Date: | August 7, 2018 | /s/ Thomas B. Nusz | ||||
Thomas B. Nusz | ||||||
Chairman and Chief Executive Officer | ||||||
(Principal Executive Officer) |
1. | I have reviewed this quarterly report on Form 10-Q of Oasis Petroleum Inc. (the “registrant”); |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
a. | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
b. | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
c. | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
d. | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5. | The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
a. | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
b. | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
Date: | August 7, 2018 | /s/ Michael H. Lou | ||||
Michael H. Lou | ||||||
Executive Vice President and Chief Financial Officer | ||||||
(Principal Financial Officer and Principal Accounting Officer) |
(1) | The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and |
(2) | The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. |
Date: | August 7, 2018 | /s/ Thomas B. Nusz | ||||
Thomas B. Nusz | ||||||
Chairman and Chief Executive Officer | ||||||
(Principal Executive Officer) |
(1) | The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and |
(2) | The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. |
Date: | August 7, 2018 | /s/ Michael H. Lou | ||||
Michael H. Lou | ||||||
Executive Vice President and Chief Financial Officer | ||||||
(Principal Financial Officer and Principal Accounting Officer) |
Document and Entity Information - shares |
6 Months Ended | |
---|---|---|
Jun. 30, 2018 |
Jul. 31, 2018 |
|
Document And Entity Information [Abstract] | ||
Document Type | 10-Q | |
Amendment Flag | false | |
Document Period End Date | Jun. 30, 2018 | |
Document Fiscal Year Focus | 2018 | |
Document Fiscal Period Focus | Q2 | |
Trading Symbol | OAS | |
Entity Registrant Name | Oasis Petroleum Inc. | |
Entity Central Index Key | 0001486159 | |
Current Fiscal Year End Date | --12-31 | |
Entity Filer Category | Large Accelerated Filer | |
Entity Common Stock, Shares Outstanding | 317,995,747 |
Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - $ / shares |
Jun. 30, 2018 |
Dec. 31, 2017 |
---|---|---|
Statement of Financial Position [Abstract] | ||
Common stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 450,000,000 | 450,000,000 |
Common stock, shares issued (in shares) | 320,010,534 | 270,627,014 |
Common stock, shares outstanding (in shares) | 317,985,056 | 269,295,466 |
Treasury stock, shares (in shares) | 2,025,478 | 1,331,548 |
Condensed Consolidated Statement of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
|
Revenues | ||||
Total revenues | $ 501,337 | $ 254,091 | $ 922,553 | $ 539,207 |
Operating expenses | ||||
Lease operating expenses | 44,141 | 44,665 | 88,922 | 88,537 |
Marketing, transportation and gathering expenses | 22,833 | 12,039 | 43,846 | 22,990 |
Production taxes | 34,026 | 18,971 | 65,026 | 39,270 |
Depreciation, depletion and amortization | 153,570 | 125,291 | 302,835 | 251,957 |
Exploration expenses | 617 | 1,667 | 1,386 | 3,156 |
Impairment | 384,135 | 3,200 | 384,228 | 5,882 |
General and administrative expenses | 28,230 | 22,626 | 56,170 | 45,802 |
Total operating expenses | 745,965 | 248,712 | 1,054,196 | 513,736 |
Gain on sale of properties | 1,954 | 0 | 1,954 | 0 |
Operating income (loss) | (242,674) | 5,379 | (129,689) | 25,471 |
Other income (expense) | ||||
Net gain (loss) on derivative instruments | (120,285) | 50,532 | (191,401) | 106,607 |
Interest expense, net of capitalized interest | (40,910) | (36,838) | (78,056) | (73,159) |
Loss on extinguishment of debt | (13,651) | 0 | (13,651) | 0 |
Other income (expense) | 218 | (166) | 35 | (150) |
Total other income (expense) | (174,628) | 13,528 | (283,073) | 33,298 |
Income (loss) before income taxes | (417,302) | 18,907 | (412,762) | 58,769 |
Income tax benefit (expense) | 101,001 | (2,339) | 100,173 | (18,376) |
Net income (loss) including non-controlling interests | (316,301) | 16,568 | (312,589) | 40,393 |
Less: Net income attributable to non-controlling interests | 3,903 | 0 | 7,025 | 0 |
Net income (loss) attributable to Oasis | $ (320,204) | $ 16,568 | $ (319,614) | $ 40,393 |
Earnings (loss) attributable to Oasis per share: | ||||
Basic (in dollars per share) | $ (1.02) | $ 0.07 | $ (1.06) | $ 0.17 |
Diluted (in dollars per share) | $ (1.02) | $ 0.07 | $ (1.06) | $ 0.17 |
Weighted average shares outstanding: | ||||
Basic (in shares) | 313,072 | 233,283 | 301,652 | 233,176 |
Diluted (in shares) | 313,072 | 234,917 | 301,652 | 236,281 |
Oil and Gas [Member] | ||||
Revenues | ||||
Total revenues | $ 395,921 | $ 218,633 | $ 759,592 | $ 455,885 |
Purchased Oil and Gas Sales [Member] | ||||
Revenues | ||||
Total revenues | 57,578 | 8,091 | 75,615 | 35,722 |
Operating expenses | ||||
Expenses | 57,165 | 7,980 | 75,163 | 35,982 |
Midstream Services [Member] | ||||
Revenues | ||||
Total revenues | 29,342 | 15,566 | 57,264 | 30,172 |
Operating expenses | ||||
Expenses | 7,688 | 3,263 | 15,673 | 6,590 |
Well Services [Member] | ||||
Revenues | ||||
Total revenues | 18,496 | 11,801 | 30,082 | 17,428 |
Operating expenses | ||||
Expenses | $ 13,560 | $ 9,010 | $ 20,947 | $ 13,570 |
Condensed Consolidated Statement of Changes in Stockholders' Equity (Unaudited) - 6 months ended Jun. 30, 2018 - USD ($) shares in Thousands, $ in Thousands |
Total |
Common Stock [Member] |
Treasury Stock [Member] |
Additional Paid-in-Capital [Member] |
Retained Earnings [Member] |
Noncontrolling Interest [Member] |
---|---|---|---|---|---|---|
Balance (shares) at Dec. 31, 2017 | 269,295 | 1,332 | ||||
Balance at Dec. 31, 2017 | $ 3,513,579 | $ 2,668 | $ (22,179) | $ 2,677,217 | $ 717,985 | $ 137,888 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||
Permian Basin Acquisition issuance (shares) | 46,000 | |||||
Permian Basin Acquisition issuance | 371,220 | $ 460 | 370,760 | |||
Other fees (2017 issuance of common stock and Oasis Midstream common units) (shares) | 0 | |||||
Other (2017 issuance of common stock and Oasis Midstream common units) | (87) | $ 0 | 38 | (125) | ||
Equity-based compensation (shares) | 3,383 | |||||
Equity-based compensation | 15,038 | $ 26 | 14,846 | 166 | ||
Distributions to non-controlling interest owners | (6,846) | (6,846) | ||||
Treasury stock - tax withholdings (shares) | 693 | 693 | ||||
Treasury stock - tax withholdings | (6,064) | $ (6,064) | 0 | |||
Net income (loss) | (312,589) | (319,614) | 7,025 | |||
Balance (shares) at Jun. 30, 2018 | 317,985 | 2,025 | ||||
Balance at Jun. 30, 2018 | $ 3,574,251 | $ 3,154 | $ (28,243) | $ 3,062,861 | $ 398,371 | $ 138,108 |
Organization and Operations of the Company |
6 Months Ended |
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Jun. 30, 2018 | |
Accounting Policies [Abstract] | |
Organization and Operations of the Company | Organization and Operations of the Company Oasis Petroleum Inc. (together with its consolidated subsidiaries, “Oasis” or the “Company”) was originally formed in 2007 and was incorporated pursuant to the laws of the State of Delaware in 2010. The Company is an independent exploration and production company focused on the acquisition and development of onshore, unconventional oil and natural gas resources in the United States. Oasis Petroleum North America LLC (“OPNA”) and Oasis Petroleum Permian LLC (“OP Permian”) conduct the Company’s exploration and production activities and own its proved and unproved oil and natural gas properties located in the North Dakota and Montana regions of the Williston Basin and the Texas regions of the Delaware Basin, respectively. The Company also operates a midstream services business through OMS Holdings LLC (“OMS”) and a well services business through Oasis Well Services LLC (“OWS”), both of which are separate reportable business segments that are complementary to its primary development and production activities. The midstream services business is conducted by Oasis Midstream Partners LP (“OMP” or “Oasis Midstream”), which completed an initial public offering in September 2017. The Company owns the general partner and a majority of the outstanding units of OMP. |
Summary of Significant Accounting Policies |
6 Months Ended |
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Jun. 30, 2018 | |
Accounting Policies [Abstract] | |
Summary of Significant Accounting Policies | Summary of Significant Accounting Policies Basis of Presentation The accompanying condensed consolidated financial statements of the Company have not been audited by the Company’s independent registered public accounting firm, except that the Condensed Consolidated Balance Sheet at December 31, 2017 is derived from audited financial statements. Certain reclassifications of prior year balances have been made to conform such amounts to current year classifications. These reclassifications have no impact on net income. In the opinion of management, all adjustments, consisting of normal recurring adjustments necessary for the fair statement of the Company’s financial position, have been included. Management has made certain estimates and assumptions that affect reported amounts in the condensed consolidated financial statements and disclosures of contingencies. Actual results may differ from those estimates. The results for interim periods are not necessarily indicative of annual results. These interim financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Certain disclosures have been condensed or omitted from these financial statements. Accordingly, they do not include all of the information and notes required by accounting principles generally accepted in the United States of America (“GAAP”) for complete consolidated financial statements and should be read in conjunction with the Company’s audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017 (“2017 Annual Report”). Consolidation. The accompanying condensed consolidated financial statements of the Company include the accounts of Oasis, the accounts of wholly-owned subsidiaries, and the accounts of OMP, which is considered a variable interest entity (“VIE”) for which the Company is the primary beneficiary. All significant intercompany balances and transactions have been eliminated upon consolidation. Consolidated VIE. The Company has determined that the partners with equity at risk in OMP lack the authority, through voting rights or similar rights, to direct the activities that most significantly impact OMP’s economic performance. Therefore, as the limited partners of OMP do not have substantive kick-out or substantive participating rights over OMP GP LLC (“OMP GP”), the general partner to OMP, OMP is a VIE. Through the Company’s ownership interest in OMP GP, the Company has the authority to direct the activities that most significantly affect economic performance and the right to receive benefits that could be potentially significant to OMP. Therefore, the Company is considered the primary beneficiary and consolidates OMP and records a non-controlling interest for the interest owned by the public as of June 30, 2018. Risks and Uncertainties As an oil and natural gas producer, the Company’s revenue, profitability and future growth are substantially dependent upon the prevailing and future prices for oil and natural gas, which are dependent upon numerous factors beyond its control such as economic, political and regulatory developments and competition from other energy sources. The energy markets have historically been very volatile, and there can be no assurance that oil and natural gas prices will not be subject to wide fluctuations in the future. A substantial or extended decline in prices for oil and, to a lesser extent, natural gas could have a material adverse effect on the Company’s financial position, results of operations, cash flows and quantities of oil and natural gas reserves that may be economically produced. Significant Accounting Policies There have been no material changes to the Company’s critical accounting policies and estimates from those disclosed in the 2017 Annual Report, other than as noted below. Revenue recognition. In the first quarter of 2018, the Company adopted Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). The objective of ASU 2014-09 is greater consistency and comparability across industries by using a five-step model to recognize revenue from customer contracts. ASU 2014-09 was applied on a modified retrospective basis. The adoption of ASU 2014-09 did not result in a material impact to the Company’s financial position, cash flows or results of operations. Enhanced disclosures in accordance with ASU 2014-09 have been provided in Note 3 – Revenue Recognition. Financial instruments. In the first quarter of 2018, the Company adopted Accounting Standards Update No. 2016-01, Recognition and Measurement of Financial Assets and Financial Liabilities (“ASU 2016-01”), which requires that most equity instruments be measured at fair value with subsequent changes in fair value recognized in net income. ASU 2016-01 also impacts financial liabilities under the fair value option and the presentation and disclosure requirements for financial instruments. ASU 2016-01 does not apply to equity method investments or investments in consolidated subsidiaries. ASU 2016-01 was applied on a prospective basis and prior periods were not retrospectively adjusted. There was no material impact as a result of adoption as of June 30, 2018. Statement of cash flows. In the first quarter of 2018, the Company adopted Accounting Standards Update No. 2016-15, Statement of Cash Flows (“ASU 2016-15”), which is intended to reduce diversity in practice in how certain transactions are classified in the statement of cash flows. ASU 2016-15 was applied on a prospective basis and prior periods were not retrospectively adjusted. There was no material impact as a result of adoption as of June 30, 2018. Income taxes. In the first quarter of 2018, the Company adopted Accounting Standards Update No. 2016-16, Intra-Entity Transfers of Assets Other Than Inventory (“ASU 2016-16”), to improve the accounting for the income tax consequences of intra-entity transfers of assets other than inventory. ASU 2016-16 was applied on a prospective basis and prior periods were not retrospectively adjusted. There was no material impact as a result of adoption as of June 30, 2018. Business combinations. In the first quarter of 2018, the Company adopted Accounting Standards Update No. 2017-01, Clarifying the Definition of a Business (“ASU 2017-01”), which provides guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. ASU 2017-01 requires entities to use a screen test to determine when an integrated set of assets and activities is not a business or if the integrated set of assets and activities needs to be further evaluated against the framework. ASU 2017-01 was applied on a prospective basis and prior periods were not retrospectively adjusted. There was no material impact as a result of adoption as of June 30, 2018. Equity-based compensation. In the first quarter of 2018, the Company adopted Accounting Standards Update No. 2017-09, Scope of Modification Accounting (“ASU 2017-09”), which provides guidance about which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting. ASU 2017-09 was applied on a prospective basis and prior periods were not retrospectively adjusted. There was no material impact as a result of adoption as of June 30, 2018. Recent Accounting Pronouncements Leases. In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2016-02, Leases (“ASU 2016-02”), which requires a lessee to recognize lease payment obligations and a corresponding right-of-use asset to be measured at fair value on the balance sheet. ASU 2016-02 also requires certain qualitative and quantitative disclosures about the amount, timing and uncertainty of cash flows arising from leases. This standard does not apply to leases to explore for or use minerals, oil or natural gas resources, including the right to explore for those natural resources. ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, including interim periods within those years. In January 2018, the FASB issued Accounting Standards Update No. 2018-01, Land easement practical expedient for transition to Topic 842, which provides an optional transition practical expedient to not evaluate under Topic 842 existing or expired land easements that were not previously accounting for as leases under Topic 840, Leases. The Company plans to elect this practical expedient and is currently evaluating the effect that adopting the new lease guidance will have on its financial position, cash flows or results of operations. Income taxes. In March 2018, the FASB issued Accounting Standards Update No. 2018-05, Income Taxes (Topic 740) - Amendments to SEC Paragraphs Pursuant to SEC Staff Accounting Bulletin No. 118 (“ASU 2018-05”). The standard amends Accounting Standards Codification 740, Income Taxes (“ASC 740”) to provide guidance on accounting for the tax effects of the Tax Cuts and Jobs Act (the “Tax Act”) pursuant to Staff Accounting Bulletin No. 118, Income Tax Accounting Implications of the Tax Cuts and Jobs Act ("SAB 118"). The Company is currently evaluating the effect of the new tax guidance, but does not expect it to have a material impact on its financial position, cash flows or results of operations. See Note 13 – Income Taxes. |
