Document and Entity Information
Document and Entity Information - shares | 6 Months Ended | |
Jun. 30, 2023 | Jul. 21, 2023 | |
Document and Entity Information | ||
Document Type | 10-Q | |
Document Quarterly Report | true | |
Document Period End Date | Jun. 30, 2023 | |
Document Transition Report | false | |
Entity File Number | 001-36120 | |
Entity Registrant Name | ANTERO RESOURCES CORPORATION | |
Entity Incorporation, State or Country Code | DE | |
Entity Tax Identification Number | 80-0162034 | |
Entity Address, Address Line One | 1615 Wynkoop Street | |
Entity Address, City or Town | Denver | |
Entity Address, State or Province | CO | |
Entity Address, Postal Zip Code | 80202 | |
City Area Code | 303 | |
Local Phone Number | 357-7310 | |
Title of 12(b) Security | Common Stock, par value $0.01 | |
Trading Symbol | AR | |
Security Exchange Name | NYSE | |
Entity Current Reporting Status | Yes | |
Entity Interactive Data Current | Yes | |
Entity Filer Category | Large Accelerated Filer | |
Entity Small Business | false | |
Entity Emerging Growth Company | false | |
Entity Shell Company | false | |
Entity Common Stock, Shares Outstanding | 300,383,794 | |
Current Fiscal Year End Date | --12-31 | |
Document Fiscal Year Focus | 2023 | |
Document Fiscal Period Focus | Q2 | |
Entity Central Index Key | 0001433270 | |
Amendment Flag | false |
Condensed Consolidated Balance
Condensed Consolidated Balance Sheets - USD ($) $ in Thousands | Jun. 30, 2023 | Dec. 31, 2022 |
Current assets: | ||
Accounts receivable | $ 36,887 | $ 35,488 |
Accrued revenue | 323,440 | 707,685 |
Derivative instruments | 3,099 | 1,900 |
Prepaid expenses and other current assets | 21,302 | 42,452 |
Total current assets | 384,728 | 787,525 |
Oil and gas properties, at cost (successful efforts method): | ||
Unproved properties | 1,017,828 | 997,715 |
Proved properties | 13,615,891 | 13,234,777 |
Gathering systems and facilities | 5,802 | 5,802 |
Other property and equipment | 91,255 | 83,909 |
Property and equipment, gross | 14,730,776 | 14,322,203 |
Less accumulated depletion, depreciation, and amortization | (4,854,565) | (4,683,399) |
Property and equipment, net | 9,876,211 | 9,638,804 |
Operating leases right-of-use assets | 3,262,253 | 3,444,331 |
Derivative instruments | 7,934 | 9,844 |
Investment in unconsolidated affiliate | 218,196 | 220,429 |
Other assets | 17,488 | 17,106 |
Total assets | 13,766,810 | 14,118,039 |
Current liabilities: | ||
Accrued liabilities | 366,038 | 461,788 |
Revenue distributions payable | 359,487 | 468,210 |
Derivative instruments | 35,509 | 97,765 |
Short-term lease liabilities | 553,953 | 556,636 |
Deferred revenue, VPP | 28,878 | 30,552 |
Other current liabilities | 6,728 | 1,707 |
Total current liabilities | 1,506,864 | 1,774,909 |
Long-term liabilities: | ||
Long-term debt | 1,492,270 | 1,183,476 |
Deferred income tax liability, net | 792,149 | 759,861 |
Derivative instruments | 59,224 | 345,280 |
Long-term lease liabilities | 2,711,735 | 2,889,854 |
Deferred revenue, VPP | 74,337 | 87,813 |
Other liabilities | 61,903 | 59,692 |
Total liabilities | 6,698,482 | 7,100,885 |
Commitments and contingencies | ||
Equity: | ||
Preferred stock, $0.01 par value; authorized - 50,000 shares; none issued | ||
Common stock, $0.01 par value; authorized - 1,000,000 shares; 297,393 shares issued and 297,359 outstanding as of December 31, 2022, and 300,359 shares issued and outstanding as of June 30, 2023 | 3,004 | 2,974 |
Additional paid-in capital | 5,803,634 | 5,838,848 |
Retained earnings | 1,019,256 | 913,896 |
Treasury stock, at cost; 34 shares and zero shares as of December 31, 2022 and June 30, 2023, respectively | (1,160) | |
Total stockholders' equity | 6,825,894 | 6,754,558 |
Noncontrolling interests | 242,434 | 262,596 |
Total equity | 7,068,328 | 7,017,154 |
Total liabilities and equity | 13,766,810 | 14,118,039 |
Affiliated Entity | ||
Current liabilities: | ||
Accounts payable | 95,360 | 80,708 |
Nonrelated Party | ||
Current liabilities: | ||
Accounts payable | $ 60,911 | $ 77,543 |
Condensed Consolidated Balanc_2
Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares shares in Thousands | Jun. 30, 2023 | Dec. 31, 2022 |
Condensed Consolidated Balance Sheets | ||
Preferred stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Preferred stock, authorized shares | 50,000 | 50,000 |
Preferred stock, shares issued | 0 | 0 |
Common stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Common stock, authorized shares | 1,000,000 | 1,000,000 |
Common stock, shares issued | 300,359 | 297,393 |
Common stock, shares outstanding | 300,359 | 297,359 |
Treasury stock, shares | 0 | 34 |
Condensed Consolidated Statemen
Condensed Consolidated Statements of Operations and Comprehensive Income (Loss) - USD ($) shares in Thousands, $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2023 | Jun. 30, 2022 | Jun. 30, 2023 | Jun. 30, 2022 | |
Revenue and other: | ||||
Total revenue | $ 953,305 | $ 2,201,685 | $ 2,361,653 | $ 2,988,525 |
Operating expenses: | ||||
Lease operating | 28,748 | 25,253 | 58,069 | 43,033 |
Production and ad valorem taxes | 36,158 | 81,842 | 85,434 | 134,650 |
General and administrative | 53,901 | 44,439 | 111,162 | 80,130 |
Depletion, depreciation and amortization | 171,406 | 173,395 | 338,988 | 341,783 |
Impairment of property and equipment | 15,710 | 23,363 | 31,270 | 45,825 |
Accretion of asset retirement obligations | 1,204 | 804 | 2,082 | 3,248 |
Contract termination | 4,441 | 2,096 | 33,991 | 2,104 |
Loss (gain) on sale of assets | (220) | 71 | (311) | 1,857 |
Other operating expense | 225 | |||
Total operating expenses | 1,042,241 | 1,140,167 | 2,119,099 | 2,131,606 |
Operating income (loss) | (88,936) | 1,061,518 | 242,554 | 856,919 |
Other income (expense): | ||||
Interest expense, net | (27,928) | (34,213) | (53,628) | (71,926) |
Equity in earnings of unconsolidated affiliate | 19,098 | 14,713 | 36,779 | 39,891 |
Loss on early extinguishment of debt | (4,414) | (15,068) | ||
Loss on convertible note inducement | (86) | |||
Total other expense | (8,830) | (23,914) | (16,935) | (47,103) |
Income (loss) before income taxes | (97,766) | 1,037,604 | 225,619 | 809,816 |
Income tax benefit (expense) | 29,833 | (225,571) | (32,350) | (172,479) |
Net income (loss) and comprehensive income (loss) including noncontrolling interests | (67,933) | 812,033 | 193,269 | 637,337 |
Less: net income and comprehensive income attributable to noncontrolling interests | 15,151 | 46,898 | 62,922 | 28,621 |
Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation | $ (83,084) | $ 765,135 | $ 130,347 | $ 608,716 |
Income (loss) per share-basic (in dollars per share) | $ (0.28) | $ 2.46 | $ 0.44 | $ 1.95 |
Income (loss) per share-diluted (in dollars per share) | $ (0.28) | $ 2.29 | $ 0.42 | $ 1.81 |
Weighted average number of shares outstanding: | ||||
Basic (in shares) | 300,141 | 310,535 | 298,461 | 312,300 |
Diluted (in shares) | 300,141 | 334,561 | 311,488 | 337,589 |
Natural gas sales | ||||
Revenue and other: | ||||
Total revenue | $ 437,130 | $ 1,558,994 | $ 1,105,445 | $ 2,554,786 |
Natural gas liquids sales | ||||
Revenue and other: | ||||
Total revenue | 397,733 | 702,388 | 893,168 | 1,362,693 |
Oil sales | ||||
Revenue and other: | ||||
Total revenue | 57,962 | 89,185 | 109,773 | 152,479 |
Gathering, compression, water handling and treatment, processing, and transportation | ||||
Operating expenses: | ||||
Cost of goods and services sold | 663,975 | 656,212 | 1,309,147 | 1,246,490 |
Marketing. | ||||
Revenue and other: | ||||
Total revenue | 43,793 | 106,150 | 102,322 | 175,188 |
Operating expenses: | ||||
Cost of goods and services sold | 66,175 | 131,298 | 147,536 | 230,194 |
Commodity derivative fair value gains (losses) | ||||
Revenue and other: | ||||
Total revenue | 8,284 | (265,662) | 134,476 | (1,277,042) |
Amortization of deferred revenue, VPP | ||||
Revenue and other: | ||||
Total revenue | 7,618 | 9,375 | 15,151 | 18,647 |
Other revenue and income | ||||
Revenue and other: | ||||
Total revenue | 785 | 1,255 | 1,318 | 1,774 |
Exploration and mine expenses | ||||
Operating expenses: | ||||
Cost of goods and services sold | $ 743 | $ 1,394 | $ 1,506 | $ 2,292 |
Condensed Consolidated Statem_2
Condensed Consolidated Statements of Operations and Comprehensive Income (Loss) (Parenthetical) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2023 | Jun. 30, 2022 | Jun. 30, 2023 | Jun. 30, 2022 | |
Condensed Consolidated Statements of Operations and Comprehensive Income (Loss) | ||||
Equity-based compensation expense | $ 13,512 | $ 8,171 | $ 26,530 | $ 12,820 |
Condensed Consolidated Statem_3
Condensed Consolidated Statement of Equity - USD ($) shares in Thousands, $ in Thousands | Common Stock | Additional Paid-In Capital | Retained Earnings (Accumulated Deficit). | Treasury Stock | Noncontrolling Interests | Total |
Balances at Dec. 31, 2021 | $ 3,139 | $ 6,371,398 | $ (617,377) | $ 308,932 | $ 6,066,092 | |
Balances (in shares) at Dec. 31, 2021 | 313,930 | |||||
Increase (Decrease) in Stockholders' Equity | ||||||
Equity component of 2026 Convertible Notes, net | (24,411) | 3,229 | (21,182) | |||
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes | $ 8 | (10,385) | (10,377) | |||
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes (in shares) | 780 | |||||
Repurchases and retirements of common stock | $ (37) | (74,745) | (25,263) | (100,045) | ||
Repurchases and retirements of common stock (in shares) | (3,690) | |||||
Equity-based compensation | 4,649 | 4,649 | ||||
Distributions to non-controlling interest | (35,757) | (35,757) | ||||
Net income (loss) and comprehensive income (loss) | (156,419) | (18,277) | (174,696) | |||
Balance at Mar. 31, 2022 | $ 3,110 | 6,266,506 | (795,830) | 254,898 | 5,728,684 | |
Balance (in shares) at Mar. 31, 2022 | 311,020 | |||||
Balances at Dec. 31, 2021 | $ 3,139 | 6,371,398 | (617,377) | 308,932 | 6,066,092 | |
Balances (in shares) at Dec. 31, 2021 | 313,930 | |||||
Increase (Decrease) in Stockholders' Equity | ||||||
Net income (loss) and comprehensive income (loss) | 637,337 | |||||
Balance at Jun. 30, 2022 | $ 3,088 | 6,119,645 | (119,125) | 270,255 | 6,273,863 | |
Balance (in shares) at Jun. 30, 2022 | 308,812 | |||||
Balances at Mar. 31, 2022 | $ 3,110 | 6,266,506 | (795,830) | 254,898 | 5,728,684 | |
Balances (in shares) at Mar. 31, 2022 | 311,020 | |||||
Increase (Decrease) in Stockholders' Equity | ||||||
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes | $ 21 | (54,463) | (54,442) | |||
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes (in shares) | 2,112 | |||||
Conversion of 2026 Convertible Notes | $ 9 | 3,955 | 3,964 | |||
Conversion of 2026 Convertible Notes (in shares) | 921 | |||||
Repurchases and retirements of common stock | $ (52) | (104,524) | (88,430) | (193,006) | ||
Repurchases and retirements of common stock (in shares) | (5,241) | |||||
Equity-based compensation | 8,171 | 8,171 | ||||
Distributions to non-controlling interest | (31,541) | (31,541) | ||||
Net income (loss) and comprehensive income (loss) | 765,135 | 46,898 | 812,033 | |||
Balance at Jun. 30, 2022 | $ 3,088 | 6,119,645 | (119,125) | 270,255 | 6,273,863 | |
Balance (in shares) at Jun. 30, 2022 | 308,812 | |||||
Balances at Dec. 31, 2022 | $ 2,974 | 5,838,848 | 913,896 | $ (1,160) | 262,596 | 7,017,154 |
Balances (in shares) at Dec. 31, 2022 | 297,393 | (34) | ||||
Increase (Decrease) in Stockholders' Equity | ||||||
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes | $ 5 | (11,464) | (11,459) | |||
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes (in shares) | 514 | |||||
Conversion of 2026 Convertible Notes | $ 40 | 17,132 | 17,172 | |||
Conversion of 2026 Convertible Notes (in shares) | 4,030 | |||||
Repurchases and retirements of common stock | $ (26) | (51,503) | (24,987) | $ 1,160 | (75,356) | |
Repurchases and retirements of common stock (in shares) | (2,616) | 34 | ||||
Equity-based compensation | 13,018 | 13,018 | ||||
Distributions to non-controlling interest | (51,339) | (51,339) | ||||
Net income (loss) and comprehensive income (loss) | 213,431 | 47,771 | 261,202 | |||
Balance at Mar. 31, 2023 | $ 2,993 | 5,806,031 | 1,102,340 | 259,028 | 7,170,392 | |
Balance (in shares) at Mar. 31, 2023 | 299,321 | |||||
Balances at Dec. 31, 2022 | $ 2,974 | 5,838,848 | 913,896 | $ (1,160) | 262,596 | 7,017,154 |
Balances (in shares) at Dec. 31, 2022 | 297,393 | (34) | ||||
Increase (Decrease) in Stockholders' Equity | ||||||
Net income (loss) and comprehensive income (loss) | 193,269 | |||||
Balance at Jun. 30, 2023 | $ 3,004 | 5,803,634 | 1,019,256 | 242,434 | 7,068,328 | |
Balance (in shares) at Jun. 30, 2023 | 300,359 | |||||
Balances at Mar. 31, 2023 | $ 2,993 | 5,806,031 | 1,102,340 | 259,028 | 7,170,392 | |
Balances (in shares) at Mar. 31, 2023 | 299,321 | |||||
Increase (Decrease) in Stockholders' Equity | ||||||
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes | $ 11 | (15,909) | (15,898) | |||
Issuance of common stock upon vesting of equity-based compensation awards, net of shares withheld for income taxes (in shares) | 1,038 | |||||
Equity-based compensation | 13,512 | 13,512 | ||||
Distributions to non-controlling interest | (31,745) | (31,745) | ||||
Net income (loss) and comprehensive income (loss) | (83,084) | 15,151 | (67,933) | |||
Balance at Jun. 30, 2023 | $ 3,004 | $ 5,803,634 | $ 1,019,256 | $ 242,434 | $ 7,068,328 | |
Balance (in shares) at Jun. 30, 2023 | 300,359 |
Condensed Consolidated Statem_4
Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands | 6 Months Ended | |
Jun. 30, 2023 | Jun. 30, 2022 | |
Cash flows provided by (used in) operating activities: | ||
Net income including noncontrolling interests | $ 193,269 | $ 637,337 |
Adjustments to reconcile net income to net cash provided by operating activities: | ||
Depletion, depreciation, amortization and accretion | 341,070 | 345,031 |
Impairments | 31,270 | 45,825 |
Commodity derivative fair value gains (losses) | (134,476) | 1,277,042 |
Losses on settled commodity derivatives | (10,787) | (844,713) |
Payments for derivative monetizations | (202,339) | |
Deferred income tax expense | 32,288 | 171,707 |
Equity-based compensation expense | 26,530 | 12,820 |
Equity in earnings of unconsolidated affiliate | (36,779) | (39,891) |
Dividends of earnings from unconsolidated affiliate | 62,569 | 62,569 |
Amortization of deferred revenue | (15,151) | (18,647) |
Amortization of debt issuance costs, debt discount and debt premium | 1,732 | 2,515 |
Settlement of asset retirement obligations | (633) | (886) |
Loss (gain) on sale of assets | (311) | 1,857 |
Loss on early extinguishment of debt | 15,068 | |
Loss on convertible note inducement | 86 | |
Changes in current assets and liabilities: | ||
Accounts receivable | (1,399) | 53,623 |
Accrued revenue | 384,245 | (360,612) |
Other current assets | 21,294 | (22,566) |
Accounts payable including related parties | 12,701 | 50,378 |
Accrued liabilities | (102,668) | 37,203 |
Revenue distributions payable | (108,723) | 40,166 |
Other current liabilities | 5,377 | 22,559 |
Net cash provided by operating activities | 499,165 | 1,488,385 |
Cash flows provided by (used in) investing activities: | ||
Additions to unproved properties | (110,447) | (72,072) |
Drilling and completion costs | (517,591) | (393,506) |
Additions to other property and equipment | (9,058) | (11,162) |
Proceeds from asset sales | 311 | 195 |
Change in other assets | (1,255) | 1,711 |
Net cash used in investing activities | (638,040) | (474,834) |
Cash flows provided by (used in) financing activities: | ||
Repurchases of common stock | (75,356) | (293,051) |
Repayment of senior notes | (658,906) | |
Borrowings on bank credit facilities, net | 325,100 | 70,800 |
Convertible note inducement | (86) | |
Distributions to noncontrolling interests in Martica Holdings LLC | (83,084) | (67,298) |
Employee tax withholding for settlement of equity compensation awards | (27,357) | (64,819) |
Other | (342) | (277) |
Net cash provided by (used in) financing activities | 138,875 | (1,013,551) |
Net increase in cash and cash equivalents | 0 | 0 |
Cash and cash equivalents, beginning of period | 0 | 0 |
Cash and cash equivalents, end of period | 0 | 0 |
Supplemental disclosure of cash flow information: | ||
Cash paid during the period for interest | 51,927 | 89,326 |
Decrease in accounts payable and accrued liabilities for additions to property and equipment | $ (8,353) | $ (3,504) |
Organization
Organization | 6 Months Ended |
Jun. 30, 2023 | |
Organization | |
Organization | (1) Organization Antero Resources Corporation (individually referred to as “Antero” and together with its consolidated subsidiaries “Antero Resources,” or the “Company”) is engaged in the development, production, exploration and acquisition of natural gas, NGLs and oil properties in the Appalachian Basin in West Virginia and Ohio. The Company targets large, repeatable resource plays where horizontal drilling and advanced fracture stimulation technologies provide the means to economically develop and produce natural gas, NGLs and oil from unconventional formations. The Company’s corporate headquarters is located in Denver, Colorado. |
Summary of Significant Accounti
Summary of Significant Accounting Policies | 6 Months Ended |
Jun. 30, 2023 | |
Summary of Significant Accounting Policies | |
