Delaware (State or other jurisdiction of incorporation or organization) | 46-5670947 (I.R.S. Employer Identification No.) | |
27200 Tourney Road, Suite 315 Santa Clarita, California (Address of principal executive offices) | 91355 (Zip Code) |
Large Accelerated Filer | þ | Accelerated Filer | o | Non-Accelerated Filer | o |
Smaller Reporting Company | o | Emerging Growth Company | o |
Title of Each Class | Trading Symbol(s) | Name of Each Exchange on Which Registered |
Common Stock | CRC | New York Stock Exchange |
Shares of common stock outstanding as of March 31, 2019 | 48,800,217 |
Page | ||
Part I | ||
Item 1 | Financial Statements (unaudited) | |
Condensed Consolidated Balance Sheets | ||
Condensed Consolidated Statements of Operations | ||
Condensed Consolidated Statements of Comprehensive Income | ||
Condensed Consolidated Statements of Cash Flows | ||
Condensed Consolidated Statements of Equity | ||
Notes to the Condensed Consolidated Financial Statements | ||
Item 2 | Management’s Discussion and Analysis of Financial Condition and Results of Operations | |
General | ||
Business Environment and Industry Outlook | ||
Seasonality | ||
Joint Ventures | ||
Asset Divestiture | ||
Operations | ||
Fixed and Variable Costs | ||
Production and Prices | ||
Balance Sheet Analysis | ||
Statements of Operations Analysis | ||
Liquidity and Capital Resources | ||
2019 Capital Program | ||
Lawsuits, Claims, Commitments and Contingencies | ||
Significant Accounting and Disclosure Changes | ||
Forward-Looking Statements | ||
Item 3 | Quantitative and Qualitative Disclosures About Market Risk | |
Item 4 | Controls and Procedures | |
Part II | ||
Item 1 | Legal Proceedings | |
Item 1A | Risk Factors | |
Item 5 | Other Disclosures | |
Item 6 | Exhibits |
Item 1. | Financial Statements (unaudited) |
March 31, | December 31, | ||||||
2019 | 2018 | ||||||
CURRENT ASSETS | |||||||
Cash | $ | 43 | $ | 17 | |||
Trade receivables | 296 | 299 | |||||
Inventories | 71 | 69 | |||||
Other current assets, net | 167 | 255 | |||||
Total current assets | 577 | 640 | |||||
PROPERTY, PLANT AND EQUIPMENT | 22,734 | 22,523 | |||||
Accumulated depreciation, depletion and amortization | (16,186 | ) | (16,068 | ) | |||
Total property, plant and equipment, net | 6,548 | 6,455 | |||||
OTHER ASSETS | 105 | 63 | |||||
TOTAL ASSETS | $ | 7,230 | $ | 7,158 |
CURRENT LIABILITIES | |||||||
Current maturities of long-term debt | 100 | — | |||||
Accounts payable | 304 | 390 | |||||
Accrued liabilities | 285 | 217 | |||||
Total current liabilities | 689 | 607 | |||||
LONG-TERM DEBT | 5,169 | 5,251 | |||||
DEFERRED GAIN AND ISSUANCE COSTS, NET | 203 | 216 | |||||
OTHER LONG-TERM LIABILITIES | 692 | 575 | |||||
MEZZANINE EQUITY | |||||||
Redeemable noncontrolling interests | 766 | 756 | |||||
EQUITY | |||||||
Preferred stock (20 million shares authorized at $0.01 par value) no shares outstanding at March 31, 2019 and December 31, 2018 | — | — | |||||
Common stock (200 million shares authorized at $0.01 par value) outstanding shares (March 31, 2019 - 48,800,217 and December 31, 2018 - 48,650,420) | — | — | |||||
Additional paid-in capital | 4,989 | 4,987 | |||||
Accumulated deficit | (5,409 | ) | (5,342 | ) | |||
Accumulated other comprehensive loss | (6 | ) | (6 | ) | |||
Total equity attributable to common stock | (426 | ) | (361 | ) | |||
Equity attributable to noncontrolling interests | 137 | 114 | |||||
Total equity | (289 | ) | (247 | ) | |||
TOTAL LIABILITIES AND EQUITY | $ | 7,230 | $ | 7,158 |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
REVENUES AND OTHER | |||||||
Oil and gas sales | $ | 601 | $ | 575 | |||
Net derivative loss from commodity contracts | (89 | ) | (38 | ) | |||
Other revenue | 178 | 72 | |||||
Total revenues and other | 690 | 609 | |||||
COSTS AND OTHER | |||||||
Production costs | 233 | 212 | |||||
General and administrative expenses | 83 | 63 | |||||
Depreciation, depletion and amortization | 118 | 119 | |||||
Taxes other than on income | 41 | 38 | |||||
Exploration expense | 10 | 8 | |||||
Other expenses, net | 148 | 61 | |||||
Total costs and other | 633 | 501 | |||||
OPERATING INCOME | 57 | 108 | |||||
NON-OPERATING (LOSS) INCOME | |||||||
Interest and debt expense, net | (100 | ) | (92 | ) | |||
Net gain on early extinguishment of debt | 6 | — | |||||
Other non-operating expenses | (7 | ) | (7 | ) | |||
(LOSS) INCOME BEFORE INCOME TAXES | (44 | ) | 9 | ||||
Income tax | — | — | |||||
NET (LOSS) INCOME | (44 | ) | 9 | ||||
NET (INCOME) LOSS ATTRIBUTABLE TO NONCONTROLLING INTERESTS | |||||||
Mezzanine equity | (28 | ) | (14 | ) | |||
Equity | 5 | 3 | |||||
Net (income) loss attributable to noncontrolling interests | (23 | ) | (11 | ) | |||
NET LOSS ATTRIBUTABLE TO COMMON STOCK | $ | (67 | ) | $ | (2 | ) | |
Net loss attributable to common stock per share | |||||||
Basic | $ | (1.38 | ) | $ | (0.05 | ) | |
Diluted | $ | (1.38 | ) | $ | (0.05 | ) |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
Net (loss) income | $ | (44 | ) | $ | 9 | ||
Net income attributable to noncontrolling interests | (23 | ) | (11 | ) | |||
Other comprehensive income items: | |||||||
Reclassification of realized losses on pension and postretirement benefits to income(a) | — | 2 | |||||
Comprehensive loss attributable to common stock | $ | (67 | ) | $ | — |
(a) | No associated tax for the three months ended March 31, 2019 and 2018. See Note 10 Pension and Postretirement Benefit Plans for additional information. |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
CASH FLOW FROM OPERATING ACTIVITIES | |||||||
Net (loss) income | $ | (44 | ) | $ | 9 | ||
Adjustments to reconcile net (loss) income to net cash provided by operating activities: | |||||||
Depreciation, depletion and amortization | 118 | 119 | |||||
Net derivative loss from commodity contracts | 89 | 38 | |||||
Net proceeds (payments) on settled commodity derivatives | 14 | (31 | ) | ||||
Net gain on early extinguishment of debt | (6 | ) | — | ||||
Amortization of deferred gain | (18 | ) | (19 | ) | |||
Dry hole expenses | 3 | 2 | |||||
Other non-cash charges to income, net | 26 | 14 | |||||
Changes in operating assets and liabilities, net | (24 | ) | 68 | ||||
Net cash provided by operating activities | 158 | 200 | |||||
CASH FLOW FROM INVESTING ACTIVITIES | |||||||
Capital investments | (131 | ) | (139 | ) | |||
Changes in capital investment accruals | (47 | ) | 5 | ||||
Acquisitions | (2 | ) | (3 | ) | |||
Other | (2 | ) | (1 | ) | |||
Net cash used in investing activities | (182 | ) | (138 | ) | |||
CASH FLOW FROM FINANCING ACTIVITIES | |||||||
Proceeds from 2014 Revolving Credit Facility | 615 | 81 | |||||
Repayments of 2014 Revolving Credit Facility | (579 | ) | (444 | ) | |||
Debt repurchases | (14 | ) | (2 | ) | |||
Contributions from noncontrolling interest holders, net | 49 | 747 | |||||
Distributions paid to noncontrolling interest holders | (20 | ) | (18 | ) | |||
Issuance of common stock | — | 50 | |||||
Shares canceled for taxes | (1 | ) | (2 | ) | |||
Net cash provided by financing activities | 50 | 412 | |||||
Increase in cash | 26 | 474 | |||||
Cash—beginning of period | 17 | 20 | |||||
Cash—end of period | $ | 43 | $ | 494 |
Additional Paid-in Capital | Accumulated (Deficit) Earnings | Accumulated Other Comprehensive (Loss) Income | Equity Attributable to Common Stock | Equity Attributable to Noncontrolling Interests | Total Equity | ||||||||||||||||||
Balance, December 31, 2018 | $ | 4,987 | $ | (5,342 | ) | $ | (6 | ) | $ | (361 | ) | $ | 114 | $ | (247 | ) | |||||||
Net loss | — | (67 | ) | — | (67 | ) | (5 | ) | (72 | ) | |||||||||||||
Contribution from noncontrolling interest holders, net | — | — | — | — | 49 | 49 | |||||||||||||||||
Distributions to noncontrolling interest holders | — | — | — | — | (21 | ) | (21 | ) | |||||||||||||||
Issuance of common stock | — | — | — | — | — | — | |||||||||||||||||
Other comprehensive income | — | — | — | — | — | — | |||||||||||||||||
Share-based compensation, net | 2 | — | — | 2 | — | 2 | |||||||||||||||||
Balance, March 31, 2019 | $ | 4,989 | $ | (5,409 | ) | $ | (6 | ) | $ | (426 | ) | $ | 137 | $ | (289 | ) | |||||||
Balance, December 31, 2017 | $ | 4,879 | $ | (5,670 | ) | $ | (23 | ) | $ | (814 | ) | $ | 94 | $ | (720 | ) | |||||||
Net loss | — | (2 | ) | — | (2 | ) | (3 | ) | (5 | ) | |||||||||||||
Contribution from noncontrolling interest holders, net | — | — | — | — | 33 | 33 | |||||||||||||||||
Distributions to noncontrolling interest holders | — | — | — | — | (15 | ) | (15 | ) | |||||||||||||||
Issuance of common stock | 50 | — | — | 50 | — | 50 | |||||||||||||||||
Other comprehensive income | — | — | 2 | 2 | — | 2 | |||||||||||||||||