Revenue Recognition |
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Revenue from Contract with Customer [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Revenue Recognition | Revenue Recognition In May 2014, the FASB issued a new accounting standard related to revenue recognition, ASC 606 - Revenue from Contracts with Customers (“ASC 606”). This standard was effective in first quarter 2018 and the Company adopted the new standard using the modified retrospective method. The Company applied ASC 606 to all new contracts entered into after January 1, 2018 and all existing contracts for which all (or substantially all) of the revenue has not been recognized under legacy revenue guidance as of December 31, 2017. ASC 606 supersedes previous revenue recognition requirements in ASC 605 and includes a five-step revenue recognition model to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the Company expects to be entitled in exchange for those goods or services. In accordance with the adoption of ASC 606, management evaluated its contracts with customers to apply the five-step revenue recognition model. The adoption of ASC 606 did not result in a material impact to the Company’s financial position, cash flows or results of operations. The unit of account in ASC 606 is a performance obligation, which is a promise in a contract to transfer to a customer either a distinct good or service (or bundle of goods or services) or a series of distinct goods or services provided over a period of time. ASC 606 requires that a contract’s transaction price, which is the amount of consideration to which an entity expects to be entitled in exchange for transferring promised goods or services to a customer, is to be allocated to each performance obligation in the contract based on relative standalone selling prices and recognized as revenue when (point in time) or as (over time) the performance obligation is satisfied. Exploration and production revenues Our exploration and production revenues are derived from contracts for oil, natural gas and natural gas liquids (“NGL”) sales, as described below. Generally, for the majority of these contracts: (i) each unit (barrel (“bbl”), mcf, gallon, etc.) of commodity product is a separate performance obligation, as our promise is to sell multiple distinct units of commodity product at a point in time; (ii) the transaction price principally consists of variable consideration, which amount is determinable each month end based on our right to invoice at month end for the value of commodity product sold to the customer that month; and (iii) the transaction price is allocated to each performance obligation based on the commodity product’s standalone selling price and recognized as revenue upon delivery of the commodity product, which is the point in time when the customer obtains control of the commodity product and our performance obligation is satisfied. The sales of oil, natural gas and NGLs as presented on the Company’s Condensed Consolidated Statements of Operations represent the Company’s share of revenues net of royalties and excluding revenue interests owned by others. When selling oil, natural gas and NGLs on behalf of royalty owners or working interest owners, the Company is acting as an agent and thus reports the revenue on a net basis. To the extent actual volumes and prices of oil and natural gas sales are unavailable for a given reporting period because of timing or information not received from third parties, the expected sales volumes and prices for those properties are estimated and recorded. The Company’s contracts with customers typically require payments for oil, natural gas and NGL sales within 30 days following the calendar month of delivery. Oil sales. The Company sells a substantial majority of its oil through bulk sales at delivery points on crude oil gathering systems or directly at the wellhead to a variety of customers under short-term contracts that include a specified quantity of crude oil to be delivered and sold to the customer at a specified delivery point. The customer pays a market-based transaction price, which incorporates differentials that include, but are not limited to, transportation costs and adjustments for product quality. Natural gas sales. The Company’s natural gas sales consist of unprocessed gas sales and residue gas sales. Unprocessed gas is sold at delivery points at or near the wellhead under percentage of proceeds contracts, in which the customer pays a transaction price based on its sale of the bifurcated NGLs and residue gas, less any associated fees. Revenue is recorded on a net basis, with processing fees deducted within revenue rather than as a separate expense line item, as title and control transfer at the delivery point. Residue gas is sold from the tailgate of the Company’s gas processing plant located in Wild Basin or transported and sold at other downstream sales points, and the customer pays a transaction price based on a market indexed per-unit rate for the quantities sold. Purchased oil and gas sales. The Company purchases and sells crude oil and natural gas at various delivery points to a variety of customers under short-term contracts that include specified quantities of crude oil and natural gas to be sold and delivered to the customer at a specified delivery point. The Company purchases and sells crude oil and natural gas to different counterparties at market-based prices. Market-based pricing is based on the price index applicable for the location of the sale. The Company accounts for these transactions on a gross basis. NGL sales. NGLs are sold from the Company’s gas processing plant complex located in Wild Basin or trucked and sold at other downstream locations, and the customer pays a transaction price based on a market indexed per-unit rate for the quantities sold. Prior period performance obligations. For sales of oil, purchased oil, natural gas, purchased gas and NGLs, the Company records revenue in the month production is delivered to the purchaser. However, settlement statements and payment may not be received for 30 to 90 days after the date production is delivered, and as a result, the Company is required to estimate the amount of production that was delivered to the purchaser and the price that will be received for the sale of the product. The Company records the differences between estimates and the actual amounts received for product sales once payment is received from the purchaser. Such differences have historically not been significant. The Company uses knowledge of its properties, its properties' historical performance, spot market prices and other factors as the basis for these estimates. For the three and six months ended June 30, 2018, revenue recognized related to performance obligations satisfied in prior reporting periods was not material. Revenues associated with contracts with customers for oil, natural gas and NGL sales were as follows for the three and six months ended June 30, 2018 and 2017:
Midstream revenues Crude oil and natural gas revenues. The Company is party to certain contracts for gas gathering, compression, processing and gas lift services, as well as crude oil gathering, stabilization, blending, storage and transportation. Under these customer contracts, the Company provides daily integrated midstream services on a stand ready basis over a period of time, which represents a single performance obligation since the customer simultaneously receives and consumes the benefits of these services on a daily basis. Satisfaction of the Company’s performance obligation is measured as each day of service is completed, which directly corresponds with its right to consideration from the customer. Revenues associated with these contracts are recognized based upon the transaction price at month-end under the right to invoice practical expedient. Payments from customers are generally received by the Company within one month after the month in which services are provided. Purchased oil sales. The Company purchases and sells crude oil at various delivery points on crude oil gathering systems to a variety of customers under short-term contracts that include a specified quantity of crude oil to be sold and delivered to the customer at a specified delivery point. The Company purchases and sells the crude oil to different counterparties at market-based prices. Market-based pricing is based on the price index applicable for the location of the sale. The Company accounts for these transactions on a gross basis. Water revenues. The Company is also party to certain contracts with customers for water services, which includes produced and flowback water gathering and disposal services and freshwater distribution services. Under its customer contracts for produced and flowback water gathering and disposal services, the Company provides daily integrated midstream services on a stand ready basis over a period of time, which represents a single performance obligation since the customer simultaneously receives and consumes the benefits of these services on a daily basis. Satisfaction of the Company’s performance obligation is measured as each day of service is completed, which directly corresponds with its right to consideration from the customer. Revenues associated with these contracts are recognized based upon the transaction price at month-end under the right to invoice practical expedient. Payments from customers are generally received by the Company within one month after the month in which services are provided. Under its customer contracts for freshwater distribution services, the Company supplies and distributes freshwater to its customers for hydraulic fracturing and production optimization. Management has determined these contracts contain multiple distinct performance obligations since each freshwater barrel is not dependent nor highly interrelated with other barrels. Revenue associated with freshwater distribution services is recognized at a point-in-time based upon the transaction price when title, control and risk of loss transfers to the customer, which occurs at the delivery point. Payments are due from customers 30 days after receipt of invoice. Revenues associated with contracts with customers for midstream services were as follows for the three and six months ended June 30, 2018 and 2017:
__________________
Well services revenues Hydraulic fracturing service revenues. Hydraulic fracturing revenue is recognized upon the completion of each hydraulic fracturing of a well. These services are composed of various components, such as personnel, equipment and hydraulic fracturing materials, but management determined that each component is not distinct, as it cannot be used on its own or together with a resource readily available to the customer. Revenue is recognized when the performance obligations of hydraulic fracturing a well in its totality are completed; generally, this is over a period of time due to all work being performed for a customer occurring on the customer’s property, where the customer has control over the work in process as it is being performed. In addition, the Company’s assets being used to perform the obligations have no alternative use at the time of performance and the Company has the right to payment for performance to date. Payments from customers are generally received by the Company within one month after the month in which services are provided. In addition, revenue from product sales to third parties is generated when OPNA requests that third-party hydraulic fracturing companies hydraulic fracture OPNA’s wells. Although the labor is provided by the third-party hydraulic fracturing company, the materials (e.g., sand, chemicals, etc.) used in the hydraulic fracturing of the wells are provided by OWS. The third-party hydraulic fracturing company or OPNA pays OWS for the materials delivered to the wells. Revenue is recognized once the performance obligations to transfer hydraulic fracturing materials are completed. Equipment rental revenues. Equipment rental revenue is generated when OPNA or a third-party hydraulic fracturing company rents equipment from OWS. This equipment is used in the preparation stage of hydraulic fracturing services or after the hydraulic fracturing services have been completed. Equipment rental revenues are calculated based on the equipment’s daily rental rate and the number of days that the equipment was rented by the customer. OWS’s performance obligation is satisfied when the entire rental period is completed. Equipment rental revenues are recognized over a period of time due to the customer simultaneously receiving and consuming the benefits of the rental equipment provided by OWS on a daily basis. Satisfaction of the Company’s performance obligation is measured as each day of rental period is completed, which directly corresponds with its right to consideration from the customer. Revenues associated with these contracts are recognized at the time of invoicing for the entire rental period under the right to invoice practical expedient. Payments from customers are generally received by the Company within one month after the month in which services are provided. Revenues associated with contracts with customers for hydraulic fracturing services and equipment rental sales were as follows for the three and six months ended June 30, 2018 and 2017:
__________________
Contract balances Under the Company's customer contracts, invoicing occurs once the Company's performance obligations have been satisfied, at which point payment is unconditional. Accordingly, the Company's contracts do not give rise to contract assets or liabilities under ASC 606. Performance obligations The majority of the Company’s sales are short-term in nature with a contract term of one year or less. For those contracts, the Company utilized the practical expedient in ASC 606-10-50-14 that exempts the Company from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less. For the Company’s product sales that have a contract term greater than one year, the Company utilized the practical expedient in ASC 606-10-50-14(A) which states the Company is not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under these sales contracts, each unit of product generally represents a separate performance obligation; therefore future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required. Under the midstream services contracts, each unit of service represents a separate performance obligation and therefore performance obligations in respect of future services are wholly unsatisfied. |
Inventory |