Summary of Significant Accounting Policies | (2) Summary of Significant Accounting Policies (a) Basis of Presentation These unaudited condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) applicable to interim financial information and should be read in the context of the Company’s December 31, 2022 consolidated financial statements and notes thereto for a more complete understanding of the Company’s operations, financial position and accounting policies. The Company’s December 31, 2022 consolidated financial statements were included in Antero Resources’ 2022 Annual Report on Form 10-K, which was filed with the SEC. These unaudited condensed consolidated financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim financial information, and, accordingly, do not include all of the information and footnotes required by GAAP for complete consolidated financial statements. In the opinion of management, these unaudited condensed consolidated financial statements include all adjustments (consisting of normal and recurring accruals) considered necessary to present fairly the Company’s financial position as of December 31, 2022 and June 30, 2023, results of operations for the three and six months ended June 30, 2022 and 2023 and cash flows for the six months ended June 30, 2022 and 2023. The Company has no items of other comprehensive income or loss; therefore, its net income or loss is equal to its comprehensive income or loss. Operating results for the period ended June 30, 2023 are not necessarily indicative of the results that may be expected for the full year because of the impact of fluctuations in prices received for natural gas, NGLs and oil, natural production declines, the uncertainty of exploration and development drilling results, fluctuations in the fair value of derivative instruments and other factors. (b) Principles of Consolidation The accompanying unaudited condensed consolidated financial statements include the accounts of Antero Resources Corporation, its wholly owned subsidiaries and its variable interest entity (“VIE”), Martica Holdings LLC, (“Martica”), for which the Company is the primary beneficiary. All significant intercompany accounts and transactions have been eliminated in the Company’s unaudited condensed consolidated financial statements. (c) Cash and Cash Equivalents The Company considers all liquid investments purchased with an initial maturity of three months or less to be cash equivalents. The carrying value of cash and cash equivalents approximates fair value due to the short-term nature of these instruments. From time to time, the Company may be in the position of a “book overdraft” in which outstanding checks exceed cash and cash equivalents. The Company classifies book overdrafts in accounts payable and revenue distributions payable within its condensed consolidated balance sheets, and classifies the change in accounts payable associated with book overdrafts as an operating activity within its unaudited condensed consolidated statements of cash flows. As of December 31, 2022, the book overdrafts included within accounts payable and revenue distributions payable were million, respectively. As of June 30, 2023, the book overdrafts included within accounts payable and revenue distributions payable were (d) Income (Loss) Per Common Share Income (loss) per common share—basic for each period is computed by dividing net income (loss) attributable to Antero by the basic weighted average number of shares outstanding during the period. Income (loss) per common share—diluted for each period is computed after giving consideration to the potential dilution from (i) outstanding equity awards using the treasury stock method and (ii) shares of common stock issuable upon conversion of the 2026 Convertible Notes (as defined below in Note 7—Long-Term Debt) using the if-converted method. The Company includes restricted stock unit (“RSU”) awards, performance share unit (“PSU”) awards and stock options in the calculation of diluted weighted average shares outstanding based on the number of common shares that would be issuable if the end of the period was also the end of the performance period required for the vesting of the awards. During periods in which the Company incurs a net loss, diluted weighted average shares outstanding are equal to basic weighted average shares outstanding because the effects of all equity awards and the 2026 Convertible Notes are anti-dilutive. The following is a reconciliation of the Company’s income (loss) attributable to common stockholders for basic and diluted income (loss) per share (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2022 2023 2022 2023 Net income (loss) attributable to Antero Resources Corporation—common shareholders $ 765,135 (83,084) 608,716 130,347 Add: Interest expense for 2026 Convertible Notes 967 — 1,934 1,085 Less: Tax-effect of interest expense for 2026 Convertible Notes (224) — (449) (233) Net income (loss) attributable to Antero Resources Corporation—common shareholders and assumed conversions $ 765,878 (83,084) 610,201 131,199 Income (loss) per share—basic $ 2.46 (0.28) 1.95 0.44 Income (loss) per share—diluted $ 2.29 (0.28) 1.81 0.42 Weighted average common shares outstanding—basic 310,535 300,141 312,300 298,461 Weighted average common shares outstanding—diluted 334,561 300,141 337,589 311,488 The following is a reconciliation of the Company’s basic weighted average shares outstanding to diluted weighted average shares outstanding during the periods presented (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2022 2023 2022 2023 Basic weighted average number of shares outstanding 310,535 300,141 312,300 298,461 Add: Dilutive effect of RSUs 3,161 — 3,629 1,593 Add: Dilutive effect of PSUs 2,108 — 2,892 967 Add: Dilutive effect of 2026 Convertible Notes 18,757 — 18,768 10,467 Diluted weighted average number of shares outstanding 334,561 300,141 337,589 311,488 Weighted average number of outstanding securities excluded from calculation of diluted income (loss) per common share (1) RSUs — 4,070 — 2,260 PSUs — 1,791 — 377 Stock options 351 324 351 324 2026 Convertible Notes — 9,076 — — (1) The potential dilutive effects of these awards were excluded from the computation of income (loss) per common share—diluted because the inclusion of these awards would have been anti-dilutive. (e) Recently Issued Accounting Standard Convertible Debt Instruments In August 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2020-06, Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity Debt with Conversion and Other Options , that require separate accounting for conversion features, and instead, allows the debt instrument and conversion features to be accounted for as a single debt instrument. 2021. The Company adopted the standard effective January 1, 2022 Upon adoption of this new standard, the Company reclassified $24 million, net of deferred income taxes and equity issuance costs, from additional paid-in capital and increased long-term debt by $27 million, reduced deferred income tax liability by $6 million and reduced accumulated deficit by $3 million as of January 1, 2022. Additionally, annual interest expense for the 2026 Convertible Notes beginning January 1, 2022 is based on an effective interest rate of |
Transactions
Transactions | 6 Months Ended |
Jun. 30, 2023 | |
Transactions | |
Transactions | (3) Transactions (a) Conveyance of Overriding Royalty Interest On June 15, 2020, the Company announced the consummation of a transaction with an affiliate of Sixth Street Partners, LLC (“Sixth Street”) relating to certain overriding royalty interests across the Company’s existing asset base (the “ORRIs”). The ORRIs include an overriding royalty interest of 1.25% in all of the Company’s operated proved developed properties in West Virginia and Ohio, subject to certain excluded wells (the “Initial PDP Override”) as of April 1, 2020, and an overriding royalty interest of 3.75% in all of the Company’s undeveloped properties in West Virginia and Ohio (the “Development Override”) as of April 1, 2020. Wells turned to sales after April 1, 2020 and prior to the later of (a) the date on which the Company turns to sales 2.2 million lateral feet (net to the Company’s interest) of horizontal wells burdened by the Development Override and (b) the earlier of (i) April 1, 2023 and (ii) the date on which the Company turns to sales 3.82 million lateral feet (net to the Company’s interest) of horizontal wells burdened by the Development Override, are subject to the Development Override. As of April 1, 2023, the Company had turned to sales over 2.2 million lateral feet and less than 3.82 million lateral feet. As a result, wells turned to sales on or after April 1, 2023 will not be subject to the ORRIs. The ORRIs also include an additional overriding royalty interest of 2.00% of the Company’s working interest in the properties underlying the Initial PDP Override (the “Incremental Override”). The Incremental Override (or a portion thereof, as applicable) may be re-conveyed to the Company (at the Company’s election) if certain production targets attributable to the ORRIs are achieved through March 31, 2023. Any portion of the Incremental Override that may not be re-conveyed to the Company based on the Company failing to achieve such production volumes through March 31, 2023 will remain with Martica. As of March 31, 2023, the portion of the Incremental Override that may be re-conveyed to the Company as a result of achieving certain production targets was 76% and the portion that will remain with Martica was 24% . Prior to Sixth Street achieving an internal rate of return of 13% and 1.5 x cash-on-cash return (the “Hurdle”), Sixth Street will receive all distributions in respect of the Initial PDP Override and the Development Override, and 24% of all distributions in respect of the Incremental Override, and the Company will receive 76% of all distributions in respect of the Incremental Override. Following Sixth Street achieving the Hurdle, the Company will receive 85% of the distributions in respect of the ORRIs to which Sixth Street was entitled immediately prior to the Hurdle being achieved. (b) Drilling Partnership On February 17, 2021, Antero Resources announced the formation of a drilling partnership with QL Capital Partners (“QL”), an affiliate of Quantum Energy Partners, for the Company’s 2021 through 2024 drilling program. Under the terms of the arrangement, each year in which QL participates represents an annual tranche, and QL will be conveyed a working interest in any wells spud by Antero Resources during such tranche year. For 2021, 2022 and 2023, Antero Resources and QL agreed to the estimated internal rate of return (“IRR”) of the Company’s capital budget for each annual tranche, and QL agreed to participate in the 2021, 2022, and 2023 tranches. For 2024, Antero Resources will propose a capital budget and estimated IRR for all wells to be spud during such year and, subject to the mutual agreement of the parties that the estimated IRR for the year exceeds a specified return, QL will be obligated to participate in such tranche. Antero Resources develops and manages the drilling program associated with each tranche, including the selection of wells. Additionally, for each annual tranche in which QL participates, Antero Resources and QL will enter into assignments, bills of sale and conveyances pursuant to which QL will be conveyed a proportionate working interest percentage in each well spud in that year, which conveyances will not be subject to any reversion. Under the terms of the arrangement, QL funded 20% and 15% of development capital for wells spud in 2021 and 2022, respectively, and will fund development capital of (i) 15% for wells spud in 2023 and (ii) if they participate in 2024, between 15% and 20% for wells spud in 2024, which funding amounts represent QL’s proportionate working interest in such wells. Additionally, Antero Resources may receive a carry in the form of a one-time payment from QL for each annual tranche if the IRR for such tranche exceeds certain specified returns, which will be determined no earlier than October 31 and no later than December 1 following the end of each tranche year. During the year ended December 31, 2022, the Company received a carry of million attributable to the 2021 tranche. All of the wells spud during each calendar year period will be a separate annual tranche. Capital costs in excess of, and cost savings below, a specified percentage of budgeted amounts for each annual tranche will be for Antero Resources’ account. Subject to the preceding sentence, for any wells included in a tranche, QL is obligated and responsible for its working interest share of costs and liabilities, and is entitled to its working interest share of revenues, associated with such wells for the life of such wells. The Company has accounted for the drilling partnership as a conveyance under ASC 932, Extractive Activities—Oil and Gas |
Revenue
Revenue | 6 Months Ended |
Jun. 30, 2023 | |
Revenue | |
Revenue | (4) Revenue (a) Disaggregation of Revenue The table set forth below presents revenue disaggregated by type and reportable segment to which it relates (in thousands). See Note 16—Reportable Segments to the unaudited condensed financial statements for more information on reportable segments. Three Months Ended June 30, Six Months Ended June 30, 2022 2023 2022 2023 Reportable Segment Revenues from contracts with customers: Natural gas sales $ 1,558,994 437,130 2,554,786 1,105,445 Exploration and production Natural gas liquids sales (ethane) 90,230 50,163 157,293 122,213 Exploration and production Natural gas liquids sales (C3+ NGLs) 612,158 347,570 1,205,400 770,955 Exploration and production Oil sales 89,185 57,962 152,479 109,773 Exploration and production Marketing 106,150 43,793 175,188 102,322 Marketing Other revenue — 365 — 540 Exploration and production Total revenue from contracts with customers 2,456,717 936,983 4,245,146 2,211,248 Income (loss) from derivatives, deferred revenue and other sources, net (255,032) 16,322 (1,256,621) 150,405 Total revenue $ 2,201,685 953,305 2,988,525 2,361,653 (b) Transaction Price Allocated to Remaining Performance Obligations For the Company’s product sales that have a contract term greater than one year, the Company utilized the practical expedient in ASC 606, Revenue from Contracts with Customers (“ASC 606”), which does not require the disclosure of the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under the Company’s product sales contracts, each unit of product delivered to the customer 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. For the Company’s product sales that have a contract term of one year or less, the Company utilized the practical expedient in ASC 606, which does not require the 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 (c) Contract Balances Under the Company’s sales contracts, the Company invoices customers after its 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. As of December 31, 2022 and June 30, 2023, the Company’s receivables from contracts with customers were $ |
Equity Method Investment
Equity Method Investment | 6 Months Ended |
Jun. 30, 2023 | |
Equity Method Investment | |
Equity Method Investment | (5) Equity Method Investment (a) Summary of Equity Method Investment As of June 30, 2023, Antero owned 29.0% of Antero Midstream’s common stock, which is reflected in Antero’s unaudited condensed consolidated financial statements using the equity method of accounting. The following table sets forth a reconciliation of Antero’s investment in unconsolidated affiliate (in thousands): Balance as of December 31, 2022 (1) $ 220,429 Equity in earnings of unconsolidated affiliate 36,779 Dividends from unconsolidated affiliate (62,569) Elimination of intercompany profit 23,557 Balance as of June 30, 2023 (1) $ 218,196 (1) The fair value of the Company’s investment in Antero Midstream as of December 31, 2022 and June 30, 2023 was $1.5 billion and $1.6 billion, respectively, based on the quoted market share price of Antero Midstream . |
Accrued Liabilities
Accrued Liabilities | 6 Months Ended |
Jun. 30, 2023 | |
Accrued Liabilities | |
Accrued Liabilities | (6) Accrued Liabilities Accrued liabilities consisted of the following items (in thousands): (Unaudited) December 31, June 30, 2022 2023 Capital expenditures $ 57,361 51,364 Gathering, compression, processing and transportation expenses 162,783 159,685 Marketing expenses 61,118 30,823 Interest expense, net 31,892 32,454 Production and ad valorem taxes 32,536 55,073 General and administrative expense 32,477 24,558 Derivative settlements payable 53,732 183 Other 29,889 11,898 Total accrued liabilities $ 461,788 366,038 |
Long-Term Debt
Long-Term Debt | 6 Months Ended |
Jun. 30, 2023 | |
Long-Term Debt. | |
Long-Term Debt | (7) Long-Term Debt Long-term debt consisted of the following items (in thousands): (Unaudited) December 31, June 30, 2022 2023 Credit Facility (a) $ 34,800 359,900 8.375% senior notes due 2026 (c) 96,870 96,870 7.625% senior notes due 2029 (d) 407,115 407,115 5.375% senior notes due 2030 (e) 600,000 600,000 4.25% convertible senior notes due 2026 (f) 56,932 39,426 Total principal 1,195,717 1,503,311 Unamortized debt issuance costs (12,241) (11,041) Long-term debt $ 1,183,476 1,492,270 (a) Senior Secured Revolving Credit Facility Antero Resources has a senior secured revolving credit facility (the “Credit Facility”) with a consortium of banks. Borrowings under the Credit Facility are subject to borrowing base limitations based on the collateral value of Antero Resources’ assets and are subject to regular semi-annual redeterminations. As of December 31, 2022 and June 30, 2023, the Credit Facility had a borrowing base of billion. The borrowing base was re- affirmed in the semi-annual redetermination in April 2023. The maturity date of the Credit Facility is the earlier of (i) October 26, 2026 and (ii) the date that is prior to the earliest stated redemption date of any series of the Company’s then outstanding senior notes. As of June 30, 2023, the Credit Facility had an available borrowing capacity of The Credit Facility contains requirements with respect to leverage and current ratios, and certain covenants, including restrictions on our ability to incur debt and limitations on our ability to pay dividends unless certain customary conditions are met, in each case, subject to customary carve-outs and exceptions. Antero Resources was in compliance with all of the financial covenants under the Credit Facility as of December 31, 2022 and June 30, 2023. The Credit Facility provides for borrowing at either an Adjusted Term Secured Overnight Financing Rate (“SOFR”), an Adjusted Daily Simple SOFR or an Alternate Base Rate (each as defined in the Credit Facility). The Credit Facility provides for interest only payments until maturity at which time all outstanding borrowings are due. Interest is payable at a variable rate based on SOFR or the Alternate Base Rate, determined by election at the time of borrowing, plus an applicable margin rate under the Credit Facility. Interest at the time of borrowing is determined with reference to the Antero Resources’ then-current leverage ratio subject to certain exceptions. Commitment fees on the unused portion of the Credit Facility are due quarterly at rates ranging from with respect to the Credit Facility, determined with reference to borrowing base utilization, subject to certain exceptions based on the leverage ratio then in effect. The Credit Facility includes fall away covenants, lower interest rates and reduced collateral requirements that Antero Resources may elect if Antero Resources is assigned an Investment Grade Rating (as defined in the Credit Facility). As of December 31, 2022, Antero Resources had an outstanding balance under the Credit Facility of $35 million, with a weighted average interest rate of 6.42%, and outstanding letters of credit of $504 million. As of June 30, 2023, Antero Resources had an outstanding balance under the Credit Facility of (b) 5.00% Senior Notes Due 2025 On December 21, 2016, Antero Resources issued $600 million of 5.00% senior notes due March 1, 2025 (the “2025 Notes”) at par . The Company repurchased or otherwise redeemed all of the 2025 Notes between 2020 and the first quarter of 2022, and the 2025 Notes were fully retired as of March 