Share-based compensation, net | 1 | — | — | 1 | — | 1 | |||||||||||||||||
Balance, March 31, 2018 | $ | 4,930 | $ | (5,672 | ) | $ | (21 | ) | $ | (763 | ) | $ | 109 | $ | (654 | ) |
Note: | The above table excludes amounts related to redeemable noncontrolling interests recorded in mezzanine equity. See Note 6 Joint Ventures for more information. |
NOTE 2 | ACCOUNTING AND DISCLOSURE CHANGES |
NOTE 3 | OTHER INFORMATION |
March 31, | December 31, | ||||||
2019 | 2018 | ||||||
(in millions) | |||||||
Derivative assets | $ | 79 | $ | 168 | |||
Amounts due from joint interest partners | 68 | 68 | |||||
Prepaid expenses | 20 | 16 | |||||
Other | — | 3 | |||||
Other current assets, net | $ | 167 | $ | 255 |
March 31, | December 31, | ||||||
2019 | 2018 | ||||||
(in millions) | |||||||
Accrued employee-related costs | $ | 69 | $ | 109 | |||
Accrued interest | 56 | 15 | |||||
Accrued taxes other than on income | 51 | 38 | |||||
Asset retirement obligation | 32 | 31 | |||||
Operating lease liability | 27 | — | |||||
Accrued distribution to JV partner | 19 | — | |||||
Other | 31 | 24 | |||||
Accrued liabilities | $ | 285 | $ | 217 |
March 31, | December 31, | ||||||
2019 | 2018 | ||||||
(in millions) | |||||||
Materials and supplies | $ | 68 | $ | 65 | |||
Finished goods | 3 | 4 | |||||
Total | $ | 71 | $ | 69 |
Outstanding Principal (in millions) | Interest Rate | Maturity | Security | ||||||||||
March 31, 2019 | December 31, 2018 | ||||||||||||
Credit Agreements | |||||||||||||
2014 Revolving Credit Facility | $ | 576 | $ | 540 | LIBOR plus 3.25%-4.00% ABR plus 2.25%-3.00% | June 30, 2021 | Shared First-Priority Lien | ||||||
2017 Credit Agreement | 1,300 | 1,300 | LIBOR plus 4.75% ABR plus 3.75% | December 31, 2022(a) | Shared First-Priority Lien | ||||||||
2016 Credit Agreement | 1,000 | 1,000 | LIBOR plus 10.375% ABR plus 9.375% | December 31, 2021 | First-Priority Lien | ||||||||
Second Lien Notes | |||||||||||||
Second Lien Notes | 2,049 | 2,067 | 8% | December 15, 2022(b) | Second-Priority Lien | ||||||||
Senior Notes | |||||||||||||
5% Senior Notes due 2020 | 100 | 100 | 5% | January 15, 2020 | Unsecured | ||||||||
5½% Senior Notes due 2021 | 100 | 100 | 5.5% | September 15, 2021 | Unsecured | ||||||||
6% Senior Notes due 2024 | 144 | 144 | 6% | November 15, 2024 | Unsecured | ||||||||
Total Debt | 5,269 | 5,251 | |||||||||||
Less: Current Maturities | (100 | ) | — | ||||||||||
Long-Term Debt | $ | 5,169 | $ | 5,251 |
Note: | For a detailed description of our credit agreements, second lien notes and senior notes, please see our most recent Form 10-K for the year ended December 31, 2018. |
(a) | The 2017 Credit Agreement is subject to a springing maturity of 91 days prior to the maturity of our 2016 Credit Agreement if more than $100 million in principal of the 2016 Credit Agreement is outstanding at that time. |
(b) | The Second Lien Notes require principal repayments of approximately $324 million in June 2021, $65 million in December 2021, $67 million in June 2022 and $1,593 million in December 2022. |
NOTE 6 | JOINT VENTURES |
Equity Attributable to Noncontrolling Interest | Mezzanine Equity - Redeemable Noncontrolling Interests | ||||||||||||||
Ares JV | BSP JV | Total | Ares JV | ||||||||||||
(in millions) | |||||||||||||||
Balance, December 31, 2018 | $ | 15 | $ | 99 | $ | 114 | $ | 756 | |||||||
Net (loss) income attributable to noncontrolling interests | (3 | ) | (2 | ) | (5 | ) | 28 | ||||||||
Contributions from noncontrolling interest holders, net | — | 49 | 49 | — | |||||||||||
Distributions accrual | — | (19 | ) | (19 | ) | — | |||||||||
Distributions to noncontrolling interest holders | (2 | ) | — | (2 | ) | (18 | ) | ||||||||
Balance, March 31, 2019 | $ | 10 | $ | 127 | $ | 137 | $ | 766 | |||||||
Balance, December 31, 2017 | $ | — | $ | 94 | $ | 94 | $ | — | |||||||
Net income (loss) attributable to noncontrolling interests | 1 | (4 | ) | (3 | ) | 14 | |||||||||
Contributions from noncontrolling interest holders, net | 33 | — | 33 | 714 | |||||||||||
Distributions to noncontrolling interest holders | (1 | ) | (14 | ) | (15 | ) | (4 | ) | |||||||
Balance, March 31, 2018 | $ | 33 | $ | 76 | $ | 109 | $ | 724 |
Q2 2019 | Q3 2019 | Q4 2019 | Q1 2020 | ||||||||||||
Sold Calls: | |||||||||||||||
Barrels per day | 5,000 | — | — | — | |||||||||||
Weighted-average price per barrel | $ | 68.45 | $ | — | $ | — | $ | — | |||||||
Purchased Puts: | |||||||||||||||
Barrels per day | 40,000 | 40,000 | 35,000 | 10,000 | |||||||||||
Weighted-average price per barrel | $ | 69.75 | $ | 73.13 | $ | 75.71 | $ | 75.00 | |||||||
Sold Puts: | |||||||||||||||
Barrels per day | 35,000 | 40,000 | 35,000 | 10,000 | |||||||||||
Weighted-average price per barrel | $ | 55.71 | $ | 57.50 | $ | 60.00 | $ | 60.00 |
March 31, 2019 | ||||||||||||
Balance Sheet Classification | Gross Amounts Recognized at Fair Value | Gross Amounts Offset in the Balance Sheet | Net Fair Value Presented in the Balance Sheet | |||||||||
Assets: | ||||||||||||
Other current assets | $ | 99 | $ | (20 | ) | $ | 79 | |||||
Other assets | 2 | — | 2 | |||||||||
Liabilities: | ||||||||||||
Accrued liabilities | (24 | ) | 20 | (4 | ) | |||||||
Other long-term liabilities | (1 | ) | — | (1 | ) | |||||||
Total derivatives | $ | 76 | $ | — | $ | 76 |
December 31, 2018 | ||||||||||||
Balance Sheet Classification | Gross Amounts Recognized at Fair Value | Gross Amounts Offset in the Balance Sheet | Net Fair Value Presented in the Balance Sheet | |||||||||
Assets: | ||||||||||||
Other current assets | $ | 252 | $ | (84 | ) | $ | 168 | |||||
Other assets | 23 | (9 | ) | 14 | ||||||||
Liabilities: | ||||||||||||
Accrued liabilities | (87 | ) | 84 | (3 | ) | |||||||
Other long-term liabilities | (10 | ) | 9 | (1 | ) | |||||||
Total derivatives | $ | 178 | $ | — | $ | 178 |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
(in millions, except per-share amounts) | |||||||
Net (loss) income | $ | (44 | ) | $ | 9 | ||
Net income attributable to noncontrolling interests | (23 | ) | (11 | ) | |||
Net income (loss) attributable to common stock | (67 | ) | (2 | ) | |||
Less: net income allocated to participating securities | — | — | |||||
Net loss available to common stockholders | $ | (67 | ) | $ | (2 | ) | |
Weighted-average common shares outstanding - basic | 48.7 | 44.2 | |||||
Basic EPS | $ | (1.38 | ) | $ | (0.05 | ) | |
Net (loss) income | $ | (44 | ) | $ | 9 | ||
Net income attributable to noncontrolling interests | (23 | ) | (11 | ) | |||
Net loss attributable to common stock | (67 | ) | (2 | ) | |||
Less: net income allocated to participating securities | — | — | |||||
Net loss available to common stockholders | $ | (67 | ) | $ | (2 | ) | |
Weighted-average common shares outstanding - basic | 48.7 | 44.2 | |||||
Dilutive effect of potentially dilutive securities | — | — | |||||
Weighted-average common shares outstanding - diluted | 48.7 | 44.2 | |||||
Diluted EPS | $ | (1.38 | ) | $ | (0.05 | ) | |
Weighted-average anti-dilutive shares(a) | 2.5 | 2.5 |
(a) | Anti-dilutive shares represent potential common shares that are excluded from the computation of diluted EPS. |
Three months ended March 31, | |||||||||||||||
2019 | 2018 | ||||||||||||||
Pension Benefit | Postretirement Benefit | Pension Benefit | Postretirement Benefit | ||||||||||||
(in millions) | |||||||||||||||
Service cost | $ | — | $ | 1 | $ | — | $ | 1 | |||||||
Interest cost | 1 | 1 | 1 | 1 | |||||||||||
Expected return on plan assets | (1 | ) | — | (1 | ) | — | |||||||||
Recognized actuarial loss | 1 | — | — | — | |||||||||||
Settlement loss | — | — | 2 | — | |||||||||||
Total | $ | 1 | $ | 2 | $ | 2 | $ | 2 |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
(in millions) | |||||||
Oil and gas sales: | |||||||
Oil | $ | 480 | $ | 466 | |||
NGLs | 59 | 63 | |||||
Natural gas | 62 | 46 | |||||
601 | 575 | ||||||
Other revenue: | |||||||
Electricity | 34 | 24 | |||||
Marketing, trading and other | 144 | 47 | |||||
Interest income | — | 1 | |||||
178 | 72 | ||||||
Net derivative loss from commodity contracts | (89 | ) | (38 | ) | |||
Total revenues and other | $ | 690 | $ | 609 |
Three months ended March 31, 2019 | |||
(in millions) | |||
Operating lease cost | $ | 12 | |
Short-term lease cost | 20 | ||
Variable lease cost | 5 | ||
Total lease cost | $ | 37 |
March 31, | |||
2019 | |||
(in millions) | |||
Operating lease right-of-use assets, net | $ | 54 | |
Current liabilities | $ | 27 | |
Long-term liabilities | 27 | ||
Total operating lease liabilities | $ | 54 | |
Weighted-average remaining lease term (in years) | 2.9 | ||
Weighted-average discount rate | 11.5 | % |
March 31, | |||