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Inventory Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventory | Inventory Crude oil inventory includes oil in tanks. Equipment and materials consist primarily of proppant, chemicals, tubular goods, well equipment to be used in future drilling or repair operations and well fracturing equipment. Crude oil inventory and equipment and materials are included in inventory on the Company’s Condensed Consolidated Balance Sheets. The minimum volume of product in a pipeline system that enables the system to operate is known as linefill and is generally not available to be withdrawn from the pipeline system until the expiration of the transportation contract. The Company owns oil linefill in third-party pipelines, which is included in long-term inventory on the Company’s Condensed Consolidated Balance Sheets. Inventory, including long-term inventory, is stated at the lower of cost and net realizable value with cost determined on an average cost method. The Company assesses the carrying value of inventory and uses estimates and judgment when making any adjustments necessary to reduce the carrying value to net realizable value. Among the uncertainties that impact the Company’s estimates are the applicable quality and location differentials to include in the Company’s net realizable value analysis. Additionally, the Company estimates the upcoming liquidation timing of the inventory. Changes in assumptions made as to the timing of a sale can materially impact net realizable value. Total inventory consists of the following:
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Accounts Receivable, Net |
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Receivables [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Receivable, Net | Accounts Receivable, Net The following table sets forth the Company’s accounts receivable, net:
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Fair Value Measurements |
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Fair Value Disclosures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Measurements | Fair Value Measurements In accordance with the FASB’s authoritative guidance on fair value measurements, the Company’s financial assets and liabilities are measured at fair value on a recurring basis. The Company’s financial instruments, including certain cash and cash equivalents, accounts receivable, accounts payable and other payables, are carried at cost, which approximates their respective fair market values due to their short-term maturities. The Company recognizes its non-financial assets and liabilities, such as asset retirement obligations (“ARO”) and proved oil and natural gas properties upon impairment, at fair value on a non-recurring basis. As defined in the authoritative guidance, fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). To estimate fair value, the Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. The authoritative guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (“Level 1” measurements) and the lowest priority to unobservable inputs (“Level 3” measurements). The three levels of the fair value hierarchy are as follows: Level 1 — Unadjusted quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 2 — Pricing inputs, other than unadjusted quoted prices in active markets included in Level 1, are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Level 3 — Pricing inputs are generally less observable from objective sources, requiring internally developed valuation methodologies that result in management’s best estimate of fair value. Financial Assets and Liabilities Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The following tables set forth by level, within the fair value hierarchy, the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis:
The Level 1 instruments presented in the tables above consist of money market funds included in cash and cash equivalents on the Company’s Condensed Consolidated Balance Sheets at June 30, 2018 and December 31, 2017. The Company’s money market funds represent cash equivalents backed by the assets of high-quality major banks and financial institutions. The Company identifies the money market funds as Level 1 instruments because the money market funds have daily liquidity, quoted prices for the underlying investments can be obtained, and there are active markets for the underlying investments. The Level 2 instruments presented in the tables above consist of commodity derivative instruments, which include oil and natural gas swaps and collars. The fair values of the Company’s commodity derivative instruments are based upon a third-party preparer’s calculation using mark-to-market valuation reports provided by the Company’s counterparties for monthly settlement purposes to determine the valuation of its derivative instruments. The Company has the third-party preparer evaluate other readily available market prices for its derivative contracts, as there is an active market for these contracts. The third-party preparer performs its independent valuation using a moment matching method similar to Turnbull-Wakeman for Asian options. The significant inputs used are crude oil prices, volatility, skew, discount rate and the contract terms of the derivative instruments. The Company compares the third-party preparer’s valuation to counterparty valuation statements, investigating any significant differences, and analyzes monthly valuation changes in relation to movements in crude oil and natural gas forward price curves. The determination of the fair value for derivative instruments also incorporates a credit adjustment for non-performance risk, as required by GAAP. The Company calculates the credit adjustment for derivatives in a net asset position using current credit default swap values for each counterparty. The credit adjustment for derivatives in a net liability position is based on the Company’s market credit spread. Based on these calculations, the Company recorded an adjustment to reduce the fair value of its net derivative liability by $3.5 million at June 30, 2018 and by $2.8 million at December 31, 2017. There were no transfers between fair value levels during the six months ended June 30, 2018 and December 31, 2017. |
Derivative Instruments |
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Derivative Instruments and Hedging Activities Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Derivative Instruments | Derivative Instruments The Company utilizes derivative financial instruments to manage risks related to changes in oil and natural gas prices. The Company’s crude oil contracts will settle monthly based on the average NYMEX West Texas Intermediate crude oil index price (“NYMEX WTI”) and the average Intercontinental Exchange, Inc. Brent crude oil index price (“ICE Brent”). The Company’s natural gas contracts will settle monthly based on the average NYMEX Henry Hub natural gas index price (“NYMEX HH”). At June 30, 2018, the Company utilized fixed price swaps, basis swaps and two-way and three-way costless collars to reduce the price volatility associated with certain of its of oil and natural gas sales. The Company’s fixed price swaps are comprised of a sold call and a purchased put established at the same price (both ceiling and floor), which the Company will receive for the volumes under contract. A basis swap transaction has an established fixed basis differential corresponding to two floating index prices. Depending on the difference of the two floating index prices in relation to the fixed basis differential, the Company either receives an amount from its counterparty, or pays an amount to its counterparty, equal to the difference multiplied by the hedged contract volume. A two-way collar is a combination of options: a sold call and a purchased put. The purchased put establishes a minimum price (floor) and the sold call establishes a maximum price (ceiling) the Company will receive for the volumes under contract. A three-way collar is a combination of options: a sold call, a purchased put and a sold put. The purchased put establishes a minimum price (floor), unless the market price falls below the sold put (sub-floor), at which point the minimum price would be the NYMEX index price plus the difference between the purchased put and the sold put strike price. The sold call establishes a maximum price (ceiling) the Company will receive for the volumes under contract. All derivative instruments are recorded on the Company’s Condensed Consolidated Balance Sheets as either assets or liabilities measured at fair value (see Note 6 – Fair Value Measurements). The Company has not designated any derivative instruments as hedges for accounting purposes and does not enter into such instruments for speculative trading purposes. If a derivative does not qualify as a hedge or is not designated as a hedge, the changes in fair value are recognized in the other income (expense) section of the Company’s Condensed Consolidated Statements of Operations as a net gain or loss on derivative instruments. The Company’s cash flow is only impacted when the actual settlements under the derivative contracts result in making a payment to or receiving a payment from the counterparty. These cash settlements represent the cumulative gains and losses on the Company’s derivative instruments and do not include a recovery of costs that were paid to acquire or modify the derivative instruments that were settled. Cash settlements are reflected as investing activities in the Company’s Condensed Consolidated Statements of Cash Flows. At June 30, 2018, the Company had the following outstanding commodity derivative instruments:
In July 2018, the Company entered into new natural gas basis swap contracts with weighted average differential prices, which represent a reduction of $0.06 per MMbtu. These basis swaps are settled based on the differential between Northern Natural Gas Ventura natural gas index price and NYMEX HH. The basis swap contracts include total notional amounts of 1,220,000 MMbtu and 1,810,000 MMbtu, which settle in 2018 and 2019, respectively. These derivative instruments do not qualify for and were not designated as hedging instruments for accounting purposes. The following table summarizes the location and amounts of gains and losses from the Company’s commodity derivative instruments recorded in the Company’s Condensed Consolidated Statements of Operations for the periods presented:
In accordance with the FASB’s authoritative guidance on disclosures about offsetting assets and liabilities, the Company is required to disclose both gross and net information about instruments and transactions eligible for offset in the statement of financial position as well as instruments and transactions subject to an agreement similar to a master netting agreement. The Company’s derivative instruments are presented as assets and liabilities on a net basis by counterparty, as all counterparty contracts provide for net settlement. No margin or collateral balances are deposited with counterparties, and as such, gross amounts are offset to determine the net amounts presented in the Company’s Condensed Consolidated Balance Sheets. The following table summarizes the location and fair value of all outstanding commodity derivative instruments recorded in the Company’s Condensed Consolidated Balance Sheets:
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Property, Plant and Equipment |
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Property, Plant and Equipment [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment | Property, Plant and Equipment The following table sets forth the Company’s property, plant and equipment:
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Acquisition |
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Business Combinations [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Acquisition | Acquisition Permian Basin Acquisition. On February 14, 2018, the Company acquired from Forge Energy, LLC (“Forge Energy”) approximately 22,000 net acres in the Delaware Basin (the “Permian Basin Acquisition”) for aggregate consideration consisting of approximately $549.8 million in cash and 46,000,000 shares of the Company’s common stock, subject to customary post-closing adjustments (collectively, the “Purchase Price”). In connection with the closing of the Permian Basin Acquisition, the Company and Forge Energy entered into a Registration Rights Agreement that granted the equity holders of Forge Energy certain customary registration rights for the stock portion of the Purchase Price. The Company funded the cash portion of the Purchase Price with borrowings under a senior secured revolving line of credit among OPNA, as Borrower, Wells Fargo Bank, N.A., as administrative agent and the lenders party thereto (the “Oasis Credit Facility”), and proceeds from the Company’s December 2017 issuance of its common stock. The Permian Basin Acquisition represents the Company’s initial entry into the Delaware Basin. The assets underlying the Permian Basin Acquisition are primarily located in the Bone Spring and Wolfcamp formations of the Delaware sub-basin, across Ward, Winkler, Loving and Reeves Counties, Texas. The Permian Basin Acquisition qualified as a business combination. As such, the Company estimated the fair value of the assets acquired and liabilities assumed as of the February 14, 2018 acquisition date. The fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). Fair value measurements also utilize assumptions of market participants. The Company used a discounted cash flow model and made market assumptions as to future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development and operating costs, projections of future rates of production, expected recovery rates and risk adjusted discount rates. These assumptions represent Level 3 inputs, as further discussed under Note 6 — Fair Value Measurements. The Company recorded the assets acquired and liabilities assumed in the Permian Basin Acquisition at their estimated fair value of $921.0 million, which the Company considers to be representative of the price paid by a typical market participant. This measurement resulted in no goodwill or bargain purchase being recognized. The Permian Basin Acquisition is considered a taxable transaction; therefore, no deferred tax amounts were recognized at the acquisition date as the tax basis of the assets acquired and liabilities assumed were also recorded at fair value. The following table summarizes the consideration paid for the Company’s acquisition and the fair value of the assets acquired and liabilities assumed as of the acquisition date. The purchase price allocation is preliminary and subject to adjustment, as the final closing statement was finalized in July 2018, subsequent to the second quarter of 2018.
The results of operations for the Permian Basin Acquisition have been included in the Company’s condensed consolidated financial statements since the February 14, 2018 closing date, including $20.0 million and $31.6 million of total revenue and $6.8 million and $10.2 million of operating income for the three and six months ended June 30, 2018, respectively. The Company also recorded a $1.0 million finite-lived intangible asset on the Company’s Condensed Consolidated Balance Sheets for a non-compete agreement with a one-year life. Intangible assets are amortized on a straight-line basis over the useful life, and the Company includes the amortization in depreciation, depletion and amortization expenses on the Company’s Condensed Consolidated Statements of Operations. For the three and six months ended June 30, 2018, amortization expense recognized for this non-compete agreement was approximately $0.3 million and $0.4 million, respectively. Summarized below are the consolidated results of operations for the three and six months ended June 30, 2018, on an unaudited pro forma basis, as if the acquisition and related financing had occurred on January 1, 2017. The unaudited pro forma financial information was derived from the historical consolidated statements of operations of the Company and the statement of revenues and direct operating expenses for the Permian Basin Acquisition properties, which were derived from the historical accounting records of Forge Energy. The unaudited pro forma financial information does not purport to be indicative of results of operations that would have occurred had the acquisition and related financing occurred on the basis assumed above, nor is such information indicative of the Company’s expected future results of operations.