1, 2022. Interest on the 2025 Notes was payable on March 1 and September 1 of each year. See “—Debt Repurchase Program” below for more information. (c) 8.375% Senior Notes Due 2026 On January 4, 2021, Antero Resources issued $500 million of 8.375% senior notes due July 15, 2026 (the “2026 Notes”) at par . The Company redeemed or otherwise repurchased million principal amount of the 2026 Notes remained outstanding. See “—Debt Repurchase Program” below for more information. The 2026 Notes are unsecured and effectively subordinated to the Credit Facility to the extent of the value of the collateral securing the Credit Facility. The 2026 Notes rank pari passu to Antero Resources’ other outstanding senior notes. The 2026 Notes are guaranteed on a full and unconditional and joint and several senior unsecured basis by Antero Resources’ existing subsidiaries that guarantee the Credit Facility and certain of its future restricted subsidiaries. Interest on the 2026 Notes is payable on January 15 and July 15 of each year. Antero Resources may redeem all or part of the 2026 Notes at any time on or after January 15, 2024 at redemption prices ranging from on or after January 15, 2026. At any time prior to January 15, 2024, Antero Resources may also redeem the 2026 Notes, in whole or in part, at a price equal to of the principal amount of the 2026 Notes plus a “make-whole” premium and accrued and unpaid interest. If Antero Resources undergoes a change of control followed by a rating decline, the holders of the 2026 Notes will have the right to require Antero Resources to repurchase all or a portion of the notes at a price equal to (d) 7.625% Senior Notes Due 2029 On January 26, 2021, Antero Resources issued $700 million of 7.625% senior notes due February 1, 2029 (the “2029 Notes”) at par . The Company redeemed or otherwise repurchased million principal amount of the 2029 Notes remained outstanding. See “—Debt Repurchase Program” below for more information. The 2029 Notes are unsecured and effectively subordinated to the Credit Facility to the extent of the value of the collateral securing the Credit Facility. The 2029 Notes rank pari passu to Antero Resources’ other outstanding senior notes. The 2029 Notes are guaranteed on a full and unconditional and joint and several senior unsecured basis by Antero Resources’ existing subsidiaries that guarantee the Credit Facility and certain of its future restricted subsidiaries. Interest on the 2029 Notes is payable on February 1 and August 1 of each year. Antero Resources may redeem all or part of the 2029 Notes at any time on or after February 1, 2024 at redemption prices ranging from on or after February 1, 2027. In addition, on or before February 1, 2024, Antero Resources may redeem up to million aggregate principal amount of outstanding 2029 Notes. At any time prior to February 1, 2024, Antero Resources may also redeem the 2029 Notes, in whole or in part, at a price equal to of the principal amount of the 2029 Notes plus a “make-whole” premium and accrued and unpaid interest. If Antero Resources undergoes a change of control followed by a rating decline, the holders of the 2029 Notes will have the right to require Antero Resources to repurchase all or a portion of the notes at a price equal to (e) 5.375% Senior Notes Due 2030 On June 1, 2021, Antero Resources issued $600 million of 5.375% senior notes due March 1, 2030 (the “2030 Notes”) at par . The 2030 Notes are unsecured and effectively subordinated to the Credit Facility to the extent of the value of the collateral securing the Credit Facility. The 2030 Notes rank pari passu to Antero Resources’ other outstanding senior notes. The 2030 Notes are guaranteed on a full and unconditional and joint and several senior unsecured basis by Antero Resources’ existing subsidiaries that guarantee the Credit Facility and certain of its future restricted subsidiaries. Interest on the 2030 Notes is payable on March 1 and September 1 of each year. Antero Resources may redeem all or part of the 2030 Notes at any time on or after March 1, 2025 at redemption prices ranging from on or after March 1, 2028. In addition, on or before March 1, 2025, Antero Resources may redeem up to of the principal amount of the 2030 Notes, plus accrued and unpaid interest. At any time prior to March 1, 2025, Antero Resources may also redeem the 2030 Notes, in whole or in part, at a price equal to of the principal amount of the 2030 Notes plus a “make-whole” premium and accrued and unpaid interest. If Antero Resources undergoes a change of control followed by a rating decline, the holders of the 2030 Notes will have the right to require Antero Resources to repurchase all or a portion of the notes at a price equal to (f) 4.25% Convertible Senior Notes Due 2026 On August 21, 2020, Antero Resources issued $250 million in aggregate principal amount of 4.25% convertible senior notes due September 1, 2026 (the “2026 Convertible Notes”). On September 2, 2020, Antero Resources issued an additional million of the 2026 Convertible Notes. Proceeds from the issuance of the 2026 Convertible Notes totaled million. The Company extinguished million principal amount of the 2026 Convertible Notes in 2021. In addition, between 2022 and the second quarter of 2023, million aggregate principal amount of the 2026 Convertible Notes were converted pursuant to their terms or induced into conversion by the Company. See “—Conversions and Inducements,” for more information. As of June 30, 2023, million principal amount of the 2026 Convertible Notes remained outstanding. The 2026 Convertible Notes were issued pursuant to an indenture and are senior, unsecured obligations of Antero Resources. The 2026 Convertible Notes bear interest at a fixed rate of per annum, payable semi-annually in arrears on March 1 and September 1 of each year, commencing on March 1, 2021. The initial conversion rate is 230.2026 shares of Antero Resources’ common stock per $1,000 principal amount of 2026 Convertible Notes, subject to adjustment upon the occurrence of specified events. As of June 30, 2023, the if-converted value of the 2026 Convertible Notes was million. The 2026 Convertible Notes will mature on September 1, 2026, unless earlier repurchased, redeemed or converted. Before May 1, 2026, noteholders will have the right to convert their 2026 Convertible Notes only upon the occurrence of the following events: ● during any calendar quarter (and only during such calendar quarter) commencing after the calendar quarter ending on September 30, 2020, if the Last Reported Sale Price per share of Antero Resources’ common stock exceeds 130% of the Conversion Price for each of at least 20 Trading Days (whether or not consecutive) during the 30 consecutive Trading Days ending on, and including, the last Trading Day of the immediately preceding calendar quarter (the “Stock Price Condition”); ● during the five consecutive Business Days immediately after any 10 consecutive Trading Day period (such 10 consecutive Trading Day period, the “Measurement Period”) if the Trading Price per $1,000 principal amount of 2026 Convertible Notes, as determined following a request by a noteholder in accordance with the procedures set forth below, for each Trading Day of the Measurement Period was less than 98% of the product of the Last Reported Sales Price per share of common stock on such Trading Day and the conversion rate on such Trading Day; ● if Antero Resources calls any or all of the 2026 Convertible Notes for redemption, at any time prior to the close of business on the scheduled Trading Day immediately preceding the redemption date; or ● upon the occurrence of certain specified corporate events as set forth in the indenture governing the 2026 Convertible Notes. From and after May 1, 2026, noteholders may convert their 2026 Convertible Notes at any time at their election until the close of business on the second scheduled Trading Day immediately before the maturity date. Upon conversion, Antero Resources may satisfy its conversion obligation by paying and/or delivering, as the case may be, cash, shares of Antero Resources’ common stock or a combination of cash and shares of Antero Resources’ common stock, at Antero Resources’ election, in the manner and subject to the terms and conditions provided in the indenture governing the 2026 Convertible Notes. The 2026 Convertible Notes have met the Stock Price Condition allowing holders of the 2026 Convertible Notes to exercise their conversion right as of June 30, 2023. The conversion rate is subject to adjustment under certain circumstances in accordance with the terms of the indenture governing the 2026 Convertible Notes. In addition, following certain corporate events, as described in the indenture governing the 2026 Convertible Notes, that occur prior to the maturity date, Antero Resources will increase the conversion rate for a holder who elects to convert its 2026 Convertible Notes in connection with such a corporate event. If certain corporate events that constitute a Fundamental Change occur, then noteholders may require Antero Resources to repurchase their 2026 Convertible Notes at a cash repurchase price equal to the principal amount of the 2026 Convertible Notes to be repurchased, plus accrued and unpaid interest, if any, to, but excluding, the Fundamental Change Repurchase Date. The definition of Fundamental Change includes certain business combination transactions involving Antero Resources and certain de-listing events with respect to Antero Resources’ common stock. Upon issuance, the Company separately accounted for the liability and equity components of the 2026 Convertible Notes. 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 2026 Convertible Notes and the estimated fair value of the liability component was recorded as a debt discount and was amortized to interest expense, together with debt issuance costs, over the term of the 2026 Convertible Notes using the effective interest method, with an effective interest rate of 15.1% per annum. As of the issuance date, the fair value of the 2026 Convertible Notes was estimated at $172 million, resulting in a debt discount at inception of $116 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 2026 Convertible Notes issuance. This equity component was recorded, net of deferred taxes and issuance costs, in additional paid-in capital within the condensed consolidated balance sheet and statement of stockholders’ equity. Transaction costs related to the 2026 Convertible Notes issuance were allocated to the liability and equity components based on their relative fair values. Issuance costs attributable to the liability component were recorded within debt issuance costs on the condensed consolidated balance sheet and were amortized over the term of the 2026 Convertible Notes using the effective interest method. Issuance costs attributable to the equity component were recorded as a charge to additional paid-in capital within the condensed consolidated balance sheet and statement of stockholders’ equity. Effective January 1, 2022, the Company adopted ASU 2020-06 whereby the Company reclassified the equity component of the 2026 Convertible Notes outstanding on such date, net of deferred income taxes and equity issuance costs, from additional paid-in capital to long-term debt. See Note 2—Summary of Significant Accounting Policies to the unaudited condensed consolidated financial statements. Conversions and Inducements During the first quarter of 2023, $9 million aggregate principal amount of the 2026 Convertible Notes were converted pursuant to their terms, and an additional $9 million aggregate principal amount of the 2026 Convertible Notes were induced into conversion by the Company. The Company elected to settle these conversions by issuing million. There were no conversions of the 2026 Convertible Notes during the second quarter of 2023 or the first or second quarters of 2022. The 2026 Convertible Notes consist of the following (in thousands): (Unaudited) December 31, June 30, 2022 2023 Principal $ 56,932 39,426 Less: unamortized debt issuance costs (1,159) (702) Net carrying value $ 55,773 38,724 Interest expense recognized on the 2026 Convertible Notes related to the stated interest rate, amortization of the debt discount and debt issuance costs totaled $1 million and $0.5 million for the three months ended June 30, 2022 and 2023, respectively, and $2 million and $1 million for the six months ended June 30, 2022 and 2023, respectively. (g) Debt Repurchase Program During the first quarter of 2022, the Company redeemed the remaining $585 million aggregate principal amount of its 2025 Notes at a redemption price of 101.25% of the principal amount thereof, plus accrued and unpaid interest and recognized a loss on early debt extinguishment of $11 million. During the second quarter of 2022, the Company repurchased $13 million of its 2026 Notes and $50 million of its 2029 Notes at a weighted average premium of 106% and recognized a loss on early debt extinguishment of $4 million. There were |
Asset Retirement Obligations
Asset Retirement Obligations | 6 Months Ended |
Jun. 30, 2023 | |
Asset Retirement Obligations | |
Asset Retirement Obligations | (8) Asset Retirement Obligations The following table presents a reconciliation of the Company’s asset retirement obligations (in thousands): Asset retirement obligations—December 31, 2022 $ 59,485 Obligations incurred 561 Accretion expense 2,082 Settlement of obligations (633) Revisions to prior estimates 301 Asset retirement obligations—June 30, 2023 $ 61,796 Asset retirement obligations are included in Other liabilities on the Company’s condensed consolidated balance sheets. |
Equity-Based Compensation and C
Equity-Based Compensation and Cash Awards | 6 Months Ended |
Jun. 30, 2023 | |
Equity-Based Compensation and Cash Awards | |
Equity-Based Compensation and Cash Awards | (9) Equity-Based Compensation and Cash Awards On June 17, 2020, Antero Resources’ stockholders approved the Antero Resources Corporation 2020 Long-Term Incentive Plan (the “2020 Plan”), which replaced the Antero Resources Corporation Long-Term Incentive Plan (the “2013 Plan”), and the 2020 Plan became effective as of such date. The 2020 Plan provides for grants of stock options (including incentive stock options), stock appreciation rights, restricted stock awards, RSU awards, vested stock awards, dividend equivalent awards and other stock-based and cash awards. The terms and conditions of the awards granted are established by the Compensation Committee of Antero Resources’ Board of Directors. Employees, officers, non-employee directors and other service providers of the Company and its affiliates are eligible to receive awards under the 2020 Plan. No further awards will be granted under the 2013 Plan on or after June 17, 2020. The 2020 Plan provides for the reservation of 10,050,000 shares of the Company’s common stock, plus the number of certain shares that become available again for delivery from the 2013 Plan in accordance with the share recycling provisions described below. The share recycling provisions allow for all or any portion of an award (including an award granted under the 2013 Plan that was outstanding as of June 17, 2020) that expires or is cancelled, forfeited, exchanged, settled for cash or otherwise terminated without actual delivery of the shares to be considered not delivered and thus, available for new awards under the 2020 Plan. Further, any shares withheld or surrendered in payment of any taxes relating to awards that were outstanding under either the 2013 Plan as of June 17, 2020 or are granted under the 2020 Plan (other than stock options and stock appreciation rights), will again be available for new awards under the 2020 Plan. A total of 6,835,261 shares were available for future grant under the 2020 Plan as of June 30, 2023. Antero Midstream Partners LP’s (“Antero Midstream Partners”) general partner was authorized to grant up to 10,000,000 common units representing limited partner interests in Antero Midstream Partners under the Antero Midstream Partners LP Long-Term Incentive Plan (the “AMP Plan”) to non-employee directors of its general partner and certain officers, employees and consultants of Antero Midstream Partners and its affiliates (which includes Antero Resources). Antero Resources deconsolidated Antero Midstream Partners on March 12, 2019 RSUs (all such RSUs, the “Converted AM RSU Awards”) under the Antero Midstream Corporation Long Term Incentive Plan (the “AM Plan”). Each RSU award under the AM Plan represented a right to receive one share of Antero Midstream common stock. As of June 30, 2023, all Converted AM RSU Awards were fully vested. The Company’s equity-based compensation expense, by type of award, is as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2022 2023 2022 2023 RSU awards $ 4,774 8,720 7,494 15,982 PSU awards 3,012 4,442 4,431 9,847 Converted AM RSU Awards (1) 35 — 195 1 Equity awards issued to directors 350 350 700 700 Total expense $ 8,171 13,512 12,820 26,530 (1) Antero Resources recognized compensation expense for equity awards granted under both the 2013 Plan and the AMP Plan because the awards under the AMP Plan are accounted for as if they are distributed by Antero Midstream Partners to Antero Resources. Antero Resources allocates a portion of equity-based compensation expense related to grants prior to March 12, 2019 (date of deconsolidation) to Antero Midstream Partners based on its proportionate share of Antero Resources’ labor costs. As of June 30, 2023, all Converted AM RSU Awards were fully vested, and there is no remaining unamortized expense attributable to these awards. (a) Restricted Stock Unit Awards A summary of RSU activity is as follows: Weighted Average Number of Grant Date Shares Fair Value Total awarded and unvested—December 31, 2022 4,676,219 $ 15.29 Granted 1,458,594 25.87 Vested (2,202,895) 9.02 Forfeited (69,321) 22.57 Total awarded and unvested—June 30, 2023 3,862,597 $ 22.74 As of June 30, 2023, there was $76 million of unamortized equity-based compensation expense related to unvested RSUs. That expense is expected to be recognized over a weighted average period of (b) Performance Share Unit Awards Performance Share Unit Awards Based on Total Shareholder Return In March 2023, the Company granted PSU awards to certain of its senior management and executive officers that vest based on Antero Resources’ absolute total shareholder return (“TSR”) determined as of the last day of each of three one-year performance periods ending on March 7, 2024, March 7, 2025 and March 7, 2026, and one cumulative three-year performance period ending on March 7, 2026, in each case, subject to certain continued employment criteria (“2023 Absolute TSR PSUs”). The number of shares of common stock that may ultimately be earned following the end of the cumulative