2019 | |||
(in millions) | |||
2019 | $ | 27 | |
2020 | 18 | ||
2021 | 7 | ||
2022 | 4 | ||
2023 | 2 | ||
Thereafter | 6 | ||
Less: Interest | (10 | ) | |
Present value of lease liabilities | $ | 54 |
December 31, | |||
2018 | |||
(in millions) | |||
2019 | $ | 12 | |
2020 | 8 | ||
2021 | 7 | ||
2022 | 7 | ||
2023 | 6 | ||
Thereafter | 28 | ||
Total | $ | 68 |
Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
Brent oil ($/Bbl) | $ | 63.90 | $ | 67.18 | |||
WTI oil ($/Bbl) | $ | 54.90 | $ | 62.87 | |||
NYMEX gas ($/MMBtu) | $ | 3.24 | $ | 2.87 |
Note: | Bbl refers to a barrel; MMBTU refers to one million British Thermal Units. |
Three months ended March 31, | |||||
2019 | 2018 | ||||
Oil (MBbl/d) | |||||
San Joaquin Basin | 55 | 49 | |||
Los Angeles Basin | 25 | 24 | |||
Ventura Basin | 4 | 4 | |||
Total | 84 | 77 | |||
NGLs (MBbl/d) | |||||
San Joaquin Basin | 14 | 15 | |||
Ventura Basin | 1 | 1 | |||
Total | 15 | 16 | |||
Natural gas (MMcf/d) | |||||
San Joaquin Basin | 165 | 143 | |||
Los Angeles Basin | 2 | 1 | |||
Ventura Basin | 7 | 7 | |||
Sacramento Basin | 28 | 31 | |||
Total | 202 | 182 | |||
Total Production (MBoe/d) | 133 | 123 |
Note: | MBbl/d refers to thousands of barrels per day; MMcf/d refers to millions of cubic feet per day; MBoe/d refers to thousands of barrels of oil equivalent (Boe) per day. Natural gas volumes have been converted to Boe based on the equivalence of energy content of six thousand cubic feet of natural gas to one barrel of oil. Barrels of oil equivalence does not necessarily result in price equivalence. |
Three months ended March 31, | |||||||||||
2019 | 2018 | ||||||||||
Price | Realization | Price | Realization | ||||||||
Oil ($ per Bbl) | |||||||||||
Brent | $ | 63.90 | $ | 67.18 | |||||||
Realized price, without hedge | $ | 63.30 | 99% | $ | 67.26 | 100% | |||||
Settled hedges | 1.98 | (4.49 | ) | ||||||||
Realized price, with hedge | $ | 65.28 | 102% | $ | 62.77 | 93% | |||||
WTI | $ | 54.90 | $ | 62.87 | |||||||
Realized price, without hedge | $ | 63.30 | 115% | $ | 67.26 | 107% | |||||
Realized price, with hedge | $ | 65.28 | 119% | $ | 62.77 | 100% | |||||
NGLs ($ per Bbl) | |||||||||||
Realized price (% of Brent) | $ | 42.52 | 67% | $ | 43.13 | 64% | |||||
Realized price (% of WTI) | $ | 42.52 | 77% | $ | 43.13 | 69% | |||||
Natural gas | |||||||||||
NYMEX ($/MMBTU) | $ | 3.24 | $ | 2.87 | |||||||
Realized price, w/out hedge ($/Mcf) | $ | 3.43 | 106% | $ | 2.81 | 98% | |||||
Settled hedges | (0.05 | ) | — | ||||||||
Realized price, with hedge ($/Mcf) | $ | 3.38 | 104% | $ | 2.81 | 98% |
March 31, 2019 | December 31, 2018 | ||||||
(in millions) | |||||||
Cash | $ | 43 | $ | 17 | |||
Trade receivables | $ | 296 | $ | 299 | |||
Inventories | $ | 71 | $ | 69 | |||
Other current assets, net | $ | 167 | $ | 255 | |||
Property, plant and equipment, net | $ | 6,548 | $ | 6,455 | |||
Other assets | $ | 105 | $ | 63 | |||
Current maturities of long-term debt | $ | 100 | $ | — | |||
Accounts payable | $ | 304 | $ | 390 | |||
Accrued liabilities | $ | 285 | $ | 217 | |||
Long-term debt | $ | 5,169 | $ | 5,251 | |||
Deferred gain and issuance costs, net | $ | 203 | $ | 216 | |||
Other long-term liabilities | $ | 692 | $ | 575 | |||
Mezzanine equity | $ | 766 | $ | 756 | |||
Equity attributable to common stock | $ | (426 | ) | $ | (361 | ) | |
Equity attributable to noncontrolling interests | $ | 137 | $ | 114 |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
Production costs | $ | 19.46 | $ | 19.08 | |||
Production costs, excluding effects of PSC-type contracts(a) | $ | 18.01 | $ | 17.47 | |||
Field general and administrative expenses(b) | $ | 1.25 | $ | 0.72 | |||
Field depreciation, depletion and amortization(b) | $ | 9.27 | $ | 9.90 | |||
Field taxes other than on income(b) | $ | 2.67 | $ | 2.70 |
(a) | As described in the Operations section, the reporting of our PSC-type contracts creates a difference between reported production costs, which are for the full field, and reported volumes, which are only our net share, inflating the per barrel production costs. These amounts represent our production costs after adjusting for this difference. |
(b) | Excludes corporate expenses. |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
(in millions) | |||||||
Oil and gas sales | $ | 601 | $ | 575 | |||
Net derivative loss | (89 | ) | (38 | ) | |||
Other revenue | 178 | 72 | |||||
Production costs | (233 | ) | (212 | ) | |||
General and administrative expenses | (83 | ) | (63 | ) | |||
Depreciation, depletion and amortization | (118 | ) | (119 | ) | |||
Taxes other than on income | (41 | ) | (38 | ) | |||
Exploration expense | (10 | ) | (8 | ) | |||
Other expenses, net | (148 | ) | (61 | ) | |||
Interest and debt expense, net | (100 | ) | (92 | ) | |||
Net gain on early extinguishment of debt | 6 | — | |||||
Other non-operating expenses | (7 | ) | (7 | ) | |||
(Loss) income before income taxes | (44 | ) | 9 | ||||
Income tax | — | — | |||||
Net (loss) income | (44 | ) | 9 | ||||
Net income attributable to noncontrolling interests | (23 | ) | (11 | ) | |||
Net loss attributable to common stock | $ | (67 | ) | $ | (2 | ) | |
Adjusted net income | $ | 31 | $ | 8 | |||
Adjusted EBITDAX | $ | 301 | $ | 250 | |||
Effective tax rate | — | % | — | % |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
(in millions, except per Boe amounts) | |||||||
General and administrative expenses | |||||||
Cash-settled awards | $ | 10 | $ | 3 | |||
Equity-settled awards | 3 | 3 | |||||
Total stock-based compensation in G&A | $ | 13 | $ | 6 | |||
Total stock-based compensation in G&A per Boe | $ | 1.09 | $ | 0.54 | |||
Production costs | |||||||
Cash-settled awards | $ | 3 | $ | 1 | |||
Equity-settled awards | 1 | 1 | |||||
Total stock-based compensation in production costs | $ | 4 | $ | 2 | |||
Total stock-based compensation in production costs per Boe | $ | 0.33 | $ | 0.18 | |||
Total company stock-based compensation | $ | 17 | $ | 8 | |||
Total company stock-based compensation per Boe | $ | 1.42 | $ | 0.72 |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
(in millions) | |||||||
Commodity Contracts: | |||||||
Non-cash derivative loss, excluding noncontrolling interest | $ | (97 | ) | $ | (7 | ) | |
Non-cash derivative loss - noncontrolling interest | (6 | ) | — | ||||
Net proceeds (payments) on settled commodity derivatives | 14 | (31 | ) | ||||
Net derivative loss from commodity contracts | $ | (89 | ) | $ | (38 | ) | |
Interest-Rate Contracts: | |||||||
Non-cash derivative loss | $ | (3 | ) | $ | — |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
(in millions, except share data) | |||||||
Net (loss) income | $ | (44 | ) | $ | 9 | ||
Net income attributable to noncontrolling interests | (23 | ) | (11 | ) | |||
Net loss attributable to common stock | (67 | ) | (2 | ) | |||
Unusual, infrequent and other items: | |||||||
Non-cash derivative loss from commodities, excluding noncontrolling interest | 97 | 7 | |||||
Non-cash derivative loss from interest-rate contracts | 3 | — | |||||
Early retirement costs | — | 2 | |||||
Net gain on early extinguishment of debt | (6 | ) | — | ||||
Other, net | 4 | 1 | |||||
Total unusual, infrequent and other items | 98 | 10 | |||||
Adjusted net income | $ | 31 | $ | 8 | |||
Net loss attributable to common stock per diluted share | $ | (1.38 | ) | $ | (0.05 | ) | |
Adjusted net income per diluted share | $ | 0.63 | $ | 0.18 |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
(in millions) | |||||||
Net (loss) income | $ | (44 | ) | $ | 9 | ||
Interest and debt expense, net | 100 | 92 | |||||
Depreciation, depletion and amortization | 118 | 119 | |||||
Exploration expense | 10 | 8 | |||||
Unusual, infrequent and other items | 98 | 10 | |||||
Other non-cash items | 19 | 12 | |||||
Adjusted EBITDAX | $ | 301 | $ | 250 |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
(in millions) | |||||||
Net cash provided by operating activities | $ | 158 | $ | 200 | |||
Cash interest | 72 | 61 | |||||
Exploration expenditures | 4 | 6 | |||||
Working capital changes | 67 | (18 | ) | ||||
Other, net | — | 1 | |||||
Adjusted EBITDAX | $ | 301 | $ | 250 |
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
(in millions) | |||||||
Net cash provided by operating activities | $ | 158 | $ | 200 | |||
Net cash used in investing activities: | |||||||
Capital investments, including accruals | $ | (178 | ) | $ | (134 | ) | |
Acquisitions, divestitures and other | $ | (4 | ) | $ | (4 | ) | |
Net cash provided by financing activities | $ | 50 | $ | 412 |
Outstanding Principal (in millions) | Interest Rate | Maturity | Security | ||||||
Credit Agreements | |||||||||