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Divestitures and Assets Held for Sale |
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Discontinued Operations and Disposal Groups [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Divestitures and Assets Held for Sale | Divestitures and Assets Held for Sale On June 25, 2018, the Company announced the signing of two separate purchase and sale agreements to sell certain non-core assets in the Williston Basin for total cash proceeds of $282.5 million. The assets to be divested consisted of certain non-operated oil and gas properties in the Williston Basin (the “Williston Non-Op Divestiture”) and oil and gas properties primarily located in the Foreman Butte area of the Williston Basin (the “Foreman Butte Divestiture,” and, together with the Williston Non-Op Divestiture, the “2018 Divestitures”). Assets and liabilities held for sale represent the assets that are expected to be sold and the liabilities that are expected to be assumed by the purchaser, respectively. As of June 30, 2018, the assets and liabilities expected to be sold in the 2018 Divestitures were classified as held for sale. The assets and liabilities held for sale are primarily in the Company’s exploration and production segment with certain assets and liabilities held for sale included in the Foreman Butte Divestiture in the Company’s midstream segment. The Company did not have any assets or liabilities classified as held for sale as of December 31, 2017. Williston Non-Op Divestiture. On July 10, 2018, the Company completed the initial closing for the Williston Non-Op Divestiture. The transaction had an effective date of March 1, 2018, and the final closing statement will be completed in the fourth quarter of 2018. Upon the initial closing, the Company recognized a $33.2 million net gain on sale of properties, which is subject to customary closing adjustments, subsequent to the quarter ended June 30, 2018. The following table presents balance sheet data related to the assets and liabilities held for sale related to the Williston Non-Op Divestiture as of June 30, 2018:
Foreman Butte Divestiture. In July 2018, the Company completed the initial closing for the Foreman Butte Divestiture. The transaction had an effective date of March 1, 2018, and the final closing statement will be completed in the first quarter of 2019. During the second quarter of 2018, the Company recorded an impairment loss of $383.4 million, which was included in impairment on the Company’s Condensed Consolidated Statements of Operations, to adjust the carrying value of these assets to their estimated fair value, determined based on the expected sales price as negotiated with the purchaser, less costs to sell. There were no similar impairment charges related to these assets recorded during the three and six months ended June 30, 2017. The following table presents balance sheet data related to the assets and liabilities held for sale related to the Foreman Butte Divestiture, including the write down for impairment loss, as of June 30, 2018:
Subsequent event. On July 2018, the Company signed a purchase and sale agreement to sell certain additional non-strategic operated assets in the Williston Basin for cash proceeds of $55.0 million. Upon signing the purchase and sale agreement, the Company recorded the related assets and liabilities as held for sale, which had a net book value of $33.9 million and $0.4 million, respectively. The transaction had an effective date of March 1, 2018, and the final closing statement will be completed in the first quarter of 2019. As of June 30, 2018, there was no impact to the Company’s condensed consolidated financial statements for this subsequent event. |
Long-Term Debt |
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Debt Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Long-Term Debt | Long-Term Debt The Company’s long-term debt consists of the following:
The carrying amount of the Company’s long-term debt reported in the Condensed Consolidated Balance Sheet at June 30, 2018 was $2,757.5 million, which included $2,039.4 million of senior unsecured notes, reductions for the unamortized debt discount related to the equity component of the senior unsecured convertible notes and the unamortized deferred financing costs on the senior unsecured notes of $75.0 million and $22.9 million, respectively, $651.0 million of borrowings under the Oasis Credit Facility and $165.0 million of borrowings under a $200.0 million senior secured revolving credit facility among OMP, as parent, OMP Operating LLC, a subsidiary of OMP, as borrower, Wells Fargo Bank, N.A., as administrative agent and the lenders party thereto (the “OMP Credit Facility,” and, together with the Oasis Credit Facility, the “Revolving Credit Facilities”). The Revolving Credit Facilities are recorded at values that approximate fair value since their variable interest rates are tied to current market rates. The fair value of the Company’s senior unsecured notes, which are publicly traded and therefore categorized as Level 1 liabilities, was $2,156.0 million at June 30, 2018. Senior secured revolving line of credit. The Company has the Oasis Credit Facility with an overall senior secured line of credit of $2,500.0 million as of June 30, 2018, which has a maturity date of April 13, 2020. The Oasis Credit Facility is restricted to a borrowing base, which is reserve-based and subject to semi-annual redeterminations on April 1 and October 1 of each year. On February 26, 2018, the Company entered into an amendment to the Oasis Credit Facility, resulting in the aggregate elected commitment being increased from $1,150.0 million to $1,350.0 million and two new lenders being added to the bank group. On April 19, 2018, the lenders under the Oasis Credit Facility completed their regular semi-annual redetermination of the borrowing base scheduled for April 1, 2018, resulting in the Company entering into the Twelfth Amendment to the Second Amended and Restated Credit Agreement to the Oasis Credit Facility, which (i) reaffirmed the borrowing base and the aggregate elected commitment at $1,600.0 million and $1,350.0 million, respectively, (ii) removed the legacy anti-cash hoarding provisions, (iii) reduced the coverage threshold with respect to mortgaged properties and (iv) amended the asset sale covenant to give the Company additional flexibility to trade oil and gas properties. In addition, in connection with such amendment, OP Permian became a guarantor under the Oasis Credit Facility. The next redetermination of the Oasis Credit Facility’s borrowing base is scheduled for October 1, 2018. At June 30, 2018, the Company had $651.0 million of London Interbank Offered Rate (“LIBOR”) loans at a weighted average interest rate of 3.8% and $14.0 million of outstanding letters of credit issued under the Oasis Credit Facility, resulting in an unused borrowing base committed capacity of $685.0 million. On a quarterly basis, the Company also pays a commitment fee that can range from 0.375% to 0.500% on the average amount of borrowing base capacity not utilized during the quarter and fees calculated on the average amount of letter of credit balances outstanding during the quarter. The Company was in compliance with the financial covenants of the Oasis Credit Facility as of June 30, 2018. OMP Operating LLC revolving line of credit. Through its ownership of OMP, the Company has the OMP Credit Facility with a revolving line of credit of $200.0 million, which has a maturity date of September 25, 2022. The OMP Credit Facility is available to fund working capital and to finance acquisitions and other capital expenditures of OMP. The OMP Credit Facility includes a letter of credit sublimit of $10.0 million and a swingline loans sublimit of $10.0 million. The borrowing capacity on the OMP Credit Facility may be increased up to $400.0 million, subject to certain conditions. Borrowings under the OMP Credit Facility bear interest at a rate per annum equal to the applicable margin (as described below) plus (i) with respect to Eurodollar Loans, the Adjusted LIBO Rate (as defined in the OMP Credit Agreement) or (ii) with respect to ABR Loans, the greatest of (A) the Prime Rate in effect on such day, (B) the Federal Funds Effective Rate in effect on such day plus 1/2 of 1.00% or (C) the Adjusted LIBO Rate for a one-month interest period on such day plus 1.00% (each as defined in the OMP Credit Agreement). The applicable margin for borrowings under the OMP Credit Facility varies from (a) in the case of Eurodollar Loans, 1.75% to 2.75%, and (b) in the case of ABR Loans or swingline loans, 0.75% to 1.75%. The unused portion of the OMP Credit Facility is subject to a commitment fee ranging from 0.375% to 0.500%. The OMP Credit Facility includes certain financial covenants as of the end of each fiscal quarter, including a (1) consolidated leverage ratio, (2) consolidated secured leverage ratio and (3) consolidated interest coverage ratio (each covenant as described in the OMP Credit Facility). OMP Operating LLC was in compliance with the financial covenants of the OMP Credit Facility as of June 30, 2018. All obligations of OMP Operating LLC, as the borrower under the OMP Credit Facility, are unconditionally guaranteed on a joint and several basis by OMP, OMP Operating LLC and Bighorn DevCo LLC. At June 30, 2018, the Company had $165.0 million of borrowings outstanding under the OMP Credit Facility. As of June 30, 2018, the weighted average interest rate on borrowings under the OMP Credit Facility was 3.8%. Senior unsecured notes. On May 14, 2018, the Company completed its offering of $400.0 million in aggregate principal amount of its 6.25% senior unsecured notes due 2026 (the “2026 Notes”). The Company used the net proceeds of $394.4 million from the 2026 Notes to fund the repurchase of certain outstanding senior notes (the “Tender Offers”), as described below. At June 30, 2018, the Company had $1,739.4 million principal amount of senior unsecured notes outstanding with maturities ranging from November 2021 to May 2026 and coupons ranging from 6.25% to 6.875% (the “Senior Notes”). Prior to certain dates, the Company has the option to redeem some or all of the Senior Notes for cash at certain redemption prices equal to a certain percentage of their principal amount plus an applicable make-whole premium and accrued and unpaid interest to the redemption date. On May 25, 2018, the Company completed the Tender Offers and, as a result of the Tender Offers, the Company repurchased an aggregate principal amount of $390.6 million of its outstanding Senior Notes, consisting of $31.3 million principal amount of its 7.25% senior unsecured notes due 2019 (the “2019 Notes”), $323.7 million principal amount of its 6.50% senior unsecured notes due 2021 and $35.6 million principal amount of its 6.875% senior unsecured notes due 2022, for an aggregate cost of $402.0 million, including accrued interest and fees. On May 29, 2018, the Company paid $23.0 million to redeem all of the remaining outstanding 2019 Notes, which payment consisted of the 100% redemption price plus all accrued and unpaid interest on the 2019 Notes. The Company financed the redemption with borrowings under the Oasis Credit Facility. As a result of the Tender Offers and the redemption, the Company recognized a pre-tax loss of $13.7 million, which was net of unamortized deferred financing costs write-offs of $4.0 million, and is reflected in loss on extinguishment of debt in the Company’s Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2018. As of June 30, 2018, no 2019 Notes remained outstanding. Senior unsecured convertible notes. At June 30, 2018, the Company had $300.0 million of 2.625% senior unsecured convertible notes due September 2023 (the “Senior Convertible Notes”). The Company has the option to settle conversions of these notes with cash, shares of common stock or a combination of cash and common stock at its election. The Company’s intent is to settle the principal amount of the Senior Convertible Notes in cash upon conversion. Prior to March 15, 2023, the Senior Convertible Notes will be convertible only under the following circumstances: (i) during any calendar quarter (and only during such calendar quarter), if the last reported sale price of the Company’s common stock for at least 20 trading days (whether or not consecutive) during the period of 30 consecutive trading days ending on the last trading day of the immediately preceding calendar quarter is greater than or equal to 130% of the conversion price on each applicable trading day; (ii) during the five business day period after any five consecutive trading day period (the “Measurement Period”) in which the trading price per $1,000 principal amount of the Senior Convertible Notes for each trading day of the Measurement Period is less than 98% of the product of the last reported sale price of the Company’s common stock and the conversion rate on each such trading day; or (iii) upon the occurrence of specified corporate events, including certain distributions or a fundamental change. On or after March 15, 2023, the Senior Convertible Notes will be convertible at any time until the second scheduled trading day immediately preceding their September 15, 2023 maturity date. The Senior Convertible Notes will be convertible at an initial conversion rate of 76.3650 shares of the Company’s common stock per $1,000 principal amount of the Senior Convertible Notes, which is equivalent to an initial conversion price of approximately $13.10. The conversion rate will be subject to adjustment in some events but will not be adjusted for any accrued and unpaid interest. In addition, following certain corporate events that occur prior to the maturity date or a notice of redemption, the Company will increase the conversion rate for a holder who elects to convert its Senior Convertible Notes in connection with such corporate event or redemption in certain circumstances. As of June 30, 2018, none of the contingent conditions allowing holders of the Senior Convertible Notes to convert these notes had been met. Upon issuance, the Company separately accounted for the liability and equity components of the Senior Convertible Notes in accordance with Accounting Standards Codification 470-20. The liability component was recorded at the estimated fair value of a similar debt instrument without the conversion feature. The difference between the principal amount of the Senior Convertible Notes and the estimated fair value of the liability component was recorded as a debt discount and will be amortized to interest expense over the term of the notes using the effective interest method, with an effective interest rate of 8.97% per annum. The fair value of the Senior Convertible Notes as of the issuance date was estimated at $206.8 million, resulting in a debt discount at inception of $93.2 million. The equity component, representing the value of the conversion option, was computed by deducting the fair value of the liability component from the initial proceeds of the Senior Convertible Notes issuance. This equity component was recorded, net of deferred taxes and issuance costs, in additional paid-in capital and will not be remeasured as long as it continues to meet the conditions for equity classification. Interest on the Senior Notes and the Senior Convertible Notes (collectively, the “Notes”) is payable semi-annually in arrears. The Notes are guaranteed on a senior unsecured basis by the Company, along with its material subsidiaries (the “Guarantors”), which are 100% owned by the Company. These guarantees are full and unconditional and joint and several among the Guarantors, subject to certain customary release provisions. The indentures governing the Notes contain customary events of default as well as covenants that place restrictions on the Company and certain of its subsidiaries. |
Asset Retirement Obligations |
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Asset Retirement Obligation Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||
Asset Retirement Obligations | Asset Retirement Obligations The following table reflects the changes in the Company’s ARO during the six months ended June 30, 2018:
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At June 30, 2018, the current portion of the total ARO balance was approximately $0.3 million and was included in accrued liabilities on the Company’s Condensed Consolidated Balance Sheets. |
Income Taxes |
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Income Tax Disclosure [Abstract] | |