three-year performance period with respect to the 2023 Absolute TSR PSUs ranges from zero to 200% of the target number of 2023 Absolute TSR PSUs originally granted. Expense related to these PSUs is recognized on a graded-vested basis over the term of each performance period. Forfeitures are accounted for as they occur by reversing the expense previously recognized for awards that were forfeited during the period. The following table presents the assumptions used in the Monte Carlo valuation model and the grant date fair value information for the 2023 Absolute TSR PSUs: Dividend yield — % Volatility 82 % Risk-free interest rate 4.61 % Weighted average fair value of awards granted—Absolute TSR $ 33.96 Performance Share Unit Awards Based on Leverage Ratio In March 2023, the Company granted PSUs to certain of its senior management and executive officers that vest based on the Company’s total debt less cash and cash equivalents divided by the Company’s Adjusted EBITDAX (as defined in the award agreement) determined as of the last day of each of three one-year performance periods ending on December 31, 2023, December 31, 2024 and December 31, 2025, in each case, subject to certain continued employment criteria (“2023 Leverage Ratio PSUs”). The number of shares of common stock that may ultimately be earned following the end of the third performance period with respect to the 2023 Leverage Ratio PSUs ranges from zero to 200% of the target number of 2023 Leverage Ratio PSUs originally granted. Expense related to the 2023 Leverage Ratio PSUs is recognized on a graded-vested basis over the term of each performance period that reflects the number of shares of common stock that are expected to be issued at the end of each measurement period, and such expense is reversed if the likelihood of achieving the performance condition becomes improbable. As of June 30, 2023, the likelihood of achieving the performance conditions related to the 2023 Leverage Ratio PSUs was probable. Summary Information for Performance Share Unit Awards A summary of PSU activity is as follows: Weighted Average Number of Grant Date Units Fair Value Total awarded and unvested—December 31, 2022 1,329,725 $ 23.18 Granted 417,466 28.51 Vested (1) (335,000) 2.97 Total awarded and unvested—June 30, 2023 1,412,191 $ 29.54 (1) During the three months ended June 30, 2023, the PSUs granted in 2020 that were based on absolute TSR and relative TSR met the performance criteria to achieve vesting at 112% and 126% of target, respectively, and converted into approximately 0.4 million shares of the Company’s common stock. As of June 30, 2023, there was $29 million of unamortized equity-based compensation expense related to unvested PSUs. That expense is expected to be recognized over a weighted average period of (c) Converted AM RSU Awards A summary of the Converted AM RSU Awards is as follows: Weighted Average Number of Grant Date Units Fair Value Total awarded and unvested—December 31, 2022 2,827 $ 12.38 Vested (2,827) 12.38 Total awarded and unvested—June 30, 2023 — $ — (d) Cash Awards In January 2020, the Company granted cash awards of $3 million to certain executives under the 2013 Plan, and compensation expense for these awards was recognized ratably over the vesting period for each of three tranches through January 20, 2023. In July 2020, the Company granted additional cash awards in the aggregate of . As of December 31, 2022 and June 30, 2023, the Company has recorded |
Fair Value
Fair Value | 6 Months Ended |
Jun. 30, 2023 | |
Fair Value. | |
Fair Value | (10) Fair Value The carrying values of accounts receivable and accounts payable as of December 31, 2022 and June 30, 2023 approximated market values because of their short-term nature. The carrying values of the amounts outstanding under the Credit Facility as of December 31, 2022 and June 30, 2023 approximated fair value because the variable interest rates are reflective of current market conditions. The following table sets forth the fair value and carrying value of the senior notes and 2026 Convertible Notes (in thousands): (Unaudited) December 31, 2022 June 30, 2023 Fair Carrying Fair Carrying Value (1) Value (2) Value (1) Value (2) 2026 Notes $ 100,987 96,123 100,076 96,235 2029 Notes 410,860 402,872 412,204 403,151 2030 Notes 556,260 593,908 548,220 594,260 2026 Convertible Notes 406,039 55,773 208,414 38,724 Total $ 1,474,146 1,148,676 1,268,914 1,132,370 (1) Fair values are based on Level 2 market data inputs. (2) Carrying values are presented net of unamortized debt issuance costs and debt discounts or premiums. See Note 9—Equity-Based Compensation and Cash Awards to the unaudited condensed consolidated financial statements for information regarding the fair value of equity-based awards. See Note 11—Derivative Instruments to the unaudited condensed consolidated financial statements for information regarding the fair value of derivative financial instruments. |
Derivative Instruments
Derivative Instruments | 6 Months Ended |
Jun. 30, 2023 | |
Derivative Instruments. | |
Derivative Instruments | (11) Derivative Instruments The Company is exposed to certain risks relating to its ongoing business operations, and it may use derivative instruments to manage its commodity price risk. In addition, the Company periodically enters into contracts that contain embedded features that are required to be bifurcated and accounted for separately as derivatives. (a) Commodity Derivative Positions The Company periodically enters into natural gas, NGLs and oil derivative contracts with counterparties to hedge the price risk associated with its production. These derivatives are not entered into for trading purposes. To the extent that changes occur in the market prices of natural gas, NGLs and oil, the Company is exposed to market risk on these open contracts. This market risk exposure is generally offset by the change in market prices of natural gas, NGLs and oil recognized upon the ultimate sale of the Company’s production. The Company was party to various fixed price commodity swap contracts that settled during the three and six months ended June 30, 2022 and 2023. The Company enters into these swap contracts when management believes that favorable future sales prices for the Company’s production can be secured. Under these swap agreements, when actual commodity prices upon settlement exceed the fixed price provided by the swap contracts, the Company pays the difference to the counterparty. When actual commodity prices upon settlement are less than the contractually provided fixed price, the Company receives the difference from the counterparty. In addition, the Company has entered into basis swap contracts in order to hedge the difference between the New York Mercantile Exchange (“NYMEX”) index price and a local index price. Under these basis swap agreements, when actual commodity prices upon settlement exceed the fixed price provided by the swap contracts, the Company receives the difference from the counterparty. When actual commodity prices upon settlement are less than the contractually provided fixed price, the Company pays the difference to the counterparty. The Company’s derivative contracts have not been designated as hedges for accounting purposes; therefore, all gains and losses are recognized in the Company’s statements of operations. As of June 30, 2023, the Company’s fixed price swap positions excluding Martica, the Company’s consolidated VIE, were as follows: Weighted Average Commodity / Settlement Period Index Contracted Volume Price Natural Gas July-December 2023 Henry Hub 43,000 MMBtu/day $ 2.37 /MMBtu The Company has a call option and an embedded put option tied to NYMEX pricing for the production volumes associated with the Company’s retained interest in the volumetric production payment transaction (“VPP”) properties. The put option was embedded within another contract, and since the embedded put option was not clearly and closely related to its host contract, the Company bifurcated this derivative instrument and reflects it at fair value in the unaudited condensed consolidated financial statements. As of June 30, 2023, the Company’s call option and embedded put option arrangements were as follows: Embedded Call Option Put Option Commodity / Settlement Period Index Contracted Volume Strike Price Strike Price Natural Gas July-December 2023 Henry Hub 55,000 MMBtu/day $ 2.466 /MMBtu $ 2.466 /MMBtu January-December 2024 Henry Hub 53,000 MMBtu/day 2.477 /MMBtu 2.527 /MMBtu January-December 2025 Henry Hub 44,000 MMBtu/day 2.564 /MMBtu 2.614 /MMBtu January-December 2026 Henry Hub 32,000 MMBtu/day 2.629 /MMBtu 2.679 /MMBtu As of June 30, 2023, the Company’s natural gas basis swap positions, which settle on the pricing index to basis differential of the Columbia Gas Transmission pipeline (“TCO”) to the NYMEX Henry Hub natural gas price were as follows: Weighted Average Commodity / Settlement Period Index to Basis Differential Contracted Volume Hedged Differential Natural Gas July-December 2023 NYMEX to TCO 50,000 MMBtu/day $ 0.525 /MMBtu January-December 2024 NYMEX to TCO 50,000 MMBtu/day 0.530 /MMBtu As of June 30, 2023, the Company’s fixed price swap positions for Martica, the Company’s consolidated VIE, were as follows: Weighted Average Commodity / Settlement Period Index Contracted Volume Price Natural Gas July-December 2023 Henry Hub 32,496 MMBtu/day $ 2.35 /MMBtu January-December 2024 Henry Hub 23,885 MMBtu/day 2.33 /MMBtu January-March 2025 Henry Hub 18,021 MMBtu/day 2.53 /MMBtu Natural Gasoline July-December 2023 Mont Belvieu Natural Gasoline-OPIS Non-TET 227 Bbl/day 40.74 /Bbl Oil July-December 2023 West Texas Intermediate 77 Bbl/day 44.72 /Bbl January-December 2024 West Texas Intermediate 43 Bbl/day 44.02 /Bbl January-March 2025 West Texas Intermediate 39 Bbl/day 45.06 /Bbl (b) Summary The table below presents a summary of the fair values of the Company’s derivative instruments and where such values are recorded in the condensed consolidated balance sheets (in thousands). (Unaudited) Balance Sheet December 31, June 30, Location 2022 2023 Asset derivatives not designated as hedges for accounting purposes: Embedded derivatives—current Derivative instruments 1,900 3,099 Embedded derivatives—noncurrent Derivative instruments 9,844 7,934 Total asset derivatives (1) 11,744 11,033 Liability derivatives not designated as hedges for accounting purposes: Commodity derivatives—current (2) Derivative instruments 97,765 35,509 Commodity derivatives—noncurrent (2) Derivative instruments 345,280 59,224 Total liability derivatives (1) 443,045 94,733 Net derivatives liability (1) $ (431,301) (83,700) (1) The fair value of derivative instruments was determined using Level 2 inputs. (2) As of December 31, 2022, $47 million of commodity derivative liabilities, including $28 million of current commodity derivatives and $19 million of noncurrent commodity derivatives, are attributable to the Company’s consolidated VIE, Martica. As of June 30, 2023, $17 million of commodity derivative liabilities, including $10 million of current commodity derivatives and $7 million of noncurrent commodity derivatives, are attributable to the Company’s consolidated VIE, Martica. The following table sets forth the gross values of recognized derivative assets and liabilities, the amounts offset under master netting arrangements with counterparties, and the resulting net amounts presented in the condensed consolidated balance sheets as of the dates presented, all at fair value (in thousands): (Unaudited) December 31, 2022 June 30, 2023 Net Amounts of Net Amounts of Gross Gross Assets Gross Gross Assets Amounts Amounts Offset (Liabilities) on Amounts Amounts Offset (Liabilities) on Recognized Recognized Balance Sheet Recognized Recognized Balance Sheet Commodity derivative assets $ 276 (276) — $ 422 (422) — Embedded derivative assets 11,744 — 11,744 11,033 — 11,033 Commodity derivative liabilities (443,321) 276 (443,045) (95,155) 422 (94,733) The following table sets forth a summary of derivative fair value gains and losses and where such values are recorded in the unaudited condensed consolidated statements of operations (in thousands): Statement of Operations Three Months Ended June 30, Six Months Ended June 30, Location 2022 2023 2022 2023 Commodity derivative fair value gains (losses) (1) Revenue $ (237,680) 6,232 (1,232,163) 133,312 Embedded derivative fair value gains (losses) (1) Revenue $ (27,982) 2,052 (44,879) 1,164 (1) The fair value of derivative instruments was determined using Level 2 inputs . Commodity derivative fair value gains (losses) for the six months ended June 30, 2023, includes a loss of $202 million related to the early settlement of the Company’s natural gas swaption agreement during the first quarter of 2023. The payment for this early settlement is classified as an operating cash flow on the Company’s condensed consolidated statement of cash flows. |
Leases
Leases | 6 Months Ended |
Jun. 30, 2023 | |
Leases | |
Leases | (12) Leases The Company leases certain office space, processing plants, drilling rigs and completion services, gas gathering lines, compressor stations, and other office and field equipment. Leases with an initial term of 12 months or less are considered short-term and are not recorded on the balance sheet. Instead, the short-term leases are recognized in expense on a straight-line basis over the lease term. Most leases include one or more options to renew, with renewal terms that can extend the lease from one or more. The exercise of the lease renewal options is at the Company’s sole discretion. The depreciable lives of the leased assets are limited by the expected lease term, unless there is a transfer of title or purchase option reasonably certain of exercise. Certain of the Company’s lease agreements include minimum payments based on a percentage of produced volumes over contractual levels and others include rental payments adjusted periodically for inflation. The Company considers all contracts that have assets specified in the contract, either explicitly or implicitly, that the Company has substantially all of the capacity of the asset, and has the right to obtain substantially all of the economic benefits of that asset, without the lessor’s ability to have a substantive right to substitute that asset, as leased assets. For any contract deemed to include a leased asset, that asset is capitalized on the balance sheet as a right-of-use asset and a corresponding lease liability is recorded at the present value of the known future minimum payments of the contract using a discount rate on the date of commencement. The leased asset classification is determined at the date of recording as either operating or financing, depending upon certain criteria of the contract. The discount rate used for present value calculations is the discount rate implicit in the contract. If an implicit rate is not determinable, a collateralized incremental borrowing rate is used at the date of commencement. As new leases commence or previous leases are modified the discount rate used in the present value calculation is the current period applicable discount rate. The Company has made an accounting policy election to adopt the practical expedient for combining lease and non-lease components on an asset class basis. This expedient allows the Company to combine non-lease components such as real estate taxes, insurance, maintenance and other operating expenses associated with the leased premises with the lease component of a lease agreement on an asset class basis when the non-lease components of the agreement cannot be easily bifurcated from the lease payment. Currently, the Company is only applying this expedient to certain office space agreements. (a) Supplemental Balance Sheet Information Related to Leases The Company’s lease assets and liabilities consisted of the following items (in thousands): (Unaudited) December 31, June 30, Leases Balance Sheet Classification 2022 2023 Operating Leases Operating lease right-of-use assets: Processing plants Operating lease right-of-use assets $ 1,849,116 1,732,132 Drilling rigs and completion services Operating lease right-of-use assets 85,405 52,094 Gas gathering lines and compressor stations (1) Operating lease right-of-use assets 1,463,756 1,435,070 Office space Operating lease right-of-use assets 41,822 39,777 Vehicles Operating lease right-of-use assets 756 109 Other office and field equipment Operating lease right-of-use assets 3,476 3,071 Total operating lease right-of-use assets $ 3,444,331 3,262,253 Operating lease liabilities: Short-term operating lease liabilities Short-term lease liabilities $ 556,137 553,107 Long-term operating lease liabilities Long-term lease liabilities 2,888,194 2,709,146 Total operating lease liabilities $ 3,444,331 3,262,253 Finance Leases Finance lease right-of-use assets: Vehicles Other property and equipment $ 2,159 3,435 Total finance lease right-of-use assets (2) $ 2,159 3,435 Finance lease liabilities: Short-term finance lease liabilities Short-term lease liabilities $ 499 846 Long-term finance lease liabilities Long-term lease liabilities 1,660 2,589 Total finance lease liabilities $ 2,159 3,435 (1) Gas gathering lines and compressor stations includes $1.4 billion related to Antero Midstream as of December 31, 2022 and June 30, 2023. See “—Related party lease disclosure” for additional discussion. (2) Financing lease assets are recorded net of accumulated amortization of $1 million as of December 31, 2022 and June 30, 2023 . The processing plants, gathering lines and compressor stations that are classified as lease liabilities are classified as such under ASC 842, Leases (b) Supplemental Information Related to Leases Costs associated with operating and finance leases were included in the unaudited condensed consolidated statement of operations and comprehensive loss (in thousands): Three Months Ended June 30, Six Months Ended June 30, Cost Classification Location 2022 2023 2022 2023 Operating lease cost Statement of operations Gathering, compression, processing and transportation $ 365,343 407,445 731,177 788,728 Operating lease cost Statement of operations General and administrative 2,787 3,030 5,654 5,967 Operating lease cost Statement of operations Contract termination — 2,808 — 3,930 Operating lease cost Statement of operations Lease operating 44 21 89 42 Operating lease cost Balance sheet Proved properties (1) 41,100 31,602 48,859 71,372 Total operating lease cost $ 409,274 444,906 785,779 870,039 Finance lease cost: Amortization of right-of-use assets Statement of operations Depletion, depreciation and amortization $ 107 546 225 638 Interest on lease liabilities Statement of operations Interest expense 51 162 65 276 Total finance lease cost $ 158 708 290 914 Short-term lease payments $ 28,348 34,707 77,108 72,408 (1) Capitalized costs related to