2014 Revolving Credit Facility | $ | 576 | LIBOR plus 3.25%-4.00% ABR plus 2.25%-3.00% | June 30, 2021 | Shared First-Priority Lien | ||||
2017 Credit Agreement | 1,300 | LIBOR plus 4.75% ABR plus 3.75% | December 31, 2022(a) | Shared First-Priority Lien | |||||
2016 Credit Agreement | 1,000 | LIBOR plus 10.375% ABR plus 9.375% | December 31, 2021 | First-Priority Lien | |||||
Second Lien Notes | |||||||||
Second Lien Notes | 2,049 | 8% | December 15, 2022(b) | Second-Priority Lien | |||||
Senior Notes | |||||||||
5% Senior Notes due 2020 | 100 | 5% | January 15, 2020 | Unsecured | |||||
5½% Senior Notes due 2021 | 100 | 5.5% | September 15, 2021 | Unsecured | |||||
6% Senior Notes due 2024 | 144 | 6% | November 15, 2024 | Unsecured | |||||
Total | 5,269 | ||||||||
Less: Current Maturities | (100 | ) | |||||||
Long-Term Debt | $ | 5,169 |
Note: | For a detailed description of our credit agreements, second lien notes and senior notes, please see our most recent Form 10-K for the year ended December 31, 2018. |
(a) | The 2017 Credit Agreement is subject to a springing maturity of 91 days prior to the maturity of our 2016 Credit Agreement if more than $100 million in principal of the 2016 Credit Agreement is outstanding at that time. |
(b) | The Second Lien Notes require principal repayments of approximately $324 million in June 2021, $65 million in December 2021, $67 million in June 2022 and $1,593 million in December 2022. |
Q2 2019 | Q3 2019 | Q4 2019 | Q1 2020 | Q2 2020 | |||||||||||||||
Sold Calls: | |||||||||||||||||||
Barrels per day | 5,000 | — | — | — | — | ||||||||||||||
Weighted-average price per barrel | $ | 68.45 | $ | — | $ | — | $ | — | $ | — | |||||||||
Purchased Puts: | |||||||||||||||||||
Barrels per day | 40,000 | 40,000 | 35,000 | 20,000 | 10,000 | ||||||||||||||
Weighted-average price per barrel | $ | 69.75 | $ | 73.13 | $ | 75.71 | $ | 72.50 | $ | 70.00 | |||||||||
Sold Puts: | |||||||||||||||||||
Barrels per day | 35,000 | 40,000 | 35,000 | 20,000 | 10,000 | ||||||||||||||
Weighted-average price per barrel | $ | 55.71 | $ | 57.50 | $ | 60.00 | $ | 57.50 | $ | 55.00 | |||||||||
Swaps: | |||||||||||||||||||
Barrels per day | — | — | — | 5,000(a) | 5,000(b) | ||||||||||||||
Weighted-average price per barrel | $ | — | $ | — | $ | — | $ | 70.29 | $ | 70.05 |
(a) | A counterparty has the option to increase swap volumes by up to 5,000 barrels per day at a weighted-average Brent price of $70.29 for the first quarter of 2020. |
(b) | A counterparty has the option to increase swap volumes by up to 5,000 barrels per day at a weighted-average Brent price of $70.05 for the second quarter of 2020. |
• | financial position, liquidity, cash flows and results of operations |
• | business prospects |
• | transactions and projects |
• | operating costs |
• | Value Creation Index (VCI) metrics, which are based on certain estimates including future production rates, costs and commodity prices |
• | operations and operational results including production, hedging and capital investment |
• | budgets and maintenance capital requirements |
• | reserves |
• | type curves |
• | expected synergies from acquisitions and joint ventures |
• | commodity price changes |
• | debt limitations on our financial flexibility |
• | insufficient cash flow to fund planned investments, debt repurchases, distributions to JV partners or changes to our capital plan |
• | inability to enter desirable transactions including acquisitions, asset sales and joint ventures |
• | legislative or regulatory changes, including those related to drilling, completion, well stimulation, operation, maintenance or abandonment of wells or facilities, managing energy, water, land, greenhouse gases or other emissions, protection of health, safety and the environment, or transportation, marketing and sale of our products |
• | joint ventures and acquisitions and our ability to achieve expected synergies |
• | the recoverability of resources and |
• | incorrect estimates of reserves and related future cash flows and the inability to replace reserves |
• | changes in business strategy |
• | PSC effects on production and unit production costs |
• | effect of stock price on costs associated with incentive compensation |
• | insufficient capital, including as a result of lender restrictions, unavailability of capital markets or inability to attract potential investors |
• | effects of hedging transactions |
• | equipment, service or labor price inflation or unavailability |
• | availability or timing of, or conditions imposed on, permits and approvals |
• | lower-than-expected production, reserves or resources from development projects, joint ventures or acquisitions, or higher-than-expected decline rates |
• | disruptions due to accidents, mechanical failures, transportation or storage constraints, natural disasters, labor difficulties, cyber attacks or other catastrophic events |
• | factors discussed in Item 1A – Risk Factors of our Form 10-K for the year ended December 31, 2018. |
Item 3. | Quantitative and Qualitative Disclosures About Market Risk |
Item 4. | Controls and Procedures |
Item 1. | Legal Proceedings |
Item 1.A. | Risk Factors |
Item 5. | Other Disclosures |
Item 6. | Exhibits |
3.1 | |
3.2 | |
10.1* | |
10.2* | |
10.3* | |
31.1* | |
31.2* | |
32.1* | |
101.INS* | XBRL Instance Document. |
101.SCH* | XBRL Taxonomy Extension Schema Document. |
101.CAL* | XBRL Taxonomy Extension Calculation Linkbase Document. |
101.LAB* | XBRL Taxonomy Extension Label Linkbase Document. |
101.PRE* | XBRL Taxonomy Extension Presentation Linkbase Document. |
101.DEF* | XBRL Taxonomy Extension Definition Linkbase Document. |
CALIFORNIA RESOURCES CORPORATION |
DATE: | May 2, 2019 | /s/ Roy M. Pineci | |
Roy M. Pineci | |||
Executive Vice President - Finance | |||
(Principal Accounting Officer) |
Grantee: | <<Grantee Name>> | |
Date of Grant: | February 19, 2019 | |
Shares of Common Stock Subject to This Option: | << Options Granted >> | |
Vesting Schedule: | One-third of the Options on February 18, 2020; One-third of the Options on February 18, 2021; One-third of the Options on February 18, 2022 (each being a “Vesting Date”) | |
Purchase Price Per Share: | $23.88 |
Grantee: | <<Grantee Name>> | |
Date of Grant: | February 19, 2019 | |
Restricted Stock Units: | <<Units Granted>> | |
Vesting Date Schedule: | One-third of the Restricted Stock Units on February 18, 2020; One-third of the Restricted Stock Units on February 18, 2021; One-third of the Restricted Stock Units on February 18, 2022 (each being a “Vesting Date”) |
Grantee: | <<Grantee Name>> | |
Date of Grant: | February 19, 2019 | |
Performance Stock Units: | <<Units Granted>> | |
Vesting Date: | February 18, 2022 | |
Performance Period: | January 1, 2019 through December 31, 2021 |
(TSR Performance Factor + VCI Performance Factor) / 2 |
Relative TSR Percentile Rank (1) | TSR Performance Factor (2) (3) |
90th or higher | 200% |
50th | 100% |
25th | 50% |
Less than 25th | 0% |
Cumulative Value Creation Index (1) | VCI Performance Factor (2) |
1.6 or greater | 200% |
1.4 | 100% |
1.2 | 50% |
Less than 1.2 | 0% |
1. | I have reviewed this quarterly report on Form 10-Q of California Resources Corporation; |
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(s) 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(s) 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. |
/s/ Todd A. Stevens | ||
Todd A. Stevens | ||
President and Chief Executive Officer | ||
(Principal Executive Officer) |
1. | I have reviewed this quarterly report on Form 10-Q of California Resources Corporation; |
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(s) 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(s) 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. |
/s/ Marshall D. Smith | ||||
Marshall D. Smith | ||||
Senior Executive Vice President and | ||||
Chief Financial Officer | ||||
(Principal Financial Officer) |
1. | The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and |
2. | The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. |
/s/ Todd A. Stevens | ||||
Name: | Todd A. Stevens | |||
Title: | President and Chief Executive Officer | |||
Date: | May 2, 2019 |
/s/ Marshall D. Smith | ||||
Name: | Marshall D. Smith | |||
Title: | Senior Executive Vice President and Chief Financial Officer | |||
Date: | May 2, 2019 |
Document and Entity Information |
3 Months Ended |
---|---|
Mar. 31, 2019
shares
| |
Document and Entity Information | |
Entity Registrant Name | California Resources Corp |
Entity Central Index Key | 0001609253 |
Document Type | 10-Q |
Current Fiscal Year End Date | --12-31 |
Document Fiscal Year Focus | 2019 |