Income Taxes | Income Taxes The Company’s effective tax rate for the three and six months ended June 30, 2018 was 24.2% and 24.3%, respectively, as compared to an effective tax rate of 12.4% and 31.3% for the three and six months ended June 30, 2017, respectively. The effective tax rate for the three and six months ended June 30, 2018 was higher than the statutory federal rate of 21% primarily due to state income taxes. The effective tax rate for the three and six months ended June 30, 2017 was lower than the statutory federal rate of 35% primarily due to the impact of non-deductible executive compensation on forecasted annual pre-tax loss and equity-based compensation windfalls, partially offset by state income taxes. Valuation allowance. The Company had valuation allowances of $3.3 million and $1.2 million as of June 30, 2018 and December 31, 2017, respectively, because the Company has concluded it is more likely than not that it will be unable to utilize certain state net operating loss carryforwards and charitable contribution carryforwards. As of each reporting date, the Company’s management considers new evidence, both positive and negative, which could impact management’s view with regard to future realization of deferred tax assets. During the six months ended June 30, 2018, the valuation allowance was increased by $2.1 million, primarily against the Company’s Montana net operating loss carryforwards, as a result of the Permian Basin Acquisition and the corresponding shift of projected future taxable income into other states. During the three months ended June 30, 2018, there was no material change to the valuation allowance. Tax Cuts and Jobs Act. On December 22, 2017, the U.S. government enacted the Tax Act, which made broad and complex changes to the U.S. tax code. Due to the complexities involved in the accounting for the enactment of the new law, the SEC issued SAB 118, which provides guidance on the accounting for the tax effects of the Tax Act. SAB 118 provides a measurement period that should not extend beyond one year from the Tax Act enactment date to complete the accounting under ASC 740, "Income Taxes." In accordance with SAB 118, the Company was able to make reasonable estimates on certain effects of the Tax Act in the financial statements as of December 31, 2017. There have been no material changes to the provisional estimate as disclosed in the Company’s 2017 Form 10-K. The Company will continue to analyze the impact of the new law and additional impacts will be recorded as they are identified during the measurement period provided for in SAB 118. |
Equity-Based Compensation |
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Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |||||||||||||||||||
Equity-Based Compensation | Equity-Based Compensation Restricted stock awards. The Company has granted restricted stock awards to employees and directors under its Amended and Restated 2010 Long Term Incentive Plan, the majority of which vest over a three-year period. The fair value of restricted stock awards is based on the closing sales price of the Company’s common stock on the date of grant. Compensation expense is recognized ratably over the requisite service period. During the six months ended June 30, 2018, employees and non-employee directors of the Company were granted restricted stock awards equal to 2,921,430 shares of common stock with a $9.61 weighted average grant date per share value. Equity-based compensation expense recorded for restricted stock awards for the three and six months ended June 30, 2018 was $4.9 million and $9.6 million, respectively, and $4.9 million and $10.3 million for the three and six months ended June 30, 2017, respectively. Equity-based compensation expense is included in general and administrative expenses on the Company’s Condensed Consolidated Statements of Operations. Performance share units. The Company has granted performance share units (“PSUs”) to officers of the Company under its Amended and Restated 2010 Long Term Incentive Plan. The PSUs are awards of restricted stock units, and each PSU that is earned represents the right to receive one share of the Company’s common stock. The Company accounts for PSUs as equity awards pursuant to the FASB’s authoritative guidance for share-based payments. The number of PSUs to be earned is subject to a market condition, which is based on a comparison of the total shareholder return (“TSR”) achieved with respect to shares of the Company’s common stock against the TSR achieved by a defined peer group at the end of the performance periods. Depending on the Company’s TSR performance relative to the defined peer group, award recipients will earn between 0% and 200% of the initial PSUs granted. All compensation expense related to the PSUs will be recognized if the requisite performance period is fulfilled, even if the market condition is not achieved. The aggregate grant date fair value of the market-based awards was determined using a Monte Carlo simulation model. The Monte Carlo simulation model uses assumptions regarding random projections and must be repeated numerous times to achieve a probabilistic assessment. The key valuation assumptions for the Monte Carlo model are the forecast period, initial value, stock price on the date of grant, risk-free interest rate, volatility and correlation coefficients. The risk-free interest rates are the U.S. Treasury bond rates on the date of grant that correspond to each performance period. The initial value is the average of the volume weighted average prices for the 30 trading days prior to the start of the performance cycle for the Company and each of its peers. Volatility was calculated from the daily historical returns of stock prices over a historical period for the Company and each of its peers. The correlation coefficients are measures of the strength of the linear relationship between and amongst the Company and its peers estimated based on historical stock price data. The following assumptions were used for the Monte Carlo model to determine the grant date fair value and associated equity-based compensation expense of the PSUs granted during the six months ended June 30, 2018:
During the six months ended June 30, 2018, officers of the Company were granted 854,400 PSUs with a $12.71 weighted average grant date per unit value. Equity-based compensation expense recorded for PSUs for the three and six months ended June 30, 2018 was $2.3 million and $4.2 million, respectively, and $2.2 million and $3.5 million for the three and six months ended June 30, 2017, respectively. Equity-based compensation expense is included in general and administrative expenses on the Company’s Condensed Consolidated Statements of Operations. OMP phantom unit awards. In September 2017, OMP GP adopted the Oasis Midstream Partners LP 2017 Long Term Incentive Plan (“OMP LTIP”). The OMP LTIP provides for the grant, from time to time at the discretion of the board of directors of OMP GP, of options, unit appreciation rights, restricted units, phantom units, unit awards, substitute awards, other unit-based awards or cash awards and includes any tandem distribution equivalent rights with respect to certain awards. Each award of phantom unit vests in equal amounts each year over a three-year period, and compensation expense will be recognized over the requisite service period. The Phantom Units are accounted for as liability-classified awards since the awards will settle in cash, and equity-based compensation cost is accounted for under the fair value method in accordance with GAAP. Under the fair value method for liability-classified awards, compensation cost is remeasured each reporting period at fair value based upon the closing price of a publicly traded common unit. The Company will reimburse OMP for the cash settlement amount of these awards, which is included in general and administrative expenses on the Company’s Condensed Consolidated Statements of Operations. Equity-based compensation expense relating to the OMP phantom unit awards for the three and six months ended June 30, 2018 was $0.1 million and $0.2 million, respectively. The Company did not record any equity-based compensation related to the OMP phantom unit awards for the three and six months ended June 30, 2017 because the awards were granted in the fourth quarter of 2017. OMP restricted unit awards. During the six months ended June 30, 2018, certain directors of OMP were granted 12,200 restricted unit awards which vest over a one-year period with a weighted average grant date fair value of $16.50 per common unit. These awards are accounted for as equity-classified awards since the awards will settle in common units upon vesting. Equity-based compensation cost is accounted for under the fair value method in accordance with GAAP. Under the fair value method for equity-classified awards, compensation cost is measured at the grant date based on the fair value of the award and is recognized over the vesting period. Compensation cost associated with these awards was approximately $0.1 million and $0.2 million for the three and six months ended June 30, 2018, respectively, and is included in general and administrative expenses on the Company’s Condensed Consolidated Statements of Operations. |
Earnings (Loss) Per Share |
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Earnings (Loss) Per Share | Earnings (Loss) Per Share Basic earnings (loss) per share is computed by dividing the earnings (loss) attributable to Oasis common stockholders by the weighted average number of shares outstanding for the periods presented. The calculation of diluted earnings (loss) per share includes the potential dilutive impact of unvested restricted stock awards and contingently issuable shares related to PSUs and senior convertible notes during the periods presented, unless their effect is anti-dilutive. There are no adjustments made to the income (loss) attributable to Oasis available to common stockholders in the calculation of diluted earnings (loss) per share. The following is a calculation of the basic and diluted weighted average shares outstanding for the three and six months ended June 30, 2018 and 2017:
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For the three and six months ended June 30, 2018, the Company incurred a net loss, and therefore the diluted loss per share calculation for those periods excludes the anti-dilutive effect of unvested stock awards. In addition, the Company excluded these unvested stock awards from the diluted earnings (loss) per share calculation for the three and six months ended June 30, 2017 because the effects were anti-dilutive based on the treasury stock method. The following is a calculation of weighted average common shares excluded from diluted earnings (loss) per share due to the anti-dilutive effect:
The Company issued its Senior Convertible Notes in September 2016 (see Note 11 – Long-Term Debt). The Company has the option to settle conversions of its Senior Convertible Notes with cash, shares of common stock or a combination of cash and common stock at its election. The Company’s intent is to settle the principal amount of the Senior Convertible Notes in cash upon conversion. As a result, only the amount by which the conversion value exceeds the aggregate principal amount of the notes (conversion spread) is considered in the diluted earnings per share computation under the treasury stock method. As of June 30, 2018, the conversion value did not exceed the principal amount of the notes, and accordingly, there was no impact to diluted earnings per share for the three and six months ended June 30, 2018. |
Business Segment Information |
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Segment Reporting [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Business Segment Information | Business Segment Information The Company’s exploration and production segment is engaged in the acquisition and development of oil and natural gas properties. Revenues for the exploration and production segment are derived from the sale of oil and natural gas production. The Company’s midstream services business segment (OMS) performs produced and flowback water gathering and disposal services, fresh water services, natural gas gathering and processing and crude oil gathering and transportation and other midstream services for the Company’s oil and natural gas wells operated by OPNA and other third-party operators. Revenues for the midstream segment are primarily derived from produced and flowback water pipeline transport, produced and flowback water disposal, fresh water sales, natural gas gathering and processing and crude oil gathering, blending, stabilization and transportation. The Company’s well services business segment (OWS) performs completion services for the Company’s oil and natural gas wells operated by OPNA. Revenues for the well services segment are derived from providing well services, product sales and equipment rentals. The revenues and expenses related to work performed by OMS and OWS for OPNA’s working interests are eliminated in consolidation, and only the revenues and expenses related to non-affiliated working interest owners are included in the Company’s Condensed Consolidated Statements of Operations. These segments represent the Company’s three operating units, each offering different products and services. The Company’s corporate activities have been allocated to the supported business segments accordingly. Management evaluates the performance of the Company’s business segments based on operating income, which is defined as segment operating revenues less operating expenses, including depreciation, depletion and amortization (“DD&A”). The following table summarizes financial information for the Company’s three business segments for the periods presented:
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Commitments and Contingencies |
6 Months Ended |
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Jun. 30, 2018 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies | Commitments and Contingencies Included below is a discussion of the Company’s various future commitments as of June 30, 2018. The commitments under these arrangements are not recorded in the accompanying Condensed Consolidated Balance Sheets. The amounts disclosed represent undiscounted cash flows on a gross basis, and no inflation elements have been applied. Volume commitment agreements. As of June 30, 2018, the Company had certain agreements with an aggregate requirement to deliver or transport a minimum quantity of approximately 55.0 MMBbl of crude oil, 20.3 MMBbl of natural gas liquids, 213.2 Bcf of natural gas, 14.8 MMBbl of freshwater and 4.4 MMBbl of produced water, prior to any applicable volume credits, within specified timeframes, all of which are ten years or less. The estimable future commitments under these agreements were approximately $526.6 million as of June 30, 2018. The future commitments under certain agreements cannot be estimated as they are based on fixed differentials relative to NYMEX WTI under the agreements as compared to the differential relative to NYMEX WTI for the Williston Basin for the production month. Litigation. The Company is party to various legal and/or regulatory proceedings from time to time arising in the ordinary course of business. When the Company determines that a loss is probable of occurring and is reasonably estimable, the Company accrues an undiscounted liability for such contingencies based on its best estimate using information available at the time. The Company discloses contingencies where an adverse outcome may be material, or in the judgment of management, the matter should otherwise be disclosed. Mirada litigation. On March 23, 2017, Mirada Energy, LLC, Mirada Wild Basin Holding Company, LLC and Mirada Energy Fund I, LLC (collectively, “Mirada”) filed a lawsuit against Oasis, OPNA and Oasis Midstream Services LLC, seeking monetary damages in excess of $100 million, declaratory relief, attorneys’ fees and costs (Mirada Energy, LLC, et al. v. Oasis Petroleum North America LLC, et al.; in the 334th Judicial District Court of Harris County, Texas; Case Number 2017-19911). Mirada asserts that it is a working interest owner in certain acreage owned and operated by the Company in Wild Basin. Specifically, Mirada asserts that the Company has breached certain agreements by: (1) failing to allow Mirada to participate in the Company’s midstream operations in Wild Basin; (2) refusing to provide Mirada with information that Mirada contends is required under certain agreements and failing to provide information in a timely fashion; (3) failing to consult with Mirada and failing to obtain Mirada’s consent prior to drilling more than one well at a time in Wild Basin; and (4) by overstating the estimated costs of proposed well operations in Wild Basin. Mirada seeks a declaratory judgment that the Company be removed as operator in Wild Basin at Mirada’s election and that Mirada be allowed to elect a new operator; certain agreements apply to the Company and Mirada and Wild Basin with respect to this dispute; the Company be required to provide all information within its possession regarding proposed or ongoing operations in Wild Basin; and the Company not be permitted to drill, or propose to drill, more than one well at a time in Wild Basin without obtaining Mirada’s consent. Mirada also seeks a declaratory judgment with respect to the Company’s current midstream operations in Wild Basin. Specifically, Mirada seeks a declaratory judgment that Mirada has a right to participate in the Company’s Wild Basin midstream operations, consisting of produced water disposal, crude oil gathering and gas gathering and processing; that, upon Mirada’s election to participate, Mirada is obligated to pay its proportionate costs of the Company’s midstream operations in Wild Basin; and that Mirada would then be entitled to receive a share of revenues from the midstream operations and would not be charged any amount for its use of these facilities for production from the “Contract Area.” On June 30, 2017, Mirada amended its original petition to add a claim that the Company has breached certain agreements by charging Mirada for midstream services provided by its affiliates and to seek a declaratory judgment that Mirada is entitled to be paid its share of total proceeds from the sale of hydrocarbons received by OPNA or any affiliate of OPNA without deductions for midstream services provided by OPNA or its affiliates. On February 2, 2018 and February 16, 2018, Mirada filed a second and third amended petition, respectively. In these filings, Mirada alleges new legal theories for being entitled to enforce the underlying contracts and added Bighorn DevCo LLC, Bobcat DevCo LLC and Beartooth DevCo LLC as defendants, asserting that these entities were created in bad faith in an effort to avoid contractual obligations owed to Mirada. The Company believes that Mirada’s claims are without merit, that the Company has complied with its obligations under the applicable agreements and that some of Mirada’s claims are grounded in agreements that do not apply to the Company. The Company filed an answer denying all of Mirada’s claims and intends and continues to vigorously defend against Mirada’s claims. Discovery is ongoing, and each of the parties has made a number of procedural filings and motions, and additional filings and motions can be expected over the course of the claim. Trial is currently scheduled for May 2019. However, the Company cannot predict or guarantee the ultimate outcome or resolution of such matter. If such matter were to be determined adversely to the Company’s interests, or if the Company were forced to settle such matter for a significant amount, such resolution or settlement could have a material adverse effect on the Company’s business, financial condition, results of operations or cash flows. Such an adverse determination could materially impact the Company’s ability to operate its properties in Wild Basin or develop its identified drilling locations in Wild Basin on its current development schedule. A determination that Mirada has a right to participate in the Company’s midstream operations could materially reduce the interests of the Company in their current assets and future midstream opportunities and related revenues in Wild Basin. In addition, the Company has agreed to indemnify OMP for any losses resulting from this litigation under the omnibus agreement it entered into with OMP at the time of OMP’s initial public offering. |