drilling and completion activities. (c) Supplemental Cash Flow Information Related to Leases The following table presents the Company’s supplemental cash flow information related to leases (in thousands): Six Months Ended June 30, 2022 2023 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 675,563 654,938 Operating cash flows from finance leases 66 276 Investing cash flows from operating leases 39,781 61,092 Financing cash flows from finance leases 277 343 Noncash activities: Right-of-use assets obtained in exchange for new operating lease obligations $ 215,157 51,737 Increase (decrease) to existing right-of-use assets and lease obligations from operating lease modifications, net (1) $ (47,728) 40,176 (1) During the six months ended June 30, 2022, the weighted average discount rate for remeasured operating leases increased from 4.5% as of December 31, 2021 to 5.1% as of June 30, 2022. During the six months ended June 30, 2023, the weighted average discount rate for remeasured operating leases increased from 5.2% as of December 31, 2022 to 5.8% as of June 30, 2023. (d) Maturities of Lease Liabilities The table below is a schedule of future minimum payments for operating and financing lease liabilities as of June 30, 2023 (in thousands): Operating Leases Financing Leases Total 2023 $ 374,215 669 374,884 2024 685,594 1,339 686,933 2025 609,747 1,297 611,044 2026 556,196 961 557,157 2027 457,972 112 458,084 Thereafter 1,252,713 33 1,252,746 Total lease payments 3,936,437 4,411 3,940,848 Less: imputed interest (674,184) (976) (675,160) Total $ 3,262,253 3,435 3,265,688 (e) Lease Term and Discount Rate The following table sets forth the Company’s weighted average remaining lease term and discount rate: December 31, 2022 June 30, 2023 Operating Leases Finance Leases Operating Leases Finance Leases Weighted average remaining lease term 7.2 years 3.5 years 6.9 years 3.4 years Weighted average discount rate 5.3 % 7.4 % 5.6 % 8.1 % (f) Related Party Lease Disclosure The Company has gathering and compression service agreements with Antero Midstream that include: (i) the second amended and restated gathering and compression agreement dated December 8, 2019 (the “2019 gathering and compression agreement”), (ii) gathering and compression agreements from Antero Midstream’s acquisition of certain Marcellus gathering and compression assets (the “Marcellus gathering and compression agreements”) and (iii) a compression agreement from Antero Midstream’s acquisition of certain Utica compressors (the “Utica compression agreement” and, together with the 2019 gathering and compression agreement and the Marcellus gathering and compression agreements, the “gathering and compression agreements”). Pursuant to the gathering and compression agreements with Antero Midstream, the Company has dedicated substantially all of its current and future acreage in West Virginia, Ohio and Pennsylvania to Antero Midstream for gathering and compression services. The 2019 gathering and compression agreement has an initial term through 2038, the Marcellus gathering and compression agreements expire between 2024 and 2031, and the Utica compression agreement has two dedicated areas that expire in 2024 and 2030. Upon expiration of each of the Marcellus gathering and compression agreements and the Utica compression agreement, Antero Midstream will continue to provide gathering and compression services under the 2019 gathering and compression agreement. Under the gathering and compression agreements, Antero Midstream receives a low-pressure gathering fee per Mcf, a high-pressure gathering fee per Mcf and a compression fee per Mcf, as applicable, subject to annual adjustments based on the consumer price index. If and to the extent the Company requests that Antero Midstream construct new low pressure lines, high pressure lines and compressor stations, the 2019 gathering and compression agreement contains options at Antero Midstream’s election for either (i) minimum volume commitments that require Antero Resources to utilize or pay for . In addition, certain of the Marcellus gathering and compression agreements provide for a minimum volume commitment that requires the Company to utilize or pay for . The 2019 gathering and compression agreement includes a growth incentive fee program whereby low-pressure gathering fees will be reduced from 2020 through 2023 to the extent the Company achieves certain quarterly volumetric targets. The Company’s throughput gathered under the Marcellus gathering and compression agreements is not considered in low pressure gathering volume targets. Upon completion of the initial contract term, the 2019 gathering and compression agreement will continue in effect from year to year until such time as the agreement is terminated, effective upon an anniversary of the effective date of the agreement, by either the Company or Antero Midstream on or before the 180th day prior to the anniversary of such effective date. The Company achieved the volumetric targets during each of the first and second quarters of 2022 and 2023, and earned fee rebates of $12 million for the three months ended June 30, 2022 and 2023 and $24 million for the six months ended June 30, 2022 and 2023. Gathering and compression fees paid by Antero related to these agreements were $164 million and $185 million for the three months ended June 30, 2022 and 2023, respectively. million, respectively. |
Commitments
Commitments | 6 Months Ended |
Jun. 30, 2023 | |
Commitments | |
Commitments | (13) Commitments The following table sets forth a schedule of future minimum payments for the Company’s contractual obligations, which include leases that have a lease term in excess of one year as of June 30, 2023 (in thousands): Processing, Gathering, Firm Compression Operating and Imputed Interest Transportation and Water Service Financing Leases for Leases Other (a) (b) (c) (c) (d) Total Remainder of 2023 $ 594,682 35,382 286,449 88,435 2,586 1,007,534 2024 1,147,772 63,212 533,031 153,902 6,009 1,903,926 2025 1,134,296 51,865 486,261 124,783 4,875 1,802,080 2026 1,131,882 18,688 459,146 98,011 2,250 1,709,977 2027 1,127,234 17,400 384,429 73,655 — 1,602,718 Thereafter 5,444,784 80,556 1,116,372 136,374 — 6,778,086 Total $ 10,580,650 267,103 3,265,688 675,160 15,720 14,804,321 (a) Firm Transportation The Company has entered into firm transportation agreements with various pipelines in order to facilitate the delivery of its production to market. These contracts commit the Company to transport minimum daily natural gas or NGLs volumes at negotiated rates or pay for any deficiencies at specified reservation fee rates. The amounts in this table are based on the Company’s minimum daily volumes at the reservation fee rate. The values in the table represent the gross amounts that the Company is committed to pay; however, the Company will record in the unaudited condensed consolidated financial statements its proportionate share of costs based on its working interest. (b) Processing, Gathering, Compression and Water Service Commitments The Company has entered into various long- term gas processing, gathering, compression and water service agreements. Certain of these agreements were determined to be leases. The minimum payment obligations under the agreements that are not leases are presented in this column. The values in the table represent the gross amounts that the Company is committed to pay; however, the Company will record in the unaudited condensed consolidated financial statements its proportionate share of costs based on its working interest. (c) Operating and Finance Leases, including Imputed Interest The Company has obligations under contracts for services provided by drilling rigs and completion fleets, processing, gathering, and compression services agreements, and office and equipment leases. The values in the table represent the gross amounts that Antero Resources is committed to pay; however, the Company will record in its financial statements its proportionate share of costs based on its working interests. See Note 12—Leases to the unaudited condensed consolidated financial statements for more information on the Company’s operating and finance leases. (d) Other The Company has entered into various land acquisition and sand supply agreements. Certain of these agreements contain minimum payment obligations over various terms. The values in the table represent the minimum payments due under these arrangements. None of these agreements were determined to be leases. (e) Contract Terminations The Company incurs costs associated with the delay or cancellation of certain contracts with third-parties. These costs are recorded in Contract termination and included in the statement of operations and comprehensive income (loss). During the six months ended June 30, 2023, the Company executed an early termination of its firm transportation commitment of million. There are no remaining payment obligations related to these delayed or cancelled contracts as of June 30, 2023. |
Contingencies
Contingencies | 6 Months Ended |
Jun. 30, 2023 | |
Contingencies | |
Contingencies | (14) Contingencies Environmental In June 2018, the Company received a Notice of Violation (“NOV”) from the U.S. Environmental Protection Agency (“EPA”) Region III for alleged violations of the federal Clean Air Act and the West Virginia State Implementation Plan. The NOV alleges that combustion devices at these facilities did not meet applicable air permitting requirements. Separately, in June 2018, the Company received an information request from the EPA Region III pursuant to Section 114(a) of the Clean Air Act relating to the facilities that were inspected in September 2017 as well as additional Antero Resources facilities for the purpose of determining if the additional facilities have the same alleged compliance issues that were identified during the September 2017 inspections. Subsequently, the West Virginia Department of Environmental Protection (“WVDEP”) and the EPA Region V (covering Ohio facilities) each conducted its own inspections, and the Company has separately received NOVs from WVDEP and EPA Region V related to similar issues being investigated by the EPA Region III. The Company continues to negotiate with the EPA and WVDEP to resolve the issues alleged in the NOVs and the information request. The Company’s operations at these facilities are not suspended, and management does not expect these matters to have a material adverse effect on the Company’s financial condition, results of operations, or cash flows. Other The Company is party to various other legal proceedings and claims in the ordinary course of its business. The Company believes that certain of these matters will be covered by insurance and that the outcome of other matters will not have a material adverse effect on the Company’s unaudited condensed consolidated financial position, results of operations or cash flows. In addition, pending litigation against the Company and other similarly situated peer operators could have an impact on the methods for determining the amount of permitted post-production costs and types of costs that have been, and may be, deducted from royalty payments, among other things. A ruling was recently received in an immaterial case to which the Company is a party, and the Company continues to analyze how this decision may impact other cases to which the Company is a party. The Company cannot predict how these issues may ultimately be resolved, and therefore is also unable to estimate any potential damages, if any, that may result. |
Related Parties
Related Parties | 6 Months Ended |
Jun. 30, 2023 | |
Related Parties | |
Related Parties | (15) Related Parties Substantially all of Antero Midstream’s revenues were and are derived from transactions with Antero Resources. See Note 16—Reportable Segments to the unaudited condensed consolidated financial statements for the operating results of the Company’s reportable segments. |
Reportable Segments
Reportable Segments | 6 Months Ended |
Jun. 30, 2023 | |
Reportable Segments | |
Reportable Segments | (16) Reportable Segments (a) Summary of Reportable Segments The Company’s operations, which are located in the United States, are organized into three reportable segments: (i) the exploration, development and production of natural gas, NGLs and oil; (ii) marketing and utilization of excess firm transportation capacity and (iii) midstream services through the Company’s equity method investment in Antero Midstream. Substantially all of the Company’s production revenues are attributable to customers located in the United States; however, some of the Company’s production revenues are attributable to customers who then transport the Company’s production to foreign countries for resale or consumption. These segments are monitored separately by management for performance and are consistent with internal financial reporting. These segments have been identified based on the differing products and services, regulatory environment and the expertise required for these operations. Management evaluates the performance of the Company’s business segments based on operating income (loss). General and administrative expenses were allocated to the midstream segment based on the nature of the expenses and on a combination of the segments’ proportionate share of the Company’s consolidated property and equipment, capital expenditures and labor costs, as applicable. General and administrative expenses related to the marketing segment are not allocated because they are immaterial. Other income, income taxes and interest expense are primarily managed and evaluated on a consolidated basis. Intersegment sales were transacted at prices which approximate market. Accounting policies for each segment are the same as the Company’s accounting policies described in Note 2—Summary of Significant Accounting Policies to the unaudited condensed consolidated financial statements. Exploration and Production The exploration and production segment is engaged in the development, production, exploration and acquisition of natural gas, NGLs and oil properties located in the Appalachian Basin. The Company targets large, repeatable resource plays where horizontal drilling and advanced fracture stimulation technologies provide the means to economically develop and produce natural gas, NGLs and oil from unconventional formations. Marketing Where feasible, the Company purchases and sells third-party natural gas and NGLs and markets its excess firm transportation capacity, or engages third parties to conduct these activities on the Company’s behalf, in order to optimize the revenues from these transportation agreements. The Company has entered into long-term firm transportation agreements for a significant portion of its current and expected future production in order to secure guaranteed capacity to favorable markets. Equity Method Investment in Antero Midstream The Company receives midstream services through its equity method investment in Antero Midstream. Antero Midstream owns, operates and develops midstream energy infrastructure primarily to service the Company’s production and completion activity in the Appalachian Basin. Antero Midstream’s assets consist of gathering pipelines, compressor stations, interests in processing and fractionation plants and water handling assets. Antero Midstream provides midstream services to Antero Resources under long-term contracts. (b) Reportable Segments Financial Information The operating results and assets of the Company’s reportable segments were as follows (in thousands): Three Months Ended June 30, 2022 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliate Total Sales and revenues: Third-party $ 2,095,144 106,150 242 (242) 2,201,294 Intersegment 391 — 228,665 (228,665) 391 Total revenue 2,095,535 106,150 228,907 (228,907) 2,201,685 Operating expenses: Lease operating 25,253 — — — 25,253 Gathering, compression, processing, transportation and water handling 656,212 — 43,299 (43,299) 656,212 General and administrative 44,439 — 16,079 (16,079) 44,439 Depletion, depreciation and amortization 173,395 — 35,675 (35,675) 173,395 Impairment of property and equipment 23,363 — 3,702 (3,702) 23,363 Other 86,207 131,298 1,756 (1,756) 217,505 Total operating expenses 1,008,869 131,298 100,511 (100,511) 1,140,167 Operating income (loss) $ 1,086,666 (25,148) 128,396 (128,396) 1,061,518 Equity in earnings of unconsolidated affiliates $ 14,713 — 22,824 (22,824) 14,713 Capital expenditures for segment assets $ 260,864 — 77,767 (77,767) 260,864 Three Months Ended June 30, 2023 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliate Total Sales and revenues: Third-party $ 909,092 43,793 274 (274) 952,885 Intersegment 420 — 258,013 (258,013) 420 Total revenue 909,512 43,793 258,287 (258,287) 953,305 Operating expenses: Lease operating 28,748 — — — 28,748 Gathering, compression, processing, transportation and water handling 663,975 — 52,595 (52,595) 663,975 General and administrative 53,901 — 18,162 (18,162) 53,901 Depletion, depreciation and amortization 171,406 — 35,233 (35,233) 171,406 Impairment of property and equipment 15,710 — — — 15,710 Other 42,326 66,175 6,774 (6,774) 108,501 Total operating expenses 976,066 66,175 112,764 (112,764) 1,042,241 Operating income (loss) $ (66,554) (22,382) 145,523 (145,523) (88,936) Equity in earnings of unconsolidated affiliates $ 19,098 — 25,972 (25,972) 19,098 Capital expenditures for segment assets $ 637,096 — 41,782 (41,782) 637,096 Six Months Ended June 30, 2022 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliate Total Sales and revenues: Third-party $ 2,812,525 175,188 637 (637) 2,987,713 Intersegment 812 — 446,761 (446,761) 812 Total revenue 2,813,337 175,188 447,398 (447,398) 2,988,525 Operating expenses: Lease operating 43,033 — — — 43,033 Gathering, compression, processing, transportation and water handling 1,246,490 — 85,311 (85,311) 1,246,490 General and administrative 80,130 — 34,010 (34,010) 80,130 Depletion, depreciation and amortization 341,783 — 63,975 (63,975) 341,783 Impairment of property and equipment 45,825 — 3,702 (3,702) 45,825 Other 144,151 230,194 2,850 (2,850) 374,345 Total operating expenses 1,901,412 230,194 189,848 (189,848) 2,131,606 Operating income (loss) $ 911,925 (55,006) 257,550 (257,550) 856,919 Equity in earnings of unconsolidated affiliates $ 39,891 — 46,056 (46,056) 39,891 Capital expenditures for segment assets $ 476,740 — 162,034 (162,034) 476,740 Six Months Ended June 30, 2023 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliate Total Sales and revenues: Third-party $ 2,258,568 102,322 546 (546) 2,360,890 Intersegment 763 — 517,216 (517,216) 763 Total revenue 2,259,331 102,322 517,762 (517,762) 2,361,653 Operating expenses: Lease operating 58,069 — — — 58,069 Gathering, compression, processing, transportation and water handling 1,309,147 — 110,468 (110,468) 1,309,147 General and administrative 111,162 — 35,509 (35,509) 111,162 Depletion, depreciation and amortization 338,988 — 70,429 (70,429) 338,988 Impairment of property and equipment 31,270 — — — 31,270 Other 99,164 171,299 7,488 (7,488) 270,463 Total operating expenses 1,947,800 171,299 223,894 (223,894) 2,119,099 Operating income (loss) $ 311,531 (68,977) 293,868 (293,868) 242,554 Equity in earnings of unconsolidated affiliates $ 36,779 — 50,428 (50,428) 36,779 Capital expenditures for segment assets $ 637,096 — 84,739 (84,739) 637,096 The summarized assets of the Company’s reportable segments are as follows (in thousands): As of December 31, 2022 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliate Total Investments in unconsolidated affiliates $ 220,429 — 652,767 (652,767) 220,429 Total assets 14,081,077 36,962 5,791,320 (5,791,320) 14,118,039 (Unaudited) As of June 30, 2023 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliate Total Investments in unconsolidated affiliates $ 218,196 — 639,887 (639,887) 218,196 Total assets 13,747,226 19,584 5,752,883 (5,752,883) 13,766,810 |