Document Fiscal Period Focus | Q1 |
Document Period End Date | Mar. 31, 2019 |
Amendment Flag | false |
Entity Current Reporting Status | Yes |
Entity Filer Category | Large Accelerated Filer |
Entity Small Business | false |
Entity Emerging Growth Company | false |
Trading Symbol | CRC |
Entity Common Stock, Shares Outstanding | 48,800,217 |
Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares |
Mar. 31, 2019 |
Dec. 31, 2018 |
---|---|---|
Condensed Consolidated Balance Sheets | ||
Preferred stock, authorized shares | 20,000,000 | 20,000,000 |
Preferred stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Preferred stock, outstanding shares | 0 | 0 |
Common stock, authorized shares | 200,000,000 | 200,000,000 |
Common stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Common stock, outstanding shares | 48,800,217 | 48,650,420 |
Condensed Consolidated Statements of Comprehensive Income - USD ($) $ in Millions |
3 Months Ended | |||
---|---|---|---|---|
Mar. 31, 2019 |
Mar. 31, 2018 |
|||
Condensed Consolidated Statements of Comprehensive Income | ||||
Net (loss) income | $ (44) | $ 9 | ||
Net income attributable to noncontrolling interests | (23) | (11) | ||
Other comprehensive income items: | ||||
Reclassification of realized losses on pension and postretirement benefits to income | [1] | $ 2 | ||
Comprehensive loss attributable to common stock | $ (67) | |||
|
Condensed Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Millions |
3 Months Ended | |
---|---|---|
Mar. 31, 2019 |
Mar. 31, 2018 |
|
Condensed Consolidated Statements of Comprehensive Income | ||
Pension and postretirement income, associated tax | $ 0 | $ 0 |
Condensed Consolidated Statements of Equity - USD ($) $ in Millions |
Equity Attributable to Common Stock |
Additional Paid-in Capital |
Accumulated (Deficit) Earnings |
Accumulated Other Comprehensive (Loss) Income |
Equity Attributable to Noncontrolling Interests |
Total |
---|---|---|---|---|---|---|
Beginning balance at Dec. 31, 2017 | $ (814) | $ 4,879 | $ (5,670) | $ (23) | $ 94 | $ (720) |
Increase (decrease) in Equity | ||||||
Net loss | (2) | (2) | (3) | (5) | ||
Contributions from noncontrolling interest holders, net | 33 | 33 | ||||
Distributions to noncontrolling interest holders | (15) | (15) | ||||
Issuance of common stock | 50 | 50 | 50 | |||
Other comprehensive income | 2 | 2 | 2 | |||
Share-based compensation, net | 1 | 1 | 1 | |||
Ending balance at Mar. 31, 2018 | (763) | 4,930 | (5,672) | (21) | 109 | (654) |
Beginning balance at Dec. 31, 2018 | (361) | 4,987 | (5,342) | (6) | 114 | (247) |
Increase (decrease) in Equity | ||||||
Net loss | (67) | (67) | (5) | (72) | ||
Contributions from noncontrolling interest holders, net | 49 | 49 | ||||
Distributions to noncontrolling interest holders | (21) | (21) | ||||
Share-based compensation, net | 2 | 2 | 2 | |||
Ending balance at Mar. 31, 2019 | $ (426) | $ 4,989 | $ (5,409) | $ (6) | $ 137 | $ (289) |
THE SPIN-OFF AND BASIS OF PRESENTATION |
3 Months Ended |
---|---|
Mar. 31, 2019 | |
THE SPIN-OFF AND BASIS OF PRESENTATION | |
THE SPIN-OFF AND BASIS OF PRESENTATION | NOTE 1 THE SPIN-OFF AND BASIS OF PRESENTATION
The Separation and Spin-off
We are an independent oil and natural gas exploration and production company operating properties exclusively within California. We were incorporated in Delaware as a wholly owned subsidiary of Occidental Petroleum Corporation (Occidental) on April 23, 2014, and we became an independent, publicly traded company on December 1, 2014.
Except when the context otherwise requires or where otherwise indicated, all references to ‘‘CRC,’’ the ‘‘Company,’’ ‘‘we,’’ ‘‘us’’ and ‘‘our’’ refer to California Resources Corporation and its subsidiaries.
Basis of Presentation
In the opinion of our management, the accompanying financial statements contain all adjustments (consisting of normal recurring adjustments) necessary to fairly present our financial position as of March 31, 2019 and December 31, 2018 and the statements of operations, comprehensive income, cash flows and equity for the three months ended March 31, 2019 and 2018, as applicable. We have eliminated all significant intercompany transactions and accounts. We account for our share of oil and gas exploration and development ventures, in which we have a direct working interest, by reporting our proportionate share of assets, liabilities, revenues, costs and cash flows within the relevant lines on our condensed consolidated balance sheets, statements of operations, equity and cash flows.
We have prepared this report pursuant to the rules and regulations of the United States (U.S.) Securities and Exchange Commission (SEC) applicable to interim financial information, which permit the omission of certain disclosures to the extent they have not changed materially since the latest annual financial statements. We believe our disclosures are adequate to make the information not misleading. This Form 10-Q should be read in conjunction with the consolidated financial statements and the notes thereto in our Annual Report on Form 10-K for the year ended December 31, 2018.
|
ACCOUNTING AND DISCLOSURE CHANGES |
3 Months Ended |
---|---|
Mar. 31, 2019 | |
ACCOUNTING AND DISCLOSURE CHANGES | |
ACCOUNTING AND DISCLOSURE CHANGES | NOTE 2 ACCOUNTING AND DISCLOSURE CHANGES
Recently Adopted Accounting and Disclosure Changes
We adopted the Financial Accounting Standards Board's (FASB) new lease accounting rules (ASC 842), as of January 1, 2019, using the modified retrospective approach where the new lease standard is not applied to prior comparative periods, which continue to be presented under accounting standards in effect for those prior periods. Under the modified retrospective approach, we recognized right-of-use assets and lease liabilities of approximately $66 million as of the adoption date. The adoption of the new lease accounting rules did not materially impact our consolidated net earnings and had no impact on cash flows or beginning retained earnings. The new lease standard does not affect our liquidity and has no impact on our debt-covenant calculations under our 2014 Revolving Credit Facility, 2016 Credit Agreement and 2017 Credit Agreement. See Note 12 Leases for more information. |
OTHER INFORMATION |
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OTHER INFORMATION | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
OTHER INFORMATION |
Cash at March 31, 2019 and December 31, 2018 included approximately $26 million and $2 million, respectively, that is restricted for capital investments and distributions to a joint venture (JV) partner.
Other current assets, net as of March 31, 2019 and December 31, 2018 consisted of the following:
Accrued liabilities as of March 31, 2019 and December 31, 2018 consisted of the following:
Other long-term liabilities included asset retirement obligations (ARO) of $490 million and $402 million at March 31, 2019 and December 31, 2018, respectively. As of March 31, 2019, the timing of our cash flows and additional testing costs associated with our future retirement activities were adjusted as a result of the enactment of new regulations, which resulted in an $87 million increase in the aggregate amount of our ARO. The Office of Administrative Law approved the Division of Oil, Gas, and Geothermal Resources' idle well management regulations on March 20, 2019, with an effective date of April 1, 2019.
Fair Value of Financial Instruments
The carrying amounts of cash and other on-balance sheet financial instruments, other than debt, approximate fair value.
Supplemental Cash Flow Information
We did not make U.S. federal and state income tax payments during the three months ended March 31, 2019 and 2018. Interest paid, net of capitalized amounts, totaled approximately $69 million and $60 million for the three months ended March 31, 2019 and 2018, respectively. |
INVENTORIES |
3 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||
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INVENTORIES | ||||||||||||||||||||||||||||||||||||||||||||||||||
INVENTORIES | NOTE 4 INVENTORIES
Inventories as of March 31, 2019 and December 31, 2018 consisted of the following:
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DEBT |
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DEBT | NOTE 5 DEBT
As of March 31, 2019 and December 31, 2018, our long-term debt consisted of the following credit agreements, second lien notes and senior notes:
Note: For a detailed description of our credit agreements, second lien notes and senior notes, please see our most recent Form 10-K for the year ended December 31, 2018.