Condensed Consolidating Financial Information |
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Organization, Consolidation and Presentation of Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Condensed Consolidating Financial Information | Condensed Consolidating Financial Information The Notes (see Note 11 – Long-Term Debt) are guaranteed on a senior unsecured basis by the Guarantors, which are 100% owned by the Company. These guarantees are full and unconditional and joint and several among the Guarantors. Certain of the Company’s operating units, including OMP, which is accounted for on a consolidated basis, do not guarantee the Notes (“Non-Guarantor Subsidiaries”). The following financial information reflects consolidating financial information of the parent company, Oasis Petroleum Inc. (“Issuer”), its Guarantors on a combined basis and the Non-Guarantor Subsidiaries on a combined basis, prepared on the equity basis of accounting. The information is presented in accordance with the requirements of Rule 3-10 under the SEC’s Regulation S-X. The financial information may not necessarily be indicative of results of operations, cash flows or financial position had the Guarantors operated as independent entities. The Company has not presented separate financial and narrative information for each of the Guarantors because it believes such financial and narrative information would not provide any additional information that would be material in evaluating the sufficiency of the Guarantors. Condensed Consolidating Balance Sheet
Condensed Consolidating Balance Sheet
Condensed Consolidating Statement of Operations
Condensed Consolidating Statement of Operations
Condensed Consolidating Statement of Operations
Condensed Consolidating Statement of Operations
Condensed Consolidating Statement of Cash Flows
Condensed Consolidating Statement of Cash Flows
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Subsequent Events |
6 Months Ended |
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Jun. 30, 2018 | |
Subsequent Events [Abstract] | |
Subsequent Events | Subsequent Events The Company has evaluated the period after the balance sheet date, noting no subsequent events or transactions that required recognition or disclosure in the financial statements, other than as previously disclosed. |
Summary of Significant Accounting Policies (Policies) |
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Accounting Policies [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Basis of Presentation | Basis of Presentation The accompanying condensed consolidated financial statements of the Company have not been audited by the Company’s independent registered public accounting firm, except that the Condensed Consolidated Balance Sheet at December 31, 2017 is derived from audited financial statements. Certain reclassifications of prior year balances have been made to conform such amounts to current year classifications. These reclassifications have no impact on net income. In the opinion of management, all adjustments, consisting of normal recurring adjustments necessary for the fair statement of the Company’s financial position, have been included. Management has made certain estimates and assumptions that affect reported amounts in the condensed consolidated financial statements and disclosures of contingencies. Actual results may differ from those estimates. The results for interim periods are not necessarily indicative of annual results. These interim financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Certain disclosures have been condensed or omitted from these financial statements. Accordingly, they do not include all of the information and notes required by accounting principles generally accepted in the United States of America (“GAAP”) for complete consolidated financial statements and should be read in conjunction with the Company’s audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017 (“2017 Annual Report”). |
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Consolidation | Consolidation. The accompanying condensed consolidated financial statements of the Company include the accounts of Oasis, the accounts of wholly-owned subsidiaries, and the accounts of OMP, which is considered a variable interest entity (“VIE”) for which the Company is the primary beneficiary. All significant intercompany balances and transactions have been eliminated upon consolidation. |
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Consolidated VIE | Consolidated VIE. The Company has determined that the partners with equity at risk in OMP lack the authority, through voting rights or similar rights, to direct the activities that most significantly impact OMP’s economic performance. Therefore, as the limited partners of OMP do not have substantive kick-out or substantive participating rights over OMP GP LLC (“OMP GP”), the general partner to OMP, OMP is a VIE. Through the Company’s ownership interest in OMP GP, the Company has the authority to direct the activities that most significantly affect economic performance and the right to receive benefits that could be potentially significant to OMP. Therefore, the Company is considered the primary beneficiary and consolidates OMP and records a non-controlling interest for the interest owned by the public as of June 30, 2018. |
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Risks and Uncertainties | Risks and Uncertainties As an oil and natural gas producer, the Company’s revenue, profitability and future growth are substantially dependent upon the prevailing and future prices for oil and natural gas, which are dependent upon numerous factors beyond its control such as economic, political and regulatory developments and competition from other energy sources. The energy markets have historically been very volatile, and there can be no assurance that oil and natural gas prices will not be subject to wide fluctuations in the future. A substantial or extended decline in prices for oil and, to a lesser extent, natural gas could have a material adverse effect on the Company’s financial position, results of operations, cash flows and quantities of oil and natural gas reserves that may be economically produced. |
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Revenue Recognition | Revenue recognition. In the first quarter of 2018, the Company adopted Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). The objective of ASU 2014-09 is greater consistency and comparability across industries by using a five-step model to recognize revenue from customer contracts. ASU 2014-09 was applied on a modified retrospective basis. The adoption of ASU 2014-09 did not result in a material impact to the Company’s financial position, cash flows or results of operations. Enhanced disclosures in accordance with ASU 2014-09 have been provided in Note 3 – Revenue Recognition. In May 2014, the FASB issued a new accounting standard related to revenue recognition, ASC 606 - Revenue from Contracts with Customers (“ASC 606”). This standard was effective in first quarter 2018 and the Company adopted the new standard using the modified retrospective method. The Company applied ASC 606 to all new contracts entered into after January 1, 2018 and all existing contracts for which all (or substantially all) of the revenue has not been recognized under legacy revenue guidance as of December 31, 2017. ASC 606 supersedes previous revenue recognition requirements in ASC 605 and includes a five-step revenue recognition model to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the Company expects to be entitled in exchange for those goods or services. In accordance with the adoption of ASC 606, management evaluated its contracts with customers to apply the five-step revenue recognition model. The adoption of ASC 606 did not result in a material impact to the Company’s financial position, cash flows or results of operations. The unit of account in ASC 606 is a performance obligation, which is a promise in a contract to transfer to a customer either a distinct good or service (or bundle of goods or services) or a series of distinct goods or services provided over a period of time. ASC 606 requires that a contract’s transaction price, which is the amount of consideration to which an entity expects to be entitled in exchange for transferring promised goods or services to a customer, is to be allocated to each performance obligation in the contract based on relative standalone selling prices and recognized as revenue when (point in time) or as (over time) the performance obligation is satisfied. Exploration and production revenues Our exploration and production revenues are derived from contracts for oil, natural gas and natural gas liquids (“NGL”) sales, as described below. Generally, for the majority of these contracts: (i) each unit (barrel (“bbl”), mcf, gallon, etc.) of commodity product is a separate performance obligation, as our promise is to sell multiple distinct units of commodity product at a point in time; (ii) the transaction price principally consists of variable consideration, which amount is determinable each month end based on our right to invoice at month end for the value of commodity product sold to the customer that month; and (iii) the transaction price is allocated to each performance obligation based on the commodity product’s standalone selling price and recognized as revenue upon delivery of the commodity product, which is the point in time when the customer obtains control of the commodity product and our performance obligation is satisfied. The sales of oil, natural gas and NGLs as presented on the Company’s Condensed Consolidated Statements of Operations represent the Company’s share of revenues net of royalties and excluding revenue interests owned by others. When selling oil, natural gas and NGLs on behalf of royalty owners or working interest owners, the Company is acting as an agent and thus reports the revenue on a net basis. To the extent actual volumes and prices of oil and natural gas sales are unavailable for a given reporting period because of timing or information not received from third parties, the expected sales volumes and prices for those properties are estimated and recorded. The Company’s contracts with customers typically require payments for oil, natural gas and NGL sales within 30 days following the calendar month of delivery. Oil sales. The Company sells a substantial majority of its oil through bulk sales at delivery points on crude oil gathering systems or directly at the wellhead to a variety of customers under short-term contracts that include a specified quantity of crude oil to be delivered and sold to the customer at a specified delivery point. The customer pays a market-based transaction price, which incorporates differentials that include, but are not limited to, transportation costs and adjustments for product quality. Natural gas sales. The Company’s natural gas sales consist of unprocessed gas sales and residue gas sales. Unprocessed gas is sold at delivery points at or near the wellhead under percentage of proceeds contracts, in which the customer pays a transaction price based on its sale of the bifurcated NGLs and residue gas, less any associated fees. Revenue is recorded on a net basis, with processing fees deducted within revenue rather than as a separate expense line item, as title and control transfer at the delivery point. Residue gas is sold from the tailgate of the Company’s gas processing plant located in Wild Basin or transported and sold at other downstream sales points, and the customer pays a transaction price based on a market indexed per-unit rate for the quantities sold. Purchased oil and gas sales. The Company purchases and sells crude oil and natural gas at various delivery points to a variety of customers under short-term contracts that include specified quantities of crude oil and natural gas to be sold and delivered to the customer at a specified delivery point. The Company purchases and sells crude oil and natural gas to different counterparties at market-based prices. Market-based pricing is based on the price index applicable for the location of the sale. The Company accounts for these transactions on a gross basis. NGL sales. NGLs are sold from the Company’s gas processing plant complex located in Wild Basin or trucked and sold at other downstream locations, and the customer pays a transaction price based on a market indexed per-unit rate for the quantities sold. Prior period performance obligations. For sales of oil, purchased oil, natural gas, purchased gas and NGLs, the Company records revenue in the month production is delivered to the purchaser. However, settlement statements and payment may not be received for 30 to 90 days after the date production is delivered, and as a result, the Company is required to estimate the amount of production that was delivered to the purchaser and the price that will be received for the sale of the product. The Company records the differences between estimates and the actual amounts received for product sales once payment is received from the purchaser. Such differences have historically not been significant. The Company uses knowledge of its properties, its properties' historical performance, spot market prices and other factors as the basis for these estimates. For the three and six months ended June 30, 2018, revenue recognized related to performance obligations satisfied in prior reporting periods was not material. Revenues associated with contracts with customers for oil, natural gas and NGL sales were as follows for the three and six months ended June 30, 2018 and 2017:
Midstream revenues Crude oil and natural gas revenues. The Company is party to certain contracts for gas gathering, compression, processing and gas lift services, as well as crude oil gathering, stabilization, blending, storage and transportation. Under these customer contracts, the Company provides daily integrated midstream services on a stand ready basis over a period of time, which represents a single performance obligation since the customer simultaneously receives and consumes the benefits of these services on a daily basis. Satisfaction of the Company’s performance obligation is measured as each day of service is completed, which directly corresponds with its right to consideration from the customer. Revenues associated with these contracts are recognized based upon the transaction price at month-end under the right to invoice practical expedient. Payments from customers are generally received by the Company within one month after the month in which services are provided. Purchased oil sales. The Company purchases and sells crude oil at various delivery points on crude oil gathering systems to a variety of customers under short-term contracts that include a specified quantity of crude oil to be sold and delivered to the customer at a specified delivery point. The Company purchases and sells the crude oil to different counterparties at market-based prices. Market-based pricing is based on the price index applicable for the location of the sale. The Company accounts for these transactions on a gross basis. Water revenues. The Company is also party to certain contracts with customers for water services, which includes produced and flowback water gathering and disposal services and freshwater distribution services. Under its customer contracts for produced and flowback water gathering and disposal services, the Company provides daily integrated midstream services on a stand ready basis over a period of time, which represents a single performance obligation since the customer simultaneously receives and consumes the benefits of these services on a daily basis. Satisfaction of the Company’s performance obligation is measured as each day of service is completed, which directly corresponds with its right to consideration from the customer. Revenues associated with these contracts are recognized based upon the transaction price at month-end under the right to invoice practical expedient. Payments from customers are generally received by the Company within one month after the month in which services are provided. Under its customer contracts for freshwater distribution services, the Company supplies and distributes freshwater to its customers for hydraulic fracturing and production optimization. Management has determined these contracts contain multiple distinct performance obligations since each freshwater barrel is not dependent nor highly interrelated with other barrels. Revenue associated with freshwater distribution services is recognized at a point-in-time based upon the transaction price when title, control and risk of loss transfers to the customer, which occurs at the delivery point. Payments are due from customers 30 days after receipt of invoice. Revenues associated with contracts with customers for midstream services were as follows for the three and six months ended June 30, 2018 and 2017:
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Well services revenues Hydraulic fracturing service revenues. Hydraulic fracturing revenue is recognized upon the completion of each hydraulic fracturing of a well. These services are composed of various components, such as personnel, equipment and hydraulic fracturing materials, but management determined that each component is not distinct, as it cannot be used on its own or together with a resource readily available to the customer. Revenue is recognized when the performance obligations of hydraulic fracturing a well in its totality are completed; generally, this is over a period of time due to all work being performed for a customer occurring on the customer’s property, where the customer has control over the work in process as it is being performed. In addition, the Company’s assets being used to perform the obligations have no alternative use at the time of performance and the Company has the right to payment for performance to date. Payments from customers are generally received by the Company within one month after the month in which services are provided. In addition, revenue from product sales to third parties is generated when OPNA requests that third-party hydraulic fracturing companies hydraulic fracture OPNA’s wells. Although the labor is provided by the third-party hydraulic fracturing company, the materials (e.g., sand, chemicals, etc.) used in the hydraulic fracturing of the wells are provided by OWS. The third-party hydraulic fracturing company or OPNA pays OWS for the materials delivered to the wells. Revenue is recognized once the performance obligations to transfer hydraulic fracturing materials are completed. Equipment rental revenues. Equipment rental revenue is generated when OPNA or a third-party hydraulic fracturing company rents equipment from OWS. This equipment is used in the preparation stage of hydraulic fracturing services or after the hydraulic fracturing services have been completed. Equipment rental revenues are calculated based on the equipment’s daily rental rate and the number of days that the equipment was rented by the customer. OWS’s performance obligation is satisfied when the entire rental period is completed. Equipment rental revenues are recognized over a period of time due to the customer simultaneously receiving and consuming the benefits of the rental equipment provided by OWS on a daily basis. Satisfaction of the Company’s performance obligation is measured as each day of rental period is completed, which directly corresponds with its right to consideration from the customer. Revenues associated with these contracts are recognized at the time of invoicing for the entire rental period under the right to invoice practical expedient. Payments from customers are generally received by the Company within one month after the month in which services are provided. Revenues associated with contracts with customers for hydraulic fracturing services and equipment rental sales were as follows for the three and six months ended June 30, 2018 and 2017:
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Contract balances Under the Company's customer contracts, invoicing occurs once the Company's performance obligations have been satisfied, at which point payment is unconditional. Accordingly, the Company's contracts do not give rise to contract assets or liabilities under ASC 606. Performance obligations The majority of the Company’s sales are short-term in nature with a contract term of one year or less. For those contracts, the Company utilized the practical expedient in ASC 606-10-50-14 that exempts the Company from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less. For the Company’s product sales that have a contract term greater than one year, the Company utilized the practical expedient in ASC 606-10-50-14(A) which states the Company is not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under these sales contracts, each unit of product generally represents a separate performance obligation; therefore future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required. Under the midstream services contracts, each unit of service represents a separate performance obligation and therefore performance obligations in respect of future services are wholly unsatisfied. |
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Financial Instruments | Financial instruments. In the first quarter of 2018, the Company adopted Accounting Standards Update No. 2016-01, Recognition and Measurement of Financial Assets and Financial Liabilities (“ASU 2016-01”), which requires that most equity instruments be measured at fair value with subsequent changes in fair value recognized in net income. ASU 2016-01 also impacts financial liabilities under the fair value option and the presentation and disclosure requirements for financial instruments. ASU 2016-01 does not apply to equity method investments or investments in consolidated subsidiaries. ASU 2016-01 was applied on a prospective basis and prior periods were not retrospectively adjusted. There was no material impact as a result of adoption as of June 30, 2018. |
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Statement of Cash Flows | Statement of cash flows. In the first quarter of 2018, the Company adopted Accounting Standards Update No. 2016-15, Statement of Cash Flows (“ASU 2016-15”), which is intended to reduce diversity in practice in how certain transactions are classified in the statement of cash flows. ASU 2016-15 was applied on a prospective basis and prior periods were not retrospectively adjusted. There was no material impact as a result of adoption as of June 30, 2018. |
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Income Taxes | Income taxes. In the first quarter of 2018, the Company adopted Accounting Standards Update No. 2016-16, Intra-Entity Transfers of Assets Other Than Inventory (“ASU 2016-16”), to improve the accounting for the income tax consequences of intra-entity transfers of assets other than inventory. ASU 2016-16 was applied on a prospective basis and prior periods were not retrospectively adjusted. There was no material impact as a result of adoption as of June 30, 2018. |
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Business Combinations | Business combinations. In the first quarter of 2018, the Company adopted Accounting Standards Update No. 2017-01, Clarifying the Definition of a Business (“ASU 2017-01”), which provides guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. ASU 2017-01 requires entities to use a screen test to determine when an integrated set of assets and activities is not a business or if the integrated set of assets and activities needs to be further evaluated against the framework. ASU 2017-01 was applied on a prospective basis and prior periods were not retrospectively adjusted. There was no material impact as a result of adoption as of June 30, 2018. |
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Equity-based Compensation | Equity-based compensation. In the first quarter of 2018, the Company adopted Accounting Standards Update No. 2017-09, Scope of Modification Accounting (“ASU 2017-09”), which provides guidance about which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting. ASU 2017-09 was applied on a prospective basis and prior periods were not retrospectively adjusted. There was no material impact as a result of adoption as of June 30, 2018. |
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Recent Accounting Pronouncements | Recent Accounting Pronouncements Leases. In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2016-02, Leases (“ASU 2016-02”), which requires a lessee to recognize lease payment obligations and a corresponding right-of-use asset to be measured at fair value on the balance sheet. ASU 2016-02 also requires certain qualitative and quantitative disclosures about the amount, timing and uncertainty of cash flows arising from leases. This standard does not apply to leases to explore for or use minerals, oil or natural gas resources, including the right to explore for those natural resources. ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, including interim periods within those years. In January 2018, the FASB issued Accounting Standards Update No. 2018-01, Land easement practical expedient for transition to Topic 842, which provides an optional transition practical expedient to not evaluate under Topic 842 existing or expired land easements that were not previously accounting for as leases under Topic 840, Leases. The Company plans to elect this practical expedient and is currently evaluating the effect that adopting the new lease guidance will have on its financial position, cash flows or results of operations. Income taxes. In March 2018, the FASB issued Accounting Standards Update No. 2018-05, Income Taxes (Topic 740) - Amendments to SEC Paragraphs Pursuant to SEC Staff Accounting Bulletin No. 118 (“ASU 2018-05”). The standard amends Accounting Standards Codification 740, Income Taxes (“ASC 740”) to provide guidance on accounting for the tax effects of the Tax Cuts and Jobs Act (the “Tax Act”) pursuant to Staff Accounting Bulletin No. 118, Income Tax Accounting Implications of the Tax Cuts and Jobs Act ("SAB 118"). The Company is currently evaluating the effect of the new tax guidance, but does not expect it to have a material impact on its financial position, cash flows or results of operations. See Note 13 – Income Taxes. |
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Inventory | Inventory, including long-term inventory, is stated at the lower of cost and net realizable value with cost determined on an average cost method. The Company assesses the carrying value of inventory and uses estimates and judgment when making any adjustments necessary to reduce the carrying value to net realizable value. Among the uncertainties that impact the Company’s estimates are the applicable quality and location differentials to include in the Company’s net realizable value analysis. Additionally, the Company estimates the upcoming liquidation timing of the inventory. Changes in assumptions made as to the timing of a sale can materially impact net realizable value. |
Revenue Recognition (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Revenue from Contract with Customer [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Disaggregation of Revenue | Revenues associated with contracts with customers for midstream services were as follows for the three and six months ended June 30, 2018 and 2017:
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Revenues associated with contracts with customers for oil, natural gas and NGL sales were as follows for the three and six months ended June 30, 2018 and 2017:
Revenues associated with contracts with customers for hydraulic fracturing services and equipment rental sales were as follows for the three and six months ended June 30, 2018 and 2017:
__________________
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Inventory (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventory Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Components of Inventory | Total inventory consists of the following:
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Components of Long-term Inventory | Total inventory consists of the following:
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Accounts Receivable, Net (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Receivables [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Accounts Receivable, Net | The following table sets forth the Company’s accounts receivable, net:
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Fair Value Measurements (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Disclosures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Hierarchy of Fair Value, Assets and Liabilities Measured on Recurring Basis | The following tables set forth by level, within the fair value hierarchy, the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis:
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Derivative Instruments (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Outstanding Commodity Derivative Instruments | At June 30, 2018, the Company had the following outstanding commodity derivative instruments:
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Gains and Losses from Commodity Derivative Instruments | The following table summarizes the location and amounts of gains and losses from the Company’s commodity derivative instruments recorded in the Company’s Condensed Consolidated Statements of Operations for the periods presented:
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Summary of Gross and Net Information about Commodity Derivative Assets | The following table summarizes the location and fair value of all outstanding commodity derivative instruments recorded in the Company’s Condensed Consolidated Balance Sheets:
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Summary of Gross and Net Information about Commodity Derivative Liabilities | The following table summarizes the location and fair value of all outstanding commodity derivative instruments recorded in the Company’s Condensed Consolidated Balance Sheets:
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Property, Plant and Equipment (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Property, Plant and Equipment | The following table sets forth the Company’s property, plant and equipment:
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Acquisition Acquisition (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Business Combinations [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Purchase Price Allocation | The following table summarizes the consideration paid for the Company’s acquisition and the fair value of the assets acquired and liabilities assumed as of the acquisition date. The purchase price allocation is preliminary and subject to adjustment, as the final closing statement was finalized in July 2018, subsequent to the second quarter of 2018.
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Pro Forma Information | Summarized below are the consolidated results of operations for the three and six months ended June 30, 2018, on an unaudited pro forma basis, as if the acquisition and related financing had occurred on January 1, 2017. The unaudited pro forma financial information was derived from the historical consolidated statements of operations of the Company and the statement of revenues and direct operating expenses for the Permian Basin Acquisition properties, which were derived from the historical accounting records of Forge Energy. The unaudited pro forma financial information does not purport to be indicative of results of operations that would have occurred had the acquisition and related financing occurred on the basis assumed above, nor is such information indicative of the Company’s expected future results of operations.