Subsidiary Guarantors
Subsidiary Guarantors | 6 Months Ended |
Jun. 30, 2023 | |
Subsidiary Guarantors | |
Subsidiary Guarantors | (17) Subsidiary Guarantors Antero Resources’ senior notes are fully and unconditionally guaranteed by Antero Resources’ existing subsidiaries that guarantee the Credit Facility. In the event a subsidiary guarantor is sold or disposed of (whether by merger, consolidation, the sale of a sufficient amount of its capital stock so that it no longer qualifies as a “Subsidiary” of Antero (as defined in the indentures governing the notes) or the sale of all or substantially all of its assets (other than by lease)) and whether or not the subsidiary guarantor is the surviving entity in such transaction to a person that is not Antero or a restricted subsidiary of Antero, such subsidiary guarantor will be released from its obligations under its subsidiary guarantee if the sale or other disposition does not violate the covenants set forth in the indentures governing the notes. In addition, a subsidiary guarantor will be released from its obligations under the indentures and its guarantee, upon the release or discharge of the guarantee of other Indebtedness (as defined in the indentures governing the notes) that resulted in the creation of such guarantee, except a release or discharge by or as a result of payment under such guarantee; if Antero designates such subsidiary as an unrestricted subsidiary and such designation complies with the other applicable provisions of the indentures governing the notes or in connection with any covenant defeasance, legal defeasance or satisfaction and discharge of the notes. The tables set forth below present summarized financial information of Antero, as parent, and its guarantor subsidiaries (in thousands). The Company Balance Sheet (Unaudited) December 31, 2022 June 30, 2023 Current assets $ 739,104 363,698 Noncurrent assets 12,663,911 12,775,341 Total assets $ 13,403,015 13,139,039 Accounts payable, related parties $ 80,708 95,360 Other current liabilities 1,668,426 1,398,840 Total current liabilities 1,749,134 1,494,200 Noncurrent liabilities 5,306,539 5,184,049 Total liabilities $ 7,055,673 6,678,249 Statement of Operations Six Months Ended June 30, 2023 Revenues $ 2,275,190 Operating expenses 2,095,558 Income from operations 179,632 Net income and comprehensive income including noncontrolling interests 130,347 Net income and comprehensive income attributable to Antero Resources Corporation $ 130,347 |
Summary of Significant Accoun_2
Summary of Significant Accounting Policies (Policies) | 6 Months Ended |
Jun. 30, 2023 | |
Summary of Significant Accounting Policies | |
Basis of Presentation | (a) Basis of Presentation These unaudited condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) applicable to interim financial information and should be read in the context of the Company’s December 31, 2022 consolidated financial statements and notes thereto for a more complete understanding of the Company’s operations, financial position and accounting policies. The Company’s December 31, 2022 consolidated financial statements were included in Antero Resources’ 2022 Annual Report on Form 10-K, which was filed with the SEC. These unaudited condensed consolidated financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim financial information, and, accordingly, do not include all of the information and footnotes required by GAAP for complete consolidated financial statements. In the opinion of management, these unaudited condensed consolidated financial statements include all adjustments (consisting of normal and recurring accruals) considered necessary to present fairly the Company’s financial position as of December 31, 2022 and June 30, 2023, results of operations for the three and six months ended June 30, 2022 and 2023 and cash flows for the six months ended June 30, 2022 and 2023. The Company has no items of other comprehensive income or loss; therefore, its net income or loss is equal to its comprehensive income or loss. Operating results for the period ended June 30, 2023 are not necessarily indicative of the results that may be expected for the full year because of the impact of fluctuations in prices received for natural gas, NGLs and oil, natural production declines, the uncertainty of exploration and development drilling results, fluctuations in the fair value of derivative instruments and other factors. |
Principles of Consolidation | (b) Principles of Consolidation The accompanying unaudited condensed consolidated financial statements include the accounts of Antero Resources Corporation, its wholly owned subsidiaries and its variable interest entity (“VIE”), Martica Holdings LLC, (“Martica”), for which the Company is the primary beneficiary. All significant intercompany accounts and transactions have been eliminated in the Company’s unaudited condensed consolidated financial statements. |
Cash and Cash Equivalents | (c) Cash and Cash Equivalents The Company considers all liquid investments purchased with an initial maturity of three months or less to be cash equivalents. The carrying value of cash and cash equivalents approximates fair value due to the short-term nature of these instruments. From time to time, the Company may be in the position of a “book overdraft” in which outstanding checks exceed cash and cash equivalents. The Company classifies book overdrafts in accounts payable and revenue distributions payable within its condensed consolidated balance sheets, and classifies the change in accounts payable associated with book overdrafts as an operating activity within its unaudited condensed consolidated statements of cash flows. As of December 31, 2022, the book overdrafts included within accounts payable and revenue distributions payable were million, respectively. As of June 30, 2023, the book overdrafts included within accounts payable and revenue distributions payable were |
Earnings (Loss) Per Common Share | (d) Income (Loss) Per Common Share Income (loss) per common share—basic for each period is computed by dividing net income (loss) attributable to Antero by the basic weighted average number of shares outstanding during the period. Income (loss) per common share—diluted for each period is computed after giving consideration to the potential dilution from (i) outstanding equity awards using the treasury stock method and (ii) shares of common stock issuable upon conversion of the 2026 Convertible Notes (as defined below in Note 7—Long-Term Debt) using the if-converted method. The Company includes restricted stock unit (“RSU”) awards, performance share unit (“PSU”) awards and stock options in the calculation of diluted weighted average shares outstanding based on the number of common shares that would be issuable if the end of the period was also the end of the performance period required for the vesting of the awards. During periods in which the Company incurs a net loss, diluted weighted average shares outstanding are equal to basic weighted average shares outstanding because the effects of all equity awards and the 2026 Convertible Notes are anti-dilutive. The following is a reconciliation of the Company’s income (loss) attributable to common stockholders for basic and diluted income (loss) per share (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2022 2023 2022 2023 Net income (loss) attributable to Antero Resources Corporation—common shareholders $ 765,135 (83,084) 608,716 130,347 Add: Interest expense for 2026 Convertible Notes 967 — 1,934 1,085 Less: Tax-effect of interest expense for 2026 Convertible Notes (224) — (449) (233) Net income (loss) attributable to Antero Resources Corporation—common shareholders and assumed conversions $ 765,878 (83,084) 610,201 131,199 Income (loss) per share—basic $ 2.46 (0.28) 1.95 0.44 Income (loss) per share—diluted $ 2.29 (0.28) 1.81 0.42 Weighted average common shares outstanding—basic 310,535 300,141 312,300 298,461 Weighted average common shares outstanding—diluted 334,561 300,141 337,589 311,488 The following is a reconciliation of the Company’s basic weighted average shares outstanding to diluted weighted average shares outstanding during the periods presented (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2022 2023 2022 2023 Basic weighted average number of shares outstanding 310,535 300,141 312,300 298,461 Add: Dilutive effect of RSUs 3,161 — 3,629 1,593 Add: Dilutive effect of PSUs 2,108 — 2,892 967 Add: Dilutive effect of 2026 Convertible Notes 18,757 — 18,768 10,467 Diluted weighted average number of shares outstanding 334,561 300,141 337,589 311,488 Weighted average number of outstanding securities excluded from calculation of diluted income (loss) per common share (1) RSUs — 4,070 — 2,260 PSUs — 1,791 — 377 Stock options 351 324 351 324 2026 Convertible Notes — 9,076 — — (1) The potential dilutive effects of these awards were excluded from the computation of income (loss) per common share—diluted because the inclusion of these awards would have been anti-dilutive. |
Recently Issued Accounting Standard | (e) Recently Issued Accounting Standard Convertible Debt Instruments In August 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2020-06, Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity Debt with Conversion and Other Options , that require separate accounting for conversion features, and instead, allows the debt instrument and conversion features to be accounted for as a single debt instrument. 2021. The Company adopted the standard effective January 1, 2022 Upon adoption of this new standard, the Company reclassified $24 million, net of deferred income taxes and equity issuance costs, from additional paid-in capital and increased long-term debt by $27 million, reduced deferred income tax liability by $6 million and reduced accumulated deficit by $3 million as of January 1, 2022. Additionally, annual interest expense for the 2026 Convertible Notes beginning January 1, 2022 is based on an effective interest rate of |
Summary of Significant Accoun_3
Summary of Significant Accounting Policies (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Summary of Significant Accounting Policies | |
Reconciliation of earnings (loss) attributable to common stockholders for basic and diluted earnings (loss) per share | The following is a reconciliation of the Company’s income (loss) attributable to common stockholders for basic and diluted income (loss) per share (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2022 2023 2022 2023 Net income (loss) attributable to Antero Resources Corporation—common shareholders $ 765,135 (83,084) 608,716 130,347 Add: Interest expense for 2026 Convertible Notes 967 — 1,934 1,085 Less: Tax-effect of interest expense for 2026 Convertible Notes (224) — (449) (233) Net income (loss) attributable to Antero Resources Corporation—common shareholders and assumed conversions $ 765,878 (83,084) 610,201 131,199 Income (loss) per share—basic $ 2.46 (0.28) 1.95 0.44 Income (loss) per share—diluted $ 2.29 (0.28) 1.81 0.42 Weighted average common shares outstanding—basic 310,535 300,141 312,300 298,461 Weighted average common shares outstanding—diluted 334,561 300,141 337,589 311,488 |
Reconciliation of basic weighted average shares outstanding to diluted weighted average shares outstanding | The following is a reconciliation of the Company’s basic weighted average shares outstanding to diluted weighted average shares outstanding during the periods presented (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2022 2023 2022 2023 Basic weighted average number of shares outstanding 310,535 300,141 312,300 298,461 Add: Dilutive effect of RSUs 3,161 — 3,629 1,593 Add: Dilutive effect of PSUs 2,108 — 2,892 967 Add: Dilutive effect of 2026 Convertible Notes 18,757 — 18,768 10,467 Diluted weighted average number of shares outstanding 334,561 300,141 337,589 311,488 Weighted average number of outstanding securities excluded from calculation of diluted income (loss) per common share (1) RSUs — 4,070 — 2,260 PSUs — 1,791 — 377 Stock options 351 324 351 324 2026 Convertible Notes — 9,076 — — (1) The potential dilutive effects of these awards were excluded from the computation of income (loss) per common share—diluted because the inclusion of these awards would have been anti-dilutive. |
Revenue (Tables)
Revenue (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Revenue | |
Schedule of disaggregation of revenue | The table set forth below presents revenue disaggregated by type and reportable segment to which it relates (in thousands). See Note 16—Reportable Segments to the unaudited condensed financial statements for more information on reportable segments. Three Months Ended June 30, Six Months Ended June 30, 2022 2023 2022 2023 Reportable Segment Revenues from contracts with customers: Natural gas sales $ 1,558,994 437,130 2,554,786 1,105,445 Exploration and production Natural gas liquids sales (ethane) 90,230 50,163 157,293 122,213 Exploration and production Natural gas liquids sales (C3+ NGLs) 612,158 347,570 1,205,400 770,955 Exploration and production Oil sales 89,185 57,962 152,479 109,773 Exploration and production Marketing 106,150 43,793 175,188 102,322 Marketing Other revenue — 365 — 540 Exploration and production Total revenue from contracts with customers 2,456,717 936,983 4,245,146 2,211,248 Income (loss) from derivatives, deferred revenue and other sources, net (255,032) 16,322 (1,256,621) 150,405 Total revenue $ 2,201,685 953,305 2,988,525 2,361,653 |
Equity Method Investment (Table
Equity Method Investment (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Antero Midstream Corporation | |
Equity Method Investments | |
Schedule of reconciliation of investments in unconsolidated affiliates and summarized financial information | The following table sets forth a reconciliation of Antero’s investment in unconsolidated affiliate (in thousands): Balance as of December 31, 2022 (1) $ 220,429 Equity in earnings of unconsolidated affiliate 36,779 Dividends from unconsolidated affiliate (62,569) Elimination of intercompany profit 23,557 Balance as of June 30, 2023 (1) $ 218,196 (1) The fair value of the Company’s investment in Antero Midstream as of December 31, 2022 and June 30, 2023 was $1.5 billion and $1.6 billion, respectively, based on the quoted market share price of Antero Midstream . |
Accrued Liabilities (Tables)
Accrued Liabilities (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Accrued Liabilities | |
Schedule of accrued liabilities | Accrued liabilities consisted of the following items (in thousands): (Unaudited) December 31, June 30, 2022 2023 Capital expenditures $ 57,361 51,364 Gathering, compression, processing and transportation expenses 162,783 159,685 Marketing expenses 61,118 30,823 Interest expense, net 31,892 32,454 Production and ad valorem taxes 32,536 55,073 General and administrative expense 32,477 24,558 Derivative settlements payable 53,732 183 Other 29,889 11,898 Total accrued liabilities $ 461,788 366,038 |
Long-Term Debt (Tables)
Long-Term Debt (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Long-Term Debt | |
Schedule of long-term debt | Long-term debt consisted of the following items (in thousands): (Unaudited) December 31, June 30, 2022 2023 Credit Facility (a) $ 34,800 359,900 8.375% senior notes due 2026 (c) 96,870 96,870 7.625% senior notes due 2029 (d) 407,115 407,115 5.375% senior notes due 2030 (e) 600,000 600,000 4.25% convertible senior notes due 2026 (f) 56,932 39,426 Total principal 1,195,717 1,503,311 Unamortized debt issuance costs (12,241) (11,041) Long-term debt $ 1,183,476 1,492,270 |
4.25% convertible senior notes due 2026 | |
Long-Term Debt | |
Schedule of long-term debt | The 2026 Convertible Notes consist of the following (in thousands): (Unaudited) December 31, June 30, 2022 2023 Principal $ 56,932 39,426 Less: unamortized debt issuance costs (1,159) (702) Net carrying value $ 55,773 38,724 |
Asset Retirement Obligations (T
Asset Retirement Obligations (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Asset Retirement Obligations | |
Schedule of reconciliation of asset retirement obligations | The following table presents a reconciliation of the Company’s asset retirement obligations (in thousands): Asset retirement obligations—December 31, 2022 $ 59,485 Obligations incurred 561 Accretion expense 2,082 Settlement of obligations (633) Revisions to prior estimates 301 Asset retirement obligations—June 30, 2023 $ 61,796 |
Equity-Based Compensation and_2
Equity-Based Compensation and Cash Awards (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Equity-Based Compensation and Cash Awards | |
Schedule of equity-based compensation expense | The Company’s equity-based compensation expense, by type of award, is as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2022 2023 2022 2023 RSU awards $ 4,774 8,720 7,494 15,982 PSU awards 3,012 4,442 4,431 9,847 Converted AM RSU Awards (1) 35 — 195 1 Equity awards issued to directors 350 350 700 700 Total expense $ 8,171 13,512 12,820 26,530 (1) Antero Resources recognized compensation expense for equity awards granted under both the 2013 Plan and the AMP Plan because the awards under the AMP Plan are accounted for as if they are distributed by Antero Midstream Partners to Antero Resources. Antero Resources allocates a portion of equity-based compensation expense related to grants prior to March 12, 2019 (date of deconsolidation) to Antero Midstream Partners based on its proportionate share of Antero Resources’ labor costs. As of June 30, 2023, all Converted AM RSU Awards were fully vested, and there is no remaining unamortized expense attributable to these awards. |