Deferred Gain and Issuance Costs
As of March 31, 2019, net deferred gain and issuance costs were $203 million, consisting of $293 million of a deferred gain offset by $90 million of deferred issuance costs and original issue discounts. The December 31, 2018 net deferred gain and issuance costs were $216 million, consisting of $313 million of a deferred gain offset by $97 million of deferred issuance costs and original issue discounts.
2014 Revolving Credit Facility
As of March 31, 2019, we had approximately $256 million of available borrowing under our $1 billion revolving credit facility (2014 Revolving Credit Facility), before a $150 million month-end minimum liquidity requirement. Effective May 1, 2019, the borrowing base under this facility was reaffirmed at $2.3 billion. Our 2014 Revolving Credit Facility also includes a sub-limit of $400 million for the issuance of letters of credit. As of March 31, 2019 and December 31, 2018, we had letters of credit outstanding of approximately $168 million and $162 million, respectively. These letters of credit were issued to support ordinary course marketing, insurance, regulatory and other matters.
Note Repurchases
In the first quarter of 2019, we repurchased $18 million in principal amount of our 8% senior secured second lien notes due December 15, 2022 (Second Lien Notes) for $14 million in cash resulting in a pre-tax gain of $6 million, including the effect of unamortized deferred gain and issuance costs.
Fair Value
We estimate the fair value of fixed-rate debt, which is classified as Level 1, based on prices from known market transactions for our instruments. The estimated fair value of our debt at March 31, 2019 and December 31, 2018, including the fair value of the variable-rate portion, was approximately $4.8 billion and $4.5 billion, respectively, compared to a carrying value of approximately $5.3 billion in both periods.
Other
At March 31, 2019, we were in compliance with all financial and other debt covenants.
All obligations under our 2014 Revolving Credit Facility, 2017 Credit Agreement and 2016 Credit Agreement (collectively, Credit Facilities) as well as our Second Lien Notes and Senior Notes are guaranteed both fully and unconditionally and jointly and severally by all of our material wholly owned subsidiaries. |
JOINT VENTURES |
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JOINT VENTURES | NOTE 6 JOINT VENTURES
Noncontrolling Interests
The following table presents the changes in noncontrolling interests by JV partners (described in greater detail below), reported in equity and mezzanine equity on the condensed consolidated balance sheets, for the three months ended March 31, 2019 and 2018:
Ares Management L.P. (Ares)
Our condensed consolidated statements of operations reflect the full operations of our midstream JV with ECR Corporate Holdings L.P. (ECR), a portfolio company of Ares Management L.P. (Ares), with ECR's share of net income (loss) reported in net income attributable to noncontrolling interests. ECR's redeemable noncontrolling interests are reported in mezzanine equity due to an embedded optional redemption feature.
Benefit Street Partners (BSP)
Our consolidated results reflect the full operations of our development JV with Benefit Street Partners (BSP), with BSP's preferred interest reported in equity on our condensed consolidated balance sheets and BSP’s share of net income (loss) being reported in net income attributable to noncontrolling interests on our condensed consolidated statements of operations. BSP contributed $49 million in the first quarter of 2019, net of transaction costs. |
LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES |
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LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES | NOTE 7 LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES
We, or certain of our subsidiaries, are involved, in the normal course of business, in lawsuits, environmental and other claims and other contingencies that seek, among other things, compensation for alleged personal injury, breach of contract, property damage or other losses, punitive damages, civil penalties, or injunctive or declaratory relief.
We accrue reserves for currently outstanding lawsuits, claims and proceedings when it is probable that a liability has been incurred and the liability can be reasonably estimated. Reserve balances at March 31, 2019 and December 31, 2018 were not material to our balance sheets as of such dates. We also evaluate the amount of reasonably possible losses that we could incur as a result of these matters. We believe that reasonably possible losses that we could incur in excess of reserves accrued would not be material to our consolidated financial position or results of operations.
We remain subject to examination by the IRS for calendar years 2016 and 2017. We remain subject to examination by the state of California for the years ended December 31, 2014 through 2017.
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DERIVATIVES |
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DERIVATIVES | NOTE 8 DERIVATIVES
General
We use a variety of derivative instruments to protect our cash flow, operating margin and capital program from the cyclical nature of commodity prices and interest-rate movements. These derivatives are intended to help us maintain adequate liquidity and improve our ability to comply with the covenants of our Credit Facilities in case of price deterioration.
Commodity Price Risk
We did not have any commodity derivatives designated as hedges as of and during the three months ended March 31, 2019 and 2018. As part of our hedging program, we held the following Brent-based crude oil contracts as of March 31, 2019:
The BSP JV entered into crude oil derivatives for insignificant volumes through 2021 that are included in our consolidated results but not in the above table. The BSP JV also entered into natural gas swaps for insignificant volumes for periods through May 2021. The hedges entered into by the BSP JV could affect the timing of the redemption of the JV interest.
Interest-Rate Risk
In May 2018, we entered into derivative contracts that limit our interest rate exposure with respect to $1.3 billion of our variable-rate indebtedness. These interest-rate contracts reset monthly and require the counterparties to pay any excess interest owed on such amount in the event the one-month LIBOR exceeds 2.75% for any monthly period prior to May 4, 2021.
Fair Value of Derivatives
Our derivative contracts are measured at fair value using industry-standard models with various inputs, including quoted forward prices, and are classified as Level 2 in the required fair value hierarchy for the periods presented. We recognize fair value changes on derivative instruments in each reporting period. The changes in fair value result from the relationship between contract prices or interest rates and the associated forward curves.
Commodity Contracts
The following table presents the fair values (at gross and net) of our outstanding commodity derivatives as of March 31, 2019 and December 31, 2018 (in millions):
Interest-Rate Contracts
As of March 31, 2019 and December 31, 2018, we reported the fair value of our interest rate derivatives of $1 million and $4 million, respectively, in other assets on our condensed consolidated balance sheets. For the three months ended March 31, 2019, we reported a $3 million non-cash derivative loss on these contracts in other non-operating expenses on our condensed consolidated statements of operations. |
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EARNINGS PER SHARE | NOTE 9 EARNINGS PER SHARE
We compute basic and diluted earnings per share (EPS) using the two-class method required for participating securities. Certain of our restricted and performance stock awards are considered participating securities because they have non-forfeitable dividend rights at the same rate as our common stock.
Under the two-class method, undistributed earnings allocated to participating securities are subtracted from net income attributable to common stock in determining net income available to common stockholders. In loss periods, no allocation is made to participating securities because participating securities do not share in losses. For basic EPS, the weighted-average number of common shares outstanding excludes outstanding shares related to unvested restricted stock awards. For diluted EPS, the basic shares outstanding are adjusted by adding all potentially dilutive securities.
The following table presents the calculation of basic and diluted EPS for the three months ended March 31, 2019 and 2018:
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PENSION AND POSTRETIREMENT BENEFIT PLANS |
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PENSION AND POSTRETIREMENT BENEFIT PLANS | NOTE 10 PENSION AND POSTRETIREMENT BENEFIT PLANS
The following table sets forth the components of the net periodic benefit costs for our defined benefit pension and postretirement benefit plans:
We did not contribute to our defined benefit pension plan in the three months ended March 31, 2019 and contributed $1 million in the three months ended March 31, 2018. We expect to satisfy minimum funding requirements with contributions of $3 million to our defined benefit pension plans during the remainder of 2019. The 2018 settlement loss, which was reclassified from accumulated other comprehensive income, was associated with early retirements. |
REVENUE RECOGNITION |
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REVENUE RECOGNITION | NOTE 11 REVENUE RECOGNITION
We derive substantially all of our revenue from sales of oil, natural gas and natural gas liquids (NGLs), with the remaining revenue generated from sales of electricity and marketing activities related to storage and managing excess pipeline capacity.
The following is a description of our principal activities from which we generate revenue. Revenues are recognized when control of promised goods is transferred to our customers, in an amount that reflects the consideration we expect to receive in exchange for those goods.
Commodity Sales Contracts
We recognize revenue from the sale of our oil, natural gas and NGL production when delivery has occurred and control passes to the customer. Our commodity contracts are short term, typically less than a year. We consider our performance obligations to be satisfied upon transfer of control of the commodity. Transportation and processing fees incurred by us prior to control being transferred to customers are recorded as a component of other expenses, net on our condensed consolidated statements of operations.
Our commodity sales contracts are indexed to a market price or an average index price. We recognize revenue in the amount that we have a right to invoice once we are able to adequately estimate the consideration (i.e., when market prices are known). Our contracts with customers typically require payment within 30 days following invoicing.
Electricity
The electrical output of the Elk Hills power plant that is not used in our operations is sold to the wholesale power market and to a utility under a power purchase and sales agreement, which includes a capacity payment. Revenue is recognized when obligations under the terms of contracts with our customers are satisfied; generally, this occurs upon delivery of the electricity. We report electricity sales as other revenue on our condensed consolidated statements of operations. Revenue is measured as the amount of consideration we expect to receive based on average index pricing with payment due the month following delivery. Capacity payments are based on a fixed annual amount per kilowatt hour and monthly rates vary based on seasonality. Capacity payments are settled monthly. We consider our performance obligations to be satisfied upon delivery of electricity or as the contracted amount of energy is made available to the customer in the case of capacity payments.
Marketing, Trading and Other
Marketing, trading and other revenue primarily includes our activities associated with storing, transporting and marketing our production as well as third-party volumes.