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Divestitures and Assets Held for Sale (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Discontinued Operations and Disposal Groups [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Assets and Liabilities Held for Sale | The following table presents balance sheet data related to the assets and liabilities held for sale related to the Foreman Butte Divestiture, including the write down for impairment loss, as of June 30, 2018:
The following table presents balance sheet data related to the assets and liabilities held for sale related to the Williston Non-Op Divestiture as of June 30, 2018:
|
Long-Term Debt (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Debt Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Long-Term Debt | The Company’s long-term debt consists of the following:
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Asset Retirement Obligations (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||
Asset Retirement Obligation Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Changes in Asset Retirement Obligations | The following table reflects the changes in the Company’s ARO during the six months ended June 30, 2018:
___________________
|
Equity-Based Compensation (Tables) |
6 Months Ended | ||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Jun. 30, 2018 | |||||||||||||||||||
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |||||||||||||||||||
Summary of Stock Based Compensation Assumptions | The following assumptions were used for the Monte Carlo model to determine the grant date fair value and associated equity-based compensation expense of the PSUs granted during the six months ended June 30, 2018:
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Earnings (Loss) Per Share (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earnings Per Share [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Weighted-Average Number of Shares Outstanding | The following is a calculation of the basic and diluted weighted average shares outstanding for the three and six months ended June 30, 2018 and 2017:
__________________
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Schedule of Common Shares Excluded From Diluted Earnings (Loss) per Share Calculation | The following is a calculation of weighted average common shares excluded from diluted earnings (loss) per share due to the anti-dilutive effect:
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Business Segment Information (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Segment Reporting [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Summarized Financial Information of Segments | The following table summarizes financial information for the Company’s three business segments for the periods presented:
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Condensed Consolidating Financial Information (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2018 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Condensed Consolidating Balance Sheet | Condensed Consolidating Balance Sheet
Condensed Consolidating Balance Sheet
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Condensed Consolidating Statement of Operations | Condensed Consolidating Statement of Operations
Condensed Consolidating Statement of Operations
Condensed Consolidating Statement of Operations
Condensed Consolidating Statement of Operations
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Condensed Consolidating Statement of Cash Flows | Condensed Consolidating Statement of Cash Flows
Condensed Consolidating Statement of Cash Flows
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Inventory- Schedule of Inventory (Details) - USD ($) $ in Thousands |
Jun. 30, 2018 |
Dec. 31, 2017 |
---|---|---|
Inventory | ||
Crude oil inventory | $ 7,000 | $ 10,427 |
Equipment and materials | 16,222 | 8,940 |
Total inventory | 23,222 | 19,367 |
Long-term inventory | ||
Linefill in third-party pipelines | 12,505 | 12,200 |
Long-term inventory | 12,505 | 12,200 |
Total | $ 35,727 | $ 31,567 |
Accounts Receivable, Net (Details) - USD ($) $ in Thousands |
Jun. 30, 2018 |
Dec. 31, 2017 |
---|---|---|
Accounts, Notes, Loans and Financing Receivable [Line Items] | ||
Accounts receivable, gross | $ 379,026 | $ 365,153 |
Allowance for Doubtful Accounts Receivable, Current | (946) | (1,573) |
Accounts Receivable, Net, Current | 378,080 | 363,580 |
Trade Accounts Receivable [Member] | ||
Accounts, Notes, Loans and Financing Receivable [Line Items] | ||
Accounts receivable, gross | 250,740 | 233,660 |
Joint Interest Accounts Receivable [Member] | ||
Accounts, Notes, Loans and Financing Receivable [Line Items] | ||
Accounts receivable, gross | 79,304 | 73,588 |
Other Accounts Receivable [Member] | ||
Accounts, Notes, Loans and Financing Receivable [Line Items] | ||
Accounts receivable, gross | $ 48,982 | $ 57,905 |
Fair Value Measurements - Additional Information (Details) - USD ($) $ in Millions |
Jun. 30, 2018 |
Dec. 31, 2017 |
---|---|---|
Fair Value Disclosures [Abstract] | ||
Derivative credit risk valuation adjustment, derivative liabilities | $ 3.5 | $ 2.8 |
Derivative Instruments - Realized and Unrealized Gains and Losses from Commodity Derivative Instruments (Details) - USD ($) $ in Thousands |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
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Derivative Instruments and Hedging Activities Disclosure [Abstract] | ||||
Net gain (loss) on derivative instruments | $ (120,285) | $ 50,532 | $ (191,401) | $ 106,607 |
Property, Plant and Equipment - Schedule of Property, Plant and Equipment (Details) - USD ($) $ in Thousands |
Jun. 30, 2018 |
Dec. 31, 2017 |
---|---|---|
Property, Plant and Equipment [Abstract] | ||
Proved oil and gas properties | $ 7,340,228 | $ 7,058,782 |
Less: Accumulated depreciation, depletion, amortization and impairment | (2,532,668) | (2,395,153) |
Proved oil and gas properties, net | 4,807,560 | 4,663,629 |
Unproved oil and gas properties | 1,084,606 | 780,173 |
Other property and equipment | 1,024,104 | 868,746 |
Less: Accumulated depreciation | (159,029) | (139,062) |
Other property and equipment, net | 865,075 | 729,684 |
Total property, plant and equipment, net | $ 6,757,241 | $ 6,173,486 |
Property, Plant and Equipment Property, Plant and Equipment - Additional Information (Details) - USD ($) $ in Millions |
Jun. 30, 2018 |
Dec. 31, 2017 |
---|---|---|
Proved Oil And Gas Properties [Member] | ||
Business Acquisition [Line Items] | ||
Estimate of future asset retirement costs | $ 44.0 | $ 39.9 |
Acquisition - Additional Information (Details) - Permian Basin Acquisition [Member] a in Thousands, $ in Thousands |
3 Months Ended | 6 Months Ended | |
---|---|---|---|
Feb. 14, 2018
USD ($)
a
shares
|
Jun. 30, 2018
USD ($)
|
Jun. 30, 2018
USD ($)
|
|
Business Acquisition [Line Items] | |||
Net acres acquired | a | 22 | ||
Cash | $ 549,770 | ||
Aggregate consideration paid in shares (shares) | shares | 46,000,000 | ||
Consideration paid to Forge Energy | $ 920,990 | ||
Actual total revenue of acquiree included in condensed financials | $ 20,000 | $ 31,600 | |
Actual operating income of acquiree included in condensed financials | 6,800 | 10,200 | |
Finite lived intangible asset | $ 1,000 | ||
Noncompete Agreements [Member] | |||
Business Acquisition [Line Items] | |||
Useful life of acquired intangible asset | 1 year | ||
Amortization of Intangible Assets | $ 300 | $ 400 |
Acquisition - Price Allocation (Details) - USD ($) $ in Thousands |
6 Months Ended | ||
---|---|---|---|
Feb. 14, 2018 |
Jun. 30, 2018 |
Jun. 30, 2017 |
|
Business Acquisition [Line Items] | |||
Common stock: 46,000,000 shares issued | $ 371,220 | $ 0 | |
Permian Basin Acquisition [Member] | |||
Business Acquisition [Line Items] | |||
Cash | $ 549,770 | ||
Common stock: 46,000,000 shares issued | $ 371,220 | ||
Common stock shares issued (shares) | 46,000,000 | ||
Consideration paid to Forge Energy: | $ 920,990 | ||
Proved developed properties | 110,735 | ||
Proved undeveloped properties | 167,170 | ||
Unproved lease acquisition costs | 644,040 | ||
Inventory | 293 | ||
Intangible assets | 1,000 | ||
Asset retirement obligations | $ (2,248) |
Acquisition - Pro-Forma Information (Details) - Permian Basin Acquisition [Member] - USD ($) $ / shares in Units, $ in Thousands |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
|
Business Acquisition [Line Items] | ||||
Revenues | $ 501,337 | $ 262,991 | $ 928,082 | $ 553,073 |
Net income attributable to Oasis | $ (320,204) | $ 23,877 | $ (315,073) | $ 51,785 |
Basic (in usd per share) | $ (1.02) | $ 0.09 | $ (1.01) | $ 0.19 |
Diluted (in usd per share) | $ (1.02) | $ 0.08 | $ (1.00) | $ 0.18 |
Divestitures and Assets Held for Sale - Schedule of Assets and Liabilities Held for Sale (Details) - Held for Sale [Member] $ in Thousands |
Jun. 30, 2018
USD ($)
|
---|---|
Williston Non-Op Divestiture [Member] | |
Assets: | |
Accounts receivable, net | $ 273 |
Oil and gas properties (successful efforts method) | 179,921 |
Less: accumulated depreciation, depletion, amortization and impairment | (61,652) |
Total assets held for sale, net | 118,542 |
Liabilities: | |
Asset retirement obligations | 1,605 |
Total liabilities held for sale | 1,605 |
Foreman Butte Divestiture [Member] | |
Assets: | |
Accounts receivable, net | 601 |
Inventory | 866 |
Oil and gas properties (successful efforts method) | 336,604 |
Other property and equipment | 11,865 |
Less: accumulated depreciation, depletion, amortization and impairment | (218,360) |
Total assets held for sale, net | 131,576 |
Liabilities: | |
Asset retirement obligations | 2,576 |
Total liabilities held for sale | $ 2,576 |
Asset Retirement Obligations - Schedule of Changes in Asset Retirement Obligations (Details) $ in Thousands |
6 Months Ended |
---|---|
Jun. 30, 2018
USD ($)
| |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |
December 31, 2017 | $ 48,799 |
Liabilities incurred during period | 4,008 |
Liabilities settled during period | (1) |
Accretion expense during period | 1,314 |
Liabilities held for sale(2) | 84 |
Asset Retirement Obligation, Liabilities Held for Sale | (4,167) |
June 30, 2018 | $ 50,037 |
Asset Retirement Obligations - Additional Information (Details) $ in Millions |
Jun. 30, 2018
USD ($)
|
---|---|
Asset Retirement Obligation Disclosure [Abstract] | |
Total asset retirement obligations, current portion | $ 0.3 |
Income Taxes - Additional Information (Details) - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended | |||
---|---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
Dec. 31, 2017 |
|
Income Tax Disclosure [Abstract] | |||||
Effective tax rate (as percent) | (24.20%) | 12.40% | (24.30%) | 31.30% | |
Valuation allowance on carryforwards | $ 3.3 | $ 3.3 | $ 1.2 | ||
Increase in valuation allowance | $ 2.1 |
Equity-Based Compensation - Summary of Assumptions (Details) - Performance Share Units [Member] - $ / shares |
6 Months Ended | |
---|---|---|
Jun. 30, 2018 |
Jan. 24, 2018 |
|
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||
Oasis stock price volatility (as percent) | 72.88% | |
Oasis initial value (usd per share) | $ 8.82 | |
Oasis stock price on date of grant (usd per share) | $ 9.27 | |
Minimum [Member] | ||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||
Risk-free interest rate (as percent) | 2.08% | |
Maximum [Member] | ||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||
Risk-free interest rate (as percent) | 2.31% |
Earnings (Loss) Per Share - Schedule of Weighted-Average Number of Shares Outstanding (Details) - shares shares in Thousands |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
|
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items] | ||||
Basic weighted average common shares outstanding (in shares) | 313,072 | 233,283 | 301,652 | 233,176 |
Diluted weighted average common shares outstanding (in shares) | 313,072 | 234,917 | 301,652 | 236,281 |
Stock Awards and PSUs [Member] | ||||
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items] | ||||
Dilution effect of stock awards at end of period (in shares) | 0 | 1,634 | 0 | 3,105 |
Earnings (Loss) Per Share - Schedule of Common Shares Excluded from Diluted Earnings (Loss) per Share (Details) - shares shares in Thousands |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2018 |
Jun. 30, 2017 |
Jun. 30, 2018 |
Jun. 30, 2017 |
|
Earnings Per Share [Abstract] | ||||
Anti-dilutive stock-based compensation awards (in shares) | 7,515 | 4,369 | 7,440 | 2,957 |
Business Segment Information - Additional Information (Details) |
6 Months Ended |
---|---|
Jun. 30, 2018
Segment
| |
Segment Reporting [Abstract] | |
Number of current operating units | 3 |
Commitments and Contingencies - Additional Information (Details) bbl in Millions, Mcf in Millions |
Mar. 23, 2017
USD ($)
|
Jun. 30, 2018
USD ($)
bbl
Mcf
|
---|---|---|
Loss Contingencies [Line Items] | ||
Estimable future commitments under agreements | $ | $ 526,600,000 | |
Mirada Litigation [Member] | Pending Litigation [Member] | ||
Loss Contingencies [Line Items] | ||
Damages sought (in excess of) | $ | $ 100,000,000 | |
Crude Oil [Member] | ||
Loss Contingencies [Line Items] | ||
Minimum quantity to be delivered or transported | 55.0 | |
Natural Gas Liquids [Member] | ||
Loss Contingencies [Line Items] | ||
Minimum quantity to be delivered or transported | 20.3 | |
Natural Gas [Member] | ||
Loss Contingencies [Line Items] | ||
Minimum quantity to be delivered or transported | Mcf | 213.2 | |
Fresh Water [Member] | ||
Loss Contingencies [Line Items] | ||
Minimum quantity to be delivered or transported | 12.5 | |
Produced Water [Member] | ||
Loss Contingencies [Line Items] | ||
Minimum quantity to be delivered or transported | 4.4 |
Condensed Consolidating Financial Information - Additional Information (Details) |
6 Months Ended |
---|---|
Jun. 30, 2018 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Ownership percentage, guarantors (as percent) | 100.00% |
Condensed Consolidating Financial Information - Schedule of Condensed Consolidating Balance Sheet - Additional Information (Details) - $ / shares |
Jun. 30, 2018 |
Dec. 31, 2017 |
---|---|---|
Organization, Consolidation and Presentation of Financial Statements [Abstract] | ||
Common stock, par value (in usd per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 450,000,000 | 450,000,000 |
Common stock, shares issued (in shares) | 320,010,534 | 270,627,014 |
Common stock, shares outstanding (in shares) | 317,985,056 | 269,295,466 |
Treasury stock, shares (in shares) | 2,025,478 | 1,331,548 |
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