Summary of RSU award activity | Weighted Average Number of Grant Date Shares Fair Value Total awarded and unvested—December 31, 2022 4,676,219 $ 15.29 Granted 1,458,594 25.87 Vested (2,202,895) 9.02 Forfeited (69,321) 22.57 Total awarded and unvested—June 30, 2023 3,862,597 $ 22.74 |
Schedule of weighted average fair value assumptions used for PSUs granted | Dividend yield — % Volatility 82 % Risk-free interest rate 4.61 % Weighted average fair value of awards granted—Absolute TSR $ 33.96 |
Summary of PSU award activity | Weighted Average Number of Grant Date Units Fair Value Total awarded and unvested—December 31, 2022 1,329,725 $ 23.18 Granted 417,466 28.51 Vested (1) (335,000) 2.97 Total awarded and unvested—June 30, 2023 1,412,191 $ 29.54 |
Schedule of Converted AM RSU Awards | Weighted Average Number of Grant Date Units Fair Value Total awarded and unvested—December 31, 2022 2,827 $ 12.38 Vested (2,827) 12.38 Total awarded and unvested—June 30, 2023 — $ — |
Fair value (Tables)
Fair value (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Fair Value. | |
Schedule of fair value and carrying value of the senior notes and 2026 Convertible Notes | The following table sets forth the fair value and carrying value of the senior notes and 2026 Convertible Notes (in thousands): (Unaudited) December 31, 2022 June 30, 2023 Fair Carrying Fair Carrying Value (1) Value (2) Value (1) Value (2) 2026 Notes $ 100,987 96,123 100,076 96,235 2029 Notes 410,860 402,872 412,204 403,151 2030 Notes 556,260 593,908 548,220 594,260 2026 Convertible Notes 406,039 55,773 208,414 38,724 Total $ 1,474,146 1,148,676 1,268,914 1,132,370 (1) Fair values are based on Level 2 market data inputs. (2) Carrying values are presented net of unamortized debt issuance costs and debt discounts or premiums. |
Derivative Instruments (Tables)
Derivative Instruments (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Schedule of outstanding commodity derivatives for Antero Resources Corporation | Weighted Average Commodity / Settlement Period Index Contracted Volume Price Natural Gas July-December 2023 Henry Hub 43,000 MMBtu/day $ 2.37 /MMBtu |
Schedule of call option and embedded put option arrangements | Embedded Call Option Put Option Commodity / Settlement Period Index Contracted Volume Strike Price Strike Price Natural Gas July-December 2023 Henry Hub 55,000 MMBtu/day $ 2.466 /MMBtu $ 2.466 /MMBtu January-December 2024 Henry Hub 53,000 MMBtu/day 2.477 /MMBtu 2.527 /MMBtu January-December 2025 Henry Hub 44,000 MMBtu/day 2.564 /MMBtu 2.614 /MMBtu January-December 2026 Henry Hub 32,000 MMBtu/day 2.629 /MMBtu 2.679 /MMBtu |
Schedule of natural gas basis swap positions which settle on pricing index to basis differential of NYMEX to TCO | Weighted Average Commodity / Settlement Period Index to Basis Differential Contracted Volume Hedged Differential Natural Gas July-December 2023 NYMEX to TCO 50,000 MMBtu/day $ 0.525 /MMBtu January-December 2024 NYMEX to TCO 50,000 MMBtu/day 0.530 /MMBtu |
Summary of the fair values of derivative instruments, which are not designated as hedges for accounting purposes | (Unaudited) Balance Sheet December 31, June 30, Location 2022 2023 Asset derivatives not designated as hedges for accounting purposes: Embedded derivatives—current Derivative instruments 1,900 3,099 Embedded derivatives—noncurrent Derivative instruments 9,844 7,934 Total asset derivatives (1) 11,744 11,033 Liability derivatives not designated as hedges for accounting purposes: Commodity derivatives—current (2) Derivative instruments 97,765 35,509 Commodity derivatives—noncurrent (2) Derivative instruments 345,280 59,224 Total liability derivatives (1) 443,045 94,733 Net derivatives liability (1) $ (431,301) (83,700) (1) The fair value of derivative instruments was determined using Level 2 inputs. (2) As of December 31, 2022, $47 million of commodity derivative liabilities, including $28 million of current commodity derivatives and $19 million of noncurrent commodity derivatives, are attributable to the Company’s consolidated VIE, Martica. As of June 30, 2023, $17 million of commodity derivative liabilities, including $10 million of current commodity derivatives and $7 million of noncurrent commodity derivatives, are attributable to the Company’s consolidated VIE, Martica. |
Schedule of gross amounts of recognized derivative assets and liabilities, the amounts offset under netting arrangements with counterparties, and the resulting net amounts | The following table sets forth the gross values of recognized derivative assets and liabilities, the amounts offset under master netting arrangements with counterparties, and the resulting net amounts presented in the condensed consolidated balance sheets as of the dates presented, all at fair value (in thousands): (Unaudited) December 31, 2022 June 30, 2023 Net Amounts of Net Amounts of Gross Gross Assets Gross Gross Assets Amounts Amounts Offset (Liabilities) on Amounts Amounts Offset (Liabilities) on Recognized Recognized Balance Sheet Recognized Recognized Balance Sheet Commodity derivative assets $ 276 (276) — $ 422 (422) — Embedded derivative assets 11,744 — 11,744 11,033 — 11,033 Commodity derivative liabilities (443,321) 276 (443,045) (95,155) 422 (94,733) |
Summary of derivative fair value gains (losses) | The following table sets forth a summary of derivative fair value gains and losses and where such values are recorded in the unaudited condensed consolidated statements of operations (in thousands): Statement of Operations Three Months Ended June 30, Six Months Ended June 30, Location 2022 2023 2022 2023 Commodity derivative fair value gains (losses) (1) Revenue $ (237,680) 6,232 (1,232,163) 133,312 Embedded derivative fair value gains (losses) (1) Revenue $ (27,982) 2,052 (44,879) 1,164 (1) The fair value of derivative instruments was determined using Level 2 inputs . |
VIE, Martica | |
Schedule of outstanding commodity derivatives | Weighted Average Commodity / Settlement Period Index Contracted Volume Price Natural Gas July-December 2023 Henry Hub 32,496 MMBtu/day $ 2.35 /MMBtu January-December 2024 Henry Hub 23,885 MMBtu/day 2.33 /MMBtu January-March 2025 Henry Hub 18,021 MMBtu/day 2.53 /MMBtu Natural Gasoline July-December 2023 Mont Belvieu Natural Gasoline-OPIS Non-TET 227 Bbl/day 40.74 /Bbl Oil July-December 2023 West Texas Intermediate 77 Bbl/day 44.72 /Bbl January-December 2024 West Texas Intermediate 43 Bbl/day 44.02 /Bbl January-March 2025 West Texas Intermediate 39 Bbl/day 45.06 /Bbl |
Leases (Tables)
Leases (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Leases | |
Summary of supplemental balance sheet information related to leases | The Company’s lease assets and liabilities consisted of the following items (in thousands): (Unaudited) December 31, June 30, Leases Balance Sheet Classification 2022 2023 Operating Leases Operating lease right-of-use assets: Processing plants Operating lease right-of-use assets $ 1,849,116 1,732,132 Drilling rigs and completion services Operating lease right-of-use assets 85,405 52,094 Gas gathering lines and compressor stations (1) Operating lease right-of-use assets 1,463,756 1,435,070 Office space Operating lease right-of-use assets 41,822 39,777 Vehicles Operating lease right-of-use assets 756 109 Other office and field equipment Operating lease right-of-use assets 3,476 3,071 Total operating lease right-of-use assets $ 3,444,331 3,262,253 Operating lease liabilities: Short-term operating lease liabilities Short-term lease liabilities $ 556,137 553,107 Long-term operating lease liabilities Long-term lease liabilities 2,888,194 2,709,146 Total operating lease liabilities $ 3,444,331 3,262,253 Finance Leases Finance lease right-of-use assets: Vehicles Other property and equipment $ 2,159 3,435 Total finance lease right-of-use assets (2) $ 2,159 3,435 Finance lease liabilities: Short-term finance lease liabilities Short-term lease liabilities $ 499 846 Long-term finance lease liabilities Long-term lease liabilities 1,660 2,589 Total finance lease liabilities $ 2,159 3,435 (1) Gas gathering lines and compressor stations includes $1.4 billion related to Antero Midstream as of December 31, 2022 and June 30, 2023. See “—Related party lease disclosure” for additional discussion. (2) Financing lease assets are recorded net of accumulated amortization of $1 million as of December 31, 2022 and June 30, 2023 . |
Summary of costs associated with operating leases and finance leases | Costs associated with operating and finance leases were included in the unaudited condensed consolidated statement of operations and comprehensive loss (in thousands): Three Months Ended June 30, Six Months Ended June 30, Cost Classification Location 2022 2023 2022 2023 Operating lease cost Statement of operations Gathering, compression, processing and transportation $ 365,343 407,445 731,177 788,728 Operating lease cost Statement of operations General and administrative 2,787 3,030 5,654 5,967 Operating lease cost Statement of operations Contract termination — 2,808 — 3,930 Operating lease cost Statement of operations Lease operating 44 21 89 42 Operating lease cost Balance sheet Proved properties (1) 41,100 31,602 48,859 71,372 Total operating lease cost $ 409,274 444,906 785,779 870,039 Finance lease cost: Amortization of right-of-use assets Statement of operations Depletion, depreciation and amortization $ 107 546 225 638 Interest on lease liabilities Statement of operations Interest expense 51 162 65 276 Total finance lease cost $ 158 708 290 914 Short-term lease payments $ 28,348 34,707 77,108 72,408 (1) Capitalized costs related to drilling and completion activities. |
Summary of supplemental cash flow information related to leases | The following table presents the Company’s supplemental cash flow information related to leases (in thousands): Six Months Ended June 30, 2022 2023 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 675,563 654,938 Operating cash flows from finance leases 66 276 Investing cash flows from operating leases 39,781 61,092 Financing cash flows from finance leases 277 343 Noncash activities: Right-of-use assets obtained in exchange for new operating lease obligations $ 215,157 51,737 Increase (decrease) to existing right-of-use assets and lease obligations from operating lease modifications, net (1) $ (47,728) 40,176 (1) During the six months ended June 30, 2022, the weighted average discount rate for remeasured operating leases increased from 4.5% as of December 31, 2021 to 5.1% as of June 30, 2022. During the six months ended June 30, 2023, the weighted average discount rate for remeasured operating leases increased from 5.2% as of December 31, 2022 to 5.8% as of June 30, 2023. |
Summary of maturities of operating lease liabilities | The table below is a schedule of future minimum payments for operating and financing lease liabilities as of June 30, 2023 (in thousands): Operating Leases Financing Leases Total 2023 $ 374,215 669 374,884 2024 685,594 1,339 686,933 2025 609,747 1,297 611,044 2026 556,196 961 557,157 2027 457,972 112 458,084 Thereafter 1,252,713 33 1,252,746 Total lease payments 3,936,437 4,411 3,940,848 Less: imputed interest (674,184) (976) (675,160) Total $ 3,262,253 3,435 3,265,688 |
Summary of maturities of financing lease liabilities | The table below is a schedule of future minimum payments for operating and financing lease liabilities as of June 30, 2023 (in thousands): Operating Leases Financing Leases Total 2023 $ 374,215 669 374,884 2024 685,594 1,339 686,933 2025 609,747 1,297 611,044 2026 556,196 961 557,157 2027 457,972 112 458,084 Thereafter 1,252,713 33 1,252,746 Total lease payments 3,936,437 4,411 3,940,848 Less: imputed interest (674,184) (976) (675,160) Total $ 3,262,253 3,435 3,265,688 |
Summary of weighted-average remaining lease term and discount rate | December 31, 2022 June 30, 2023 Operating Leases Finance Leases Operating Leases Finance Leases Weighted average remaining lease term 7.2 years 3.5 years 6.9 years 3.4 years Weighted average discount rate 5.3 % 7.4 % 5.6 % 8.1 % |
Commitments (Tables)
Commitments (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Commitments | |
Schedule of future minimum payments which include leases that have remaining lease terms in excess of one year | The following table sets forth a schedule of future minimum payments for the Company’s contractual obligations, which include leases that have a lease term in excess of one year as of June 30, 2023 (in thousands): Processing, Gathering, Firm Compression Operating and Imputed Interest Transportation and Water Service Financing Leases for Leases Other (a) (b) (c) (c) (d) Total Remainder of 2023 $ 594,682 35,382 286,449 88,435 2,586 1,007,534 2024 1,147,772 63,212 533,031 153,902 6,009 1,903,926 2025 1,134,296 51,865 486,261 124,783 4,875 1,802,080 2026 1,131,882 18,688 459,146 98,011 2,250 1,709,977 2027 1,127,234 17,400 384,429 73,655 — 1,602,718 Thereafter 5,444,784 80,556 1,116,372 136,374 — 6,778,086 Total $ 10,580,650 267,103 3,265,688 675,160 15,720 14,804,321 |
Reportable Segments (Tables)
Reportable Segments (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Reportable Segments | |
Schedule of operating results and assets of reportable segments | The operating results and assets of the Company’s reportable segments were as follows (in thousands): Three Months Ended June 30, 2022 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliate Total Sales and revenues: Third-party $ 2,095,144 106,150 242 (242) 2,201,294 Intersegment 391 — 228,665 (228,665) 391 Total revenue 2,095,535 106,150 228,907 (228,907) 2,201,685 Operating expenses: Lease operating 25,253 — — — 25,253 Gathering, compression, processing, transportation and water handling 656,212 — 43,299 (43,299) 656,212 General and administrative 44,439 — 16,079 (16,079) 44,439 Depletion, depreciation and amortization 173,395 — 35,675 (35,675) 173,395 Impairment of property and equipment 23,363 — 3,702 (3,702) 23,363 Other 86,207 131,298 1,756 (1,756) 217,505 Total operating expenses 1,008,869 131,298 100,511 (100,511) 1,140,167 Operating income (loss) $ 1,086,666 (25,148) 128,396 (128,396) 1,061,518 Equity in earnings of unconsolidated affiliates $ 14,713 — 22,824 (22,824) 14,713 Capital expenditures for segment assets $ 260,864 — 77,767 (77,767) 260,864 Three Months Ended June 30, 2023 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliate Total Sales and revenues: Third-party $ 909,092 43,793 274 (274) 952,885 Intersegment 420 — 258,013 (258,013) 420 Total revenue 909,512 43,793 258,287 (258,287) 953,305 Operating expenses: Lease operating 28,748 — — — 28,748 Gathering, compression, processing, transportation and water handling 663,975 — 52,595 (52,595) 663,975 General and administrative 53,901 — 18,162 (18,162) 53,901 Depletion, depreciation and amortization 171,406 — 35,233 (35,233) 171,406 Impairment of property and equipment 15,710 — — — 15,710 Other 42,326 66,175 6,774 (6,774) 108,501 Total operating expenses 976,066 66,175 112,764 (112,764) 1,042,241 Operating income (loss) $ (66,554) (22,382) 145,523 (145,523) (88,936) Equity in earnings of unconsolidated affiliates $ 19,098 — 25,972 (25,972) 19,098 Capital expenditures for segment assets $ 637,096 — 41,782 (41,782) 637,096 Six Months Ended June 30, 2022 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliate Total Sales and revenues: Third-party $ 2,812,525 175,188 637 (637) 2,987,713 Intersegment 812 — 446,761 (446,761) 812 Total revenue 2,813,337 175,188 447,398 (447,398) 2,988,525 Operating expenses: Lease operating 43,033 — — — 43,033 Gathering, compression, processing, transportation and water handling 1,246,490 — 85,311 (85,311) 1,246,490 General and administrative 80,130 — 34,010 (34,010) 80,130 Depletion, depreciation and amortization 341,783 — 63,975 (63,975) 341,783 Impairment of property and equipment 45,825 — 3,702 (3,702) 45,825 Other 144,151 230,194 2,850 (2,850) 374,345 Total operating expenses 1,901,412 230,194 189,848 (189,848) 2,131,606 Operating income (loss) $ 911,925 (55,006) 257,550 (257,550) 856,919 Equity in earnings of unconsolidated affiliates $ 39,891 — 46,056 (46,056) 39,891 Capital expenditures for segment assets $ 476,740 — 162,034 (162,034) 476,740 Six Months Ended June 30, 2023 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliate Total Sales and revenues: Third-party $ 2,258,568 102,322 546 (546) 2,360,890 Intersegment 763 — 517,216 (517,216) 763 Total revenue 2,259,331 102,322 517,762 (517,762) 2,361,653 Operating expenses: Lease operating 58,069 — — — 58,069 Gathering, compression, processing, transportation and water handling 1,309,147 — 110,468 (110,468) 1,309,147 General and administrative 111,162 — 35,509 (35,509) 111,162 Depletion, depreciation and amortization 338,988 — 70,429 (70,429) 338,988 Impairment of property and equipment 31,270 — — — 31,270 Other 99,164 171,299 7,488 (7,488) 270,463 Total operating expenses 1,947,800 171,299 223,894 (223,894) 2,119,099 Operating income (loss) $ 311,531 (68,977) 293,868 (293,868) 242,554 Equity in earnings of unconsolidated affiliates $ 36,779 — 50,428 (50,428) 36,779 Capital expenditures for segment assets $ 637,096 — 84,739 (84,739) 637,096 The summarized assets of the Company’s reportable segments are as follows (in thousands): As of December 31, 2022 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliate Total Investments in unconsolidated affiliates $ 220,429 — 652,767 (652,767) 220,429 Total assets 14,081,077 36,962 5,791,320 (5,791,320) 14,118,039 (Unaudited) As of June 30, 2023 Equity Method Exploration Investment in Elimination of and Antero Unconsolidated Consolidated Production Marketing Midstream Affiliate Total Investments in unconsolidated affiliates $ 218,196 — 639,887 (639,887) 218,196 Total assets 13,747,226 19,584 5,752,883 (5,752,883) 13,766,810 |
Subsidiary Guarantors (Tables)
Subsidiary Guarantors (Tables) | 6 Months Ended |
Jun. 30, 2023 | |
Subsidiary Guarantors | |
Schedule of summarized financial information of Antero and its guarantor subsidiaries | The tables set forth below present summarized financial information of Antero, as parent, and its guarantor subsidiaries (in thousands). The Company Balance Sheet (Unaudited) December 31, 2022 June 30, 2023 Current assets $ 739,104 363,698 Noncurrent assets 12,663,911 12,775,341 Total assets $ 13,403,015 13,139,039 Accounts payable, related parties $ 80,708 95,360 Other current liabilities 1,668,426 1,398,840 Total current liabilities 1,749,134 1,494,200 Noncurrent liabilities 5,306,539 5,184,049 Total liabilities $ 7,055,673 6,678,249 Statement of Operations Six Months Ended June 30, 2023 Revenues $ 2,275,190 Operating expenses 2,095,558 Income from operations 179,632 Net income and comprehensive income including noncontrolling interests 130,347 Net income and comprehensive income attributable to Antero Resources Corporation $ 130,347 |
Summary of Significant Accoun_4