To transport our natural gas as well as third-party volumes, we have entered into firm pipeline commitments. Depending on market conditions, we may have excess capacity, in which case we may enter into natural gas purchase and sale agreements with third parties. We consider our performance obligations to be satisfied upon transfer of control of the commodity. We have not incurred any significant fees or penalties related to excess capacity on these commitments.
We report our marketing and trading activities on a gross basis with purchases and costs reported in other expenses, net and sales recorded in other revenue on our condensed consolidated statements of operations.
Disaggregation of Revenue
The following table provides disaggregated revenue for the three months ended March 31, 2019 and 2018:
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LEASES |
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LEASES | NOTE 12 LEASES
On January 1, 2019, we adopted ASC 842 using the modified retrospective approach that requires us to determine our lease balances as of the date of adoption. Prior periods continue to be reported under accounting standards in effect for those periods. We also elected to carry forward our current accounting treatment for land easements on existing agreements. Mineral leases, including oil and natural gas leases, are not included in the scope of ASC 842.
We have long-term operating leases for commercial office space, drilling rigs, fleet vehicles and certain facilities. In considering whether a contract contains a lease, we first considered whether there was an identifiable asset and then considered how and for what purpose the asset would be used over the contract term.
Our lease liability was determined by measuring the present value of the remaining fixed minimum lease payments as of the date of adoption discounted using our incremental borrowing rate (IBR). In determining our IBR, we considered the average cost of borrowing for publicly traded corporate bond yields, which were adjusted to reflect our credit rating, remaining lease term and frequency of payments.
We elected to combine lease and non-lease components in determining fixed minimum lease payments for our drilling rigs and commercial office space. If applicable, fixed minimum lease payments were reduced by lease incentives for our commercial buildings and increased by mobilization and demobilization fees related to our drilling rigs. Certain of our lease agreements include options to renew, which we exercise at our sole discretion, and we did not include these options in determining our fixed minimum lease payments. Our lease liability does not include options to extend or terminate our leases. Our leases do not include options to purchase the leased property. Lease agreements for our fleet vehicles include residual value guarantees, none of which are recognized in our financial statements until the underlying contingency is resolved.
For all of our asset classes, we elected to keep leases with an initial term of 12 months or less off the balance sheet and have included costs related to these contracts in our short-term lease cost disclosure below. Contracts with terms of one month or less are excluded from our disclosure of short-term lease costs.
For our long-term contracts, variable lease costs were not included in the measurement of our lease balances. Variable lease costs for our drilling rigs included costs to operate, move and repair the rigs. Variable lease costs for certain of our commercial office buildings included utilities and common area maintenance charges. Variable lease costs for our fleet vehicles included other-than-routine maintenance and other various amounts in excess of our fixed minimum rental fee.
Our operating lease costs, including amounts capitalized to property, plant and equipment, for the three months ended March 31, 2019 were as follows:
We sublease certain commercial office space to third parties where we are the primary obligor under the head lease. The lease terms on those subleases never extend past the term of the head lease and the sublease contains no extension options or residual value guarantees. Sublease income is recognized based on the contract terms and included as a reduction of operating lease cost under our head lease. For the quarter ended March 31, 2019, sublease income was not material to our condensed consolidated financial statements.
For the quarter ended March 31, 2019, we paid $9 million and $3 million for our operating lease liabilities, which were reported in net cash used in investing activities and net cash provided by operating activities in our condensed consolidated statement of cash flows, respectively.
Our right-of-use assets for operating leases, net of accumulated amortization, were approximately $54 million at March 31, 2019, which is reported in other assets on our consolidated balance sheet. Supplemental balance sheet information related to our operating leases was as follows:
As part of our company-wide consolidation of office space, we will be vacating certain office space in 2019 some of which we may sublease. Should we enter into a sublease agreement, we will evaluate the carrying value of our right-of-use asset, along with the carrying value of related tenant improvements, for impairment based on future identifiable cash flows. For the period ended March 31, 2019, we recognized an impairment of $3 million. We do not expect to terminate leases for vacated office space before the expiration of the lease term. Where we have decided to not sublease vacated commercial office space, we will shorten the useful life of the right-of-use assets and related tenant improvements to recover our remaining costs over our expected period of use. Once the leased office space is abandoned, lease costs will be classified as other non-operating expenses, net on our condensed consolidated statements of operations.
Maturities of our operating lease liabilities at March 31, 2019 are as follows:
We have entered into contracts for commercial office space and facilities that are under construction as of March 31, 2019. These leases are not included in our lease population at March 31, 2019 as the lease terms have not commenced because we do not control the assets during construction. We will apply the new lease standard when the asset is placed in service by us, which is expected to be January and June 2020. Payments for these contracts were included in the table of our future minimum lease payments as of December 31, 2018, which is shown below.
At December 31, 2018, future minimum lease payments for noncancelable operating leases under ASC 840 (excluding oil and natural gas and other mineral leases, utilities, taxes, insurance and common area maintenance expenses) were:
Rental expense for operating leases under ASC 840 was $2.8 million for the three months ended March 31, 2018. Rental income from subleases for the three months ended March 31, 2018 was not significant. |
INCOME TAXES |
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INCOME TAXES | NOTE 13 INCOME TAXES
For the three months ended March 31, 2019 and 2018, we did not provide any current or deferred tax provision or benefit. The difference between our statutory tax rate and our effective tax rate of zero for the periods presented includes changes to maintain our full valuation allowance against our net deferred tax assets given our recent and anticipated future earnings trends. We believe that there is a reasonable possibility that some or all of this allowance could be released in the foreseeable future. However, the amount of the net deferred tax assets considered realizable depends on the level of profitability that we are able to actually achieve. |
ASSET DIVESTITURE |
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ASSET DIVESTITURE | NOTE 14 ASSET DIVESTITURE
On May 1, 2019, we sold 50% of our working interest and transferred operatorship in certain zones of our Lost Hills field, located in the San Joaquin basin, for total consideration in excess of $200 million, consisting of approximately $168 million in cash and a carried 200-well development program to be drilled through 2023 with an estimated minimum value of $35 million. The proceeds were used to pay down our 2014 Revolving Credit Facility. |
THE SPIN-OFF AND BASIS OF PRESENTATION (Policies) |
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Basis of Presentation | Basis of Presentation
In the opinion of our management, the accompanying financial statements contain all adjustments (consisting of normal recurring adjustments) necessary to fairly present our financial position as of March 31, 2019 and December 31, 2018 and the statements of operations, comprehensive income, cash flows and equity for the three months ended March 31, 2019 and 2018, as applicable. We have eliminated all significant intercompany transactions and accounts. We account for our share of oil and gas exploration and development ventures, in which we have a direct working interest, by reporting our proportionate share of assets, liabilities, revenues, costs and cash flows within the relevant lines on our condensed consolidated balance sheets, statements of operations, equity and cash flows.
We have prepared this report pursuant to the rules and regulations of the United States (U.S.) Securities and Exchange Commission (SEC) applicable to interim financial information, which permit the omission of certain disclosures to the extent they have not changed materially since the latest annual financial statements. We believe our disclosures are adequate to make the information not misleading. This Form 10-Q should be read in conjunction with the consolidated financial statements and the notes thereto in our Annual Report on Form 10-K for the year ended December 31, 2018. |
OTHER INFORMATION (Tables) |
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Mar. 31, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
OTHER INFORMATION | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of other current assets, net |
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Schedule of accrued liabilities |
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INVENTORIES (Tables) |
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Mar. 31, 2019 | ||||||||||||||||||||||||||||||||||||||||||||||||||
INVENTORIES | ||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Inventories |
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DEBT (Tables) |
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DEBT | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Debt |
Note: For a detailed description of our credit agreements, second lien notes and senior notes, please see our most recent Form 10-K for the year ended December 31, 2018.
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JOINT VENTURES (Tables) |
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JOINT VENTURES | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of changes in noncontrolling interests |
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DERIVATIVES (Tables) |
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DERIVATIVES | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of oil hedge positions |
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Schedule of fair value (at gross and net) of outstanding derivatives | The following table presents the fair values (at gross and net) of our outstanding commodity derivatives as of March 31, 2019 and December 31, 2018 (in millions):
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EARNINGS PER SHARE (Tables) |
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EARNINGS PER SHARE | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Calculation of basic and diluted EPS |
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PENSION AND POSTRETIREMENT BENEFIT PLANS (Tables) |
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Components of the net periodic benefit costs |
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REVENUE RECOGNITION (Tables) |
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REVENUE RECOGNITION | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of disaggregated revenue | The following table provides disaggregated revenue for the three months ended March 31, 2019 and 2018:
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LEASES (Tables) |
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Mar. 31, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||
LEASES | |||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of operating lease costs, including amounts capitalized to property, plant and equipment |
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Schedule of supplemental balance sheet information related to operating leases |
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Schedule of maturities of our operating lease liabilities |
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Schedule of future minimum lease payments for noncancelable operating leases |
At December 31, 2018, future minimum lease payments for noncancelable operating leases under ASC 840 (excluding oil and natural gas and other mineral leases, utilities, taxes, insurance and common area maintenance expenses) were:
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ACCOUNTING AND DISCLOSURE CHANGES - Recently Adopted Accounting and Disclosure Changes (Details) - USD ($) $ in Millions |
Mar. 31, 2019 |
Jan. 01, 2019 |
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Recently Issued Accounting and Disclosure Changes | ||
Right-of-use asset | $ 54 | |
Operating lease liability | $ 54 | |
ASU 2016-02 | Adoption Adjustment | ||
Recently Issued Accounting and Disclosure Changes | ||
Right-of-use asset | $ 66 | |
Operating lease liability | $ 66 |
OTHER INFORMATION (Details) - USD ($) $ in Millions |
3 Months Ended | ||
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Mar. 31, 2019 |
Mar. 31, 2018 |
Dec. 31, 2018 |
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Cash restricted for capital investments and distributions to a joint venture (JV) partner | $ 26 | $ 2 | |
Derivative assets | 79 | 168 | |
Amounts due from joint interest partners | 68 | 68 | |
Prepaid expenses | 20 | 16 | |
Other | 3 | ||
Other current assets, net | 167 | 255 | |
Accrued employee-related costs | 69 | 109 | |
Accrued interest | 56 | 15 | |
Accrued taxes other than on income | 51 | 38 | |
Asset retirement obligation | 32 | 31 | |
Operating lease liability | 27 | ||
Accrued distribution to JV partner | 19 | ||
Other | 31 | 24 | |
Accrued liabilities | 285 | 217 | |
Increase in the aggregate amount of ARO as a result of the adoption of new regulations | 87 | ||
Interest paid, net of capitalized amounts | 69 | $ 60 | |
Other long-term liabilities | |||
Non-current asset retirement obligation | $ 490 | $ 402 |
INVENTORIES (Details) - USD ($) $ in Millions |
Mar. 31, 2019 |
Dec. 31, 2018 |
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INVENTORIES | ||
Materials and supplies | $ 68 | $ 65 |
Finished goods | 3 | 4 |
Total | $ 71 | $ 69 |
DEBT - Deferred Gain and Issuance Costs (Details) - USD ($) $ in Millions |
Mar. 31, 2019 |
Dec. 31, 2018 |
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DEBT | ||
Net deferred gain and issuance costs | $ 203 | $ 216 |
Deferred gains | 293 | 313 |
Deferred issuance costs and original issue discounts | $ 90 | $ 97 |
DEBT - 2014 Revolving Credit Facility (Details) - 2014 Revolving Credit Facility - USD ($) $ in Millions |
May 01, 2019 |
Mar. 31, 2019 |
Dec. 31, 2018 |
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Debt | |||
Available borrowing capacity before a month-end minimum liquidity requirement | $ 256 | ||
Maximum borrowing capacity | 1,000 | ||
Financial covenant minimum month end liquidity | 150 | ||
Borrowing base | $ 2,300 | ||
Letters of Credit | |||
Debt | |||
Maximum sub-limit on borrowing capacity for issuance of letters of credit | 400 | $ 400 | |
Aggregate letters of credit issued | $ 168 | $ 162 |
DEBT - Note Repurchases (Details) - Second Lien Notes (Second Priority Lien) - USD ($) $ in Millions |
3 Months Ended | |
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Mar. 31, 2019 |
Dec. 31, 2018 |
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Repurchases of debt | ||
Principal amount of debt reduction through payment or repurchase | $ 18 | |
Debt instrument interest rate stated percentage | 8.00% | 8.00% |
Repurchase value of the principal amounts | $ 14 | |
Pre-tax gain on extinguishment of debt, net of a reduction in deferred issuance costs | $ 6 |
DEBT - Fair Value (Details) - USD ($) $ in Millions |
Mar. 31, 2019 |
Dec. 31, 2018 |
---|---|---|
DEBT | ||
Estimated fair value of long-term debt | $ 4,800 | $ 4,500 |
Debt carrying value | $ 5,269 | $ 5,251 |
JOINT VENTURES - Mezzanine Equity (Details) - USD ($) $ in Millions |
3 Months Ended | |
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Mar. 31, 2019 |
Mar. 31, 2018 |
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Mezzanine Equity - Redeemable Noncontrolling Interest - Ares | ||
Balance at the beginning of the period | $ 756 | |
Net (loss) income attributable to noncontrolling interests | 28 | $ 14 |
Balance at the end of the period | 766 | |
Mezzanine Equity - Redeemable Noncontrolling Interest - Ares | ||
Mezzanine Equity - Redeemable Noncontrolling Interest - Ares | ||
Balance at the beginning of the period | 756 | |
Net (loss) income attributable to noncontrolling interests | 28 | 14 |
Contributions from noncontrolling interest holders, net | 714 | |
Distributions to noncontrolling interest holders | (18) | (4) |
Balance at the end of the period | $ 766 | $ 724 |
JOINT VENTURES - BSP (Details) - USD ($) $ in Millions |
3 Months Ended | |
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Mar. 31, 2019 |
Mar. 31, 2018 |
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JOINT VENTURES | ||
Contribution net of transaction costs | $ 49 | $ 747 |
BSP JV | Joint venture with BSP | ||
JOINT VENTURES | ||
Contribution net of transaction costs | $ 49 |
DERIVATIVES - Interest-Rate Risk (Details) - Interest-rate contract $ in Billions |
May 31, 2018
USD ($)
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Derivatives | |
Hedged amount for variable-rate indebtedness | $ 1.3 |
One month LIBOR | |
Derivatives | |
Interest rate to be in place to receive payment | 2.75% |
PENSION AND POSTRETIREMENT BENEFIT PLANS (Details) - USD ($) $ in Millions |
3 Months Ended | |
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Mar. 31, 2019 |
Mar. 31, 2018 |
|
Net periodic benefit costs: | ||
Employer contributions to pension plan | $ 1 | |
Expected contribution to defined benefit pension plans during the reminder of 2019 | $ 3 | |
Pension Benefit | ||
Net periodic benefit costs: | ||
Interest cost | 1 | 1 |
Expected return on plan assets | (1) | (1) |
Recognized actuarial loss | 1 | |
Settlement loss | 2 | |
Net periodic benefit costs | 1 | 2 |
Postretirement Benefit | ||
Net periodic benefit costs: | ||
Service cost | 1 | 1 |
Interest cost | 1 | 1 |
Net periodic benefit costs | $ 2 | $ 2 |
REVENUE RECOGNITION - Commodity Sales Contracts and Marketing (Details) |
3 Months Ended |
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Mar. 31, 2019 | |
REVENUE RECOGNITION | |
Typical term of payment following invoicing | 30 days |
REVENUE RECOGNITION - Disaggregation of revenue (Details) - USD ($) $ in Millions |
3 Months Ended | |
---|---|---|
Mar. 31, 2019 |
Mar. 31, 2018 |
|
Disaggregation of revenue | ||
Oil and gas sales | $ 601 | $ 575 |
Other revenue | 178 | 72 |
Net derivative loss from commodity contracts | (89) | (38) |
Total revenues and other | 690 | 609 |
Oil | ||
Disaggregation of revenue | ||
Oil and gas sales | 480 | 466 |
NGLs | ||
Disaggregation of revenue | ||
Oil and gas sales | 59 | 63 |
Natural gas | ||
Disaggregation of revenue | ||
Oil and gas sales | 62 | 46 |
Electricity | ||
Disaggregation of revenue | ||
Other revenue | 34 | 24 |
Marketing, trading and other | ||
Disaggregation of revenue | ||
Other revenue | $ 144 | 47 |
Interest income | ||
Disaggregation of revenue | ||
Interest income | $ 1 |
LEASES - Operating lease costs (Details) $ in Millions |
3 Months Ended |
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Mar. 31, 2019
USD ($)
| |
Operating lease costs | |
Operating lease cost | $ 12 |
Short-term Lease, Cost | 20 |
Variable lease cost | 5 |
Total lease cost | 37 |
Investing activities, operating lease liabilities payment | |
Payment of operating lease liabilities reported in net cash used in investing activities | 9 |
Operating activities, operating lease liabilities payment | |
Payment of operating lease liabilities reported in net cash provided by operating activities | $ 3 |
LEASES - Supplement balance sheet information (Details) $ in Millions |
Mar. 31, 2019
USD ($)
|
---|---|
LEASES | |
Operating lease right-of-use assets, net | $ 54 |
Current liabilities | 27 |
Long-term liabilities | 27 |
Total operating lease liabilities | $ 54 |
Weighted-average remaining lease term (in years) | 2 years 10 months 24 days |
Weighted-average discount rate (as a percentage) | 11.50% |
LEASES - Operating lease liabilities (Details) $ in Millions |
3 Months Ended |
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Mar. 31, 2019
USD ($)
| |
LEASES | |
Impairment on right-of-use asset | $ 3 |
Operating lease liabilities | |
2019 | 27 |
2020 | 18 |
2021 | 7 |
2022 | 4 |
2023 | 2 |
Thereafter | 6 |
Less: Interest | (10) |
Present value of lease liabilities | $ 54 |
LEASES - Noncancelable operating leases (Details) - USD ($) $ in Millions |
3 Months Ended | |
---|---|---|
Mar. 31, 2018 |
Dec. 31, 2018 |
|
Noncancelable operating leases | ||
2019 | $ 12.0 | |
2020 | 8.0 | |
2021 | 7.0 | |
2022 | 7.0 | |
2023 | 6.0 | |
Thereafter | 28.0 | |
Total | $ 68.0 | |
Rental expense for operating leases | $ 2.8 |
INCOME TAXES (Details) |
3 Months Ended | |
---|---|---|
Mar. 31, 2019 |
Mar. 31, 2018 |
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INCOME TAXES | ||
Effective tax rate (as a percent) | 0.00% | 0.00% |
ASSET DIVESTITURE (Details) $ in Millions |
May 01, 2019
USD ($)
item
|
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ASSET DIVESTITURE | |
Working interest in Lost Hills field sold (in percent) | 50.00% |
Total consideration of the sale of Lost Hills field 50% interest | $ 200 |
Consideration in cash in the sale of Lost Hills field 50% interest | $ 168 |
Number of well development plan included in the sale of Lost Host field | item | 200 |
Minimum value of well development plan of Lost Hills field | $ 35 |
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