Summary of Significant Accounting Policies - Cash and Cash Equivalents (Details) - USD ($) $ in Millions | Jun. 30, 2023 | Dec. 31, 2022 |
Accounts Payable | ||
Basis of Presentation | ||
Book overdrafts | $ 33 | $ 28 |
Revenue distributions payable | ||
Basis of Presentation | ||
Book overdrafts | $ 16 | $ 43 |
Summary of Significant Accoun_5
Summary of Significant Accounting Policies - Reconciliation of Earnings (Loss) Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2023 | Jun. 30, 2022 | Jun. 30, 2023 | Sep. 30, 2022 | Jun. 30, 2022 | |
Summary of Significant Accounting Policies | |||||
Net income (loss) attributable to Antero Resources Corporation-common shareholders | $ (83,084) | $ 765,135 | $ 130,347 | $ 608,716 | |
Add: Interest expense for 2026 Convertible Notes | 967 | 1,085 | 1,934 | ||
Less: Tax-effect of interest expense for 2026 Convertible Notes | (224) | (233) | (449) | ||
Net income (loss) attributable to Antero Resources Corporation-common shareholders and assumed conversions | $ (83,084) | $ 765,878 | $ 131,199 | $ 610,201 | |
Income (loss) per share-basic (in dollars per share) | $ (0.28) | $ 2.46 | $ 0.44 | $ 1.95 | |
Income (loss) per share-diluted (in dollars per share) | $ (0.28) | $ 2.29 | $ 0.42 | $ 1.81 | |
Weighted average common shares outstanding-basic (in shares) | 300,141 | 310,535 | 298,461 | 312,300 | 312,300 |
Weighted average common shares outstanding-diluted (in shares) | 300,141 | 334,561 | 311,488 | 337,589 | 337,589 |
Summary of Significant Accoun_6
Summary of Significant Accounting Policies - Reconciliation of Weighted Average Shares Outstanding (Details) - shares shares in Thousands | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2023 | Jun. 30, 2022 | Jun. 30, 2023 | Sep. 30, 2022 | Jun. 30, 2022 | |
Income (loss) per common share | |||||
Basic weighted average number of shares outstanding | 300,141 | 310,535 | 298,461 | 312,300 | 312,300 |
Diluted weighted average number of shares outstanding | 300,141 | 334,561 | 311,488 | 337,589 | 337,589 |
RSUs | |||||
Income (loss) per common share | |||||
Add: Dilutive effect | 3,161 | 1,593 | 3,629 | ||
Weighted average number of outstanding securities excluded from calculation of diluted income (loss) per common share | 4,070 | 2,260 | |||
PSUs | |||||
Income (loss) per common share | |||||
Add: Dilutive effect | 2,108 | 967 | 2,892 | ||
Weighted average number of outstanding securities excluded from calculation of diluted income (loss) per common share | 1,791 | 377 | |||
Stock options | |||||
Income (loss) per common share | |||||
Weighted average number of outstanding securities excluded from calculation of diluted income (loss) per common share | 324 | 351 | 324 | 351 | |
4.25% convertible senior notes due 2026 | |||||
Income (loss) per common share | |||||
Add: Dilutive effect | 18,757 | 10,467 | 18,768 | ||
Weighted average number of outstanding securities excluded from calculation of diluted income (loss) per common share | 9,076 |
Summary of Significant Accoun_7
Summary of Significant Accounting Policies - Recently Issued Accounting Standards (Details) - USD ($) $ in Thousands | Jun. 30, 2023 | Jan. 01, 2023 | Dec. 31, 2022 | Jan. 01, 2022 | Dec. 31, 2021 | Aug. 21, 2020 |
Recently Issued Accounting Standards | ||||||
Additional paid-in capital | $ 5,803,634 | $ 5,838,848 | ||||
Long-term debt | 1,492,270 | 1,183,476 | ||||
Deferred income tax liability, net | 792,149 | 759,861 | ||||
Retained earnings | 1,019,256 | 913,896 | ||||
4.25% convertible senior notes due 2026 | ||||||
Recently Issued Accounting Standards | ||||||
Long-term debt | $ 38,724 | $ 55,773 | ||||
Effective interest rate (as a percent) | 15.10% | 15.10% | ||||
Accounting Standards Update 2020-06 | Adjustment Effect | ||||||
Recently Issued Accounting Standards | ||||||
Additional paid-in capital | $ (24,000) | |||||
Long-term debt | 27,000 | |||||
Deferred income tax liability, net | (6,000) | |||||
Retained earnings | $ 3,000 | |||||
Accounting Standards Update 2020-06 | Adjustment Effect | 4.25% convertible senior notes due 2026 | ||||||
Recently Issued Accounting Standards | ||||||
Effective interest rate (as a percent) | 4.90% |
Transactions (Details)
Transactions (Details) ft in Thousands, $ in Millions | 6 Months Ended | 12 Months Ended | |||||
Apr. 01, 2023 ft | Jun. 15, 2020 ft | Jun. 30, 2023 USD ($) | Jun. 30, 2022 USD ($) | Dec. 31, 2022 USD ($) | Mar. 31, 2023 | Feb. 17, 2021 | |
Transactions | |||||||
Portion of Incremental Override that may be re-conveyed to the Company | 76% | ||||||
Portion of Incremental Override that must remain with Martica | 24% | ||||||
ORRI | |||||||
Transactions | |||||||
Initial PDP Override (as a percent) | 1.25% | ||||||
Development Override (as a percent) | 3.75% | ||||||
Horizontal wells turned to sales, threshold one (in lateral feet) | 2,200 | ||||||
Horizontal wells turned to sales, threshold two (in lateral feet) | 3,820 | ||||||
Incremental override (percentage) | 2% | ||||||
Percentage of distributions received | 85% | ||||||
Percentage of distributions received on Incremental Override | 76% | ||||||
ORRI | Minimum | |||||||
Transactions | |||||||
Horizontal wells turned to sales | 2,200 | ||||||
ORRI | Maximum | |||||||
Transactions | |||||||
Horizontal wells turned to sales | 3,820 | ||||||
ORRI | Sixth Street | |||||||
Transactions | |||||||
Internal rate of return threshold | 13% | ||||||
Cash on cash return threshold | 150% | ||||||
Percentage of distributions received on Incremental Override | 24% | ||||||
Drilling Partnership | QL | |||||||
Transactions | |||||||
Cash contribution | $ | $ 29 | ||||||
Percent of total development capital spending in current year funded by drilling partner | 20% | ||||||
Percent of total development capital spending in the next year to be funded by drilling partner | 15% | ||||||
Percent of total development capital spending in year two to be funded by drilling partner | 15% | ||||||
Gain (loss) on interests conveyed | $ | $ 0 | $ 0 | |||||
Drilling Partnership | QL | Minimum | |||||||
Transactions | |||||||
Percent of total development capital spending in year three to be funded by drilling partner | 15% | ||||||
Drilling Partnership | QL | Maximum | |||||||
Transactions | |||||||
Percent of total development capital spending in year three to be funded by drilling partner | 20% |
Revenue (Details)
Revenue (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2023 | Jun. 30, 2022 | Jun. 30, 2023 | Jun. 30, 2022 | |
Disaggregation of Revenue | ||||
Revenue | $ 936,983 | $ 2,456,717 | $ 2,211,248 | $ 4,245,146 |
Income (loss) from derivatives, deferred revenue and other sources | 16,322 | (255,032) | 150,405 | (1,256,621) |
Total revenue | 953,305 | 2,201,685 | 2,361,653 | 2,988,525 |
Natural gas sales | ||||
Disaggregation of Revenue | ||||
Total revenue | 437,130 | 1,558,994 | 1,105,445 | 2,554,786 |
Oil sales | ||||
Disaggregation of Revenue | ||||
Total revenue | 57,962 | 89,185 | 109,773 | 152,479 |
Marketing | ||||
Disaggregation of Revenue | ||||
Total revenue | 43,793 | 106,150 | 102,322 | 175,188 |
Exploration and production | Natural gas sales | ||||
Disaggregation of Revenue | ||||
Revenue | 437,130 | 1,558,994 | 1,105,445 | 2,554,786 |
Exploration and production | Natural gas liquids sales (ethane) | ||||
Disaggregation of Revenue | ||||
Revenue | 50,163 | 90,230 | 122,213 | 157,293 |
Exploration and production | Natural gas liquids sales (C3+ NGLs) | ||||
Disaggregation of Revenue | ||||
Revenue | 347,570 | 612,158 | 770,955 | 1,205,400 |
Exploration and production | Oil sales | ||||
Disaggregation of Revenue | ||||
Revenue | 57,962 | 89,185 | 109,773 | 152,479 |
Exploration and production | Other | ||||
Disaggregation of Revenue | ||||
Revenue | 365 | 540 | ||
Marketing | Marketing | ||||
Disaggregation of Revenue | ||||
Revenue | $ 43,793 | $ 106,150 | $ 102,322 | $ 175,188 |
Revenue - Transaction Price All
Revenue - Transaction Price Allocation and Contract Balances (Details) - USD ($) $ in Thousands | 6 Months Ended | |
Jun. 30, 2023 | Dec. 31, 2022 | |
Revenue | ||
Original expected duration | true | |
Receivables from contracts with customers | $ 323,440 | $ 707,685 |
Equity Method Investment (Detai
Equity Method Investment (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2023 | Jun. 30, 2022 | Jun. 30, 2023 | Jun. 30, 2022 | Dec. 31, 2022 | |
Investments in unconsolidated affiliates | |||||
Equity in earnings of unconsolidated affiliate | $ 19,098 | $ 14,713 | $ 36,779 | $ 39,891 | |
Dividends from unconsolidated affiliate | $ (62,569) | $ (62,569) | |||
Antero Midstream Corporation | |||||
Equity Method Investments | |||||
Ownership percentage | 29% | 29% | |||
Investments in unconsolidated affiliates | |||||
Balance at beginning of period | $ 220,429 | ||||
Equity in earnings of unconsolidated affiliate | 36,779 | ||||
Dividends from unconsolidated affiliate | (62,569) | ||||
Elimination of intercompany profit | 23,557 | ||||
Balance at end of period | $ 218,196 | 218,196 | |||
Fair value of investment | $ 1,600,000 | $ 1,600,000 | $ 1,500,000 |
Accrued Liabilities (Details)
Accrued Liabilities (Details) - USD ($) $ in Thousands | Jun. 30, 2023 | Dec. 31, 2022 |
Accrued Liabilities | ||
Capital expenditures | $ 51,364 | $ 57,361 |
Gathering, compression, processing, and transportation expenses | 159,685 | 162,783 |
Marketing expenses | 30,823 | 61,118 |
Interest expense, net | 32,454 | 31,892 |
Production and ad valorem taxes | 55,073 | 32,536 |
General and administrative expense | 24,558 | 32,477 |
Derivative settlements payable | 183 | 53,732 |
Other | 11,898 | 29,889 |
Total accrued liabilities | $ 366,038 | $ 461,788 |
Long-Term Debt (Details)
Long-Term Debt (Details) $ in Thousands, shares in Millions | 1 Months Ended | 3 Months Ended | 6 Months Ended | 12 Months Ended | 18 Months Ended | |||||||||||
Jun. 01, 2021 USD ($) | Jan. 26, 2021 USD ($) | Jan. 04, 2021 USD ($) | Aug. 21, 2020 USD ($) D | Sep. 02, 2020 USD ($) | Jun. 30, 2023 USD ($) | Mar. 31, 2023 USD ($) | Jun. 30, 2022 USD ($) | Mar. 31, 2022 USD ($) | Jun. 30, 2023 USD ($) shares | Jun. 30, 2022 USD ($) | Dec. 31, 2021 USD ($) | Jun. 30, 2023 USD ($) | Dec. 31, 2022 USD ($) | Oct. 18, 2021 USD ($) | Dec. 21, 2016 USD ($) | |
Long-Term Debt | ||||||||||||||||
Total principal | $ 1,503,311 | $ 1,503,311 | $ 1,503,311 | $ 1,195,717 | ||||||||||||
Unamortized debt issuance costs | (11,041) | (11,041) | (11,041) | (12,241) | ||||||||||||
Long-term debt | 1,492,270 | 1,492,270 | 1,492,270 | 1,183,476 | ||||||||||||
Amount of debt repurchased | 0 | $ 0 | 0 | 0 | ||||||||||||
Aggregate principal amount converted | $ 17,172 | $ 3,964 | ||||||||||||||
Loss on convertible note equitizations | 86 | |||||||||||||||
Gain (loss) on extinguishment of debt repurchased | (4,414) | $ (15,068) | ||||||||||||||
Credit Facility | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Credit facility | 359,900 | 359,900 | 359,900 | 34,800 | ||||||||||||
Current borrowing base | 3,500,000 | 3,500,000 | 3,500,000 | 3,500,000 | ||||||||||||
Lender commitments | 1,500,000 | $ 1,500,000 | 1,500,000 | 1,500,000 | ||||||||||||
Debt maturity threshold days | 180 days | |||||||||||||||
Available borrowing capacity | 638,000 | $ 638,000 | 638,000 | |||||||||||||
Outstanding letters of credit | $ 502,000 | $ 502,000 | $ 502,000 | $ 504,000 | ||||||||||||
Weighted average interest rate (as a percent) | 7.44% | 7.44% | 7.44% | 6.42% | ||||||||||||
Credit Facility | Minimum | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Commitment fees on the unused portion during any period that is not an Investment Grade Period (as a percent) | 0.375% | |||||||||||||||
Credit Facility | Maximum | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Commitment fees on the unused portion during any period that is not an Investment Grade Period (as a percent) | 0.50% | |||||||||||||||
5.00% senior notes due 2025 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Senior notes | $ 600,000 | |||||||||||||||
Interest rate (as a percent) | 5% | |||||||||||||||
Issue price as percentage of par value | 100% | |||||||||||||||
5.00% senior notes due 2025 | Debt Repurchase Program | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Amount of debt repurchased | $ 585,000 | |||||||||||||||
Gain (loss) on extinguishment of debt repurchased | $ (11,000) | |||||||||||||||
Percentage of redeemed amount | 101.25% | |||||||||||||||
8.375% Senior Notes Due 2026 and 7.625% Senior Notes Due 2029 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Gain (loss) on extinguishment of debt repurchased | $ 4,000 | |||||||||||||||
Weighted average percentage premium on repurchases of debt | 106% | |||||||||||||||
8.375% Senior Notes Due 2026 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Senior notes | $ 500,000 | $ 96,870 | $ 96,870 | $ 96,870 | $ 96,870 | |||||||||||
Interest rate (as a percent) | 8.375% | 8.375% | 8.375% | 8.375% | 8.375% | |||||||||||
Issue price as percentage of par value | 100% | |||||||||||||||
Redemption price of the debt instrument in the event of change of control (as a percent) | 101% | |||||||||||||||
Amount of debt repurchased | $ 13,000 | 13,000 | $ 403,000 | |||||||||||||
8.375% Senior Notes Due 2026 | On or after January 15, 2024 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Redemption price | 104.188% | |||||||||||||||
8.375% Senior Notes Due 2026 | On or after January 15, 2026 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Redemption price | 100% | |||||||||||||||
8.375% Senior Notes Due 2026 | Prior to January 15, 2024 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Redemption price | 100% | |||||||||||||||
7.625% Senior Notes Due 2029 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Senior notes | $ 700,000 | $ 407,115 | $ 407,115 | $ 407,115 | $ 407,115 | |||||||||||
Interest rate (as a percent) | 7.625% | 7.625% | 7.625% | 7.625% | 7.625% | |||||||||||
Issue price as percentage of par value | 100% | |||||||||||||||
Redemption price of the debt instrument in the event of change of control (as a percent) | 101% | |||||||||||||||
Amount of debt repurchased | 50,000 | 50,000 | $ 293,000 | $ 116,000 | ||||||||||||
7.625% Senior Notes Due 2029 | On or after February 1, 2024 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Redemption price | 103.813% | |||||||||||||||
7.625% Senior Notes Due 2029 | On or after February 1, 2027 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Redemption price | 100% | |||||||||||||||
7.625% Senior Notes Due 2029 | On or before February 1, 2024 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Redemption price of the debt instrument if redeemed with the proceeds of certain equity offerings (as a percent) | 107.625% | |||||||||||||||
Percentage of the principal amount of the debt instrument which the entity may redeem with the proceeds from certain equity offerings | 35% | |||||||||||||||
7.625% Senior Notes Due 2029 | Prior to February 1, 2024 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Redemption price | 100% | |||||||||||||||
5.375% senior notes due 2030 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Senior notes | $ 600,000 | $ 600,000 | $ 600,000 | $ 600,000 | $ 600,000 | |||||||||||
Interest rate (as a percent) | 5.375% | 5.375% | 5.375% | 5.375% | 5.375% | |||||||||||
Issue price as percentage of par value | 100% | |||||||||||||||
Redemption price of the debt instrument in the event of change of control (as a percent) | 101% | |||||||||||||||
5.375% senior notes due 2030 | On or after March 1, 2025 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Redemption price | 102.688% | |||||||||||||||
5.375% senior notes due 2030 | On or after March 1, 2028 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Redemption price | 100% | |||||||||||||||
5.375% senior notes due 2030 | On or Before March 1, 2025 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Redemption price of the debt instrument if redeemed with the proceeds of certain equity offerings (as a percent) | 105.375% | |||||||||||||||
Percentage of the principal amount of the debt instrument which the entity may redeem with the proceeds from certain equity offerings | 35% | |||||||||||||||
5.375% senior notes due 2030 | Prior to March 1, 2025 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Redemption price | 100% | |||||||||||||||
4.25% convertible senior notes due 2026 | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Convertible senior notes | $ 250,000 | $ 37,500 | $ 39,426 | $ 39,426 | $ 39,426 | $ 56,932 | ||||||||||
Unamortized discount, net | $ (116,000) | |||||||||||||||
Unamortized debt issuance costs | (702) | (702) | (702) | (1,159) | ||||||||||||
Long-term debt | $ 38,724 | $ 38,724 | $ 38,724 | $ 55,773 | ||||||||||||
Interest rate (as a percent) | 4.25% | 4.25% | 4.25% | 4.25% | 4.25% | |||||||||||
Amount of debt converted | $ 206,000 | $ 43,000 | ||||||||||||||
Issuance of convertible notes | 278,500 | |||||||||||||||
Payments of deferred financing costs | $ 9,000 | |||||||||||||||
Conversion rate | 230.2026 | |||||||||||||||
If-converted value | $ 209,000 | $ 209,000 | 209,000 | |||||||||||||
If-converted value above principal amount | 170,000 | $ 170,000 | $ 170,000 | |||||||||||||
Aggregate principal amount converted | 9,000 | |||||||||||||||
Aggregate principal amount induced into conversion | 9,000 | |||||||||||||||
Shares issued to cover conversions (in shares) | shares | 4 | |||||||||||||||
Cash inducement premium | $ 100 | |||||||||||||||
Effective interest rate (as a percent) | 15.10% | 15.10% | ||||||||||||||
Interest expense | $ 500 | $ 1,000 | $ 1,000 | $ 2,000 | ||||||||||||
4.25% convertible senior notes due 2026 | Convertible debt threshold minimum percentage | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Stock price trigger | 98% | |||||||||||||||
Trading days | D | 5 | |||||||||||||||
Consecutive trading days | D | 10 | |||||||||||||||
4.25% convertible senior notes due 2026 | Convertible debt threshold maximum percentage | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Stock price trigger | 130% | |||||||||||||||
Trading days | D | 20 | |||||||||||||||
Consecutive trading days | D | 30 | |||||||||||||||
4.25% convertible senior notes due 2026 | Fair value | ||||||||||||||||
Long-Term Debt | ||||||||||||||||
Fair value | $ 172,000 |
Asset Retirement Obligations (D
Asset Retirement Obligations (Details) - USD ($) $ in Thousands | 6 Months Ended | |
Jun. 30, 2023 | Jun. 30, 2022 | |
Asset Retirement Obligations | ||
Asset retirement obligations - beginning of period | $ 59,485 | |
Obligations incurred | 561 | |
Accretion expense | 2,082 | |
Settlement of obligations | (633) | $ (886) |
Revisions to prior estimates | 301 | |
Asset retirement obligations - end of period | $ 61,796 |
Equity-Based Compensation and_3
Equity-Based Compensation and Cash Awards (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | |||||
Mar. 12, 2019 | Jun. 30, 2023 | Jun. 30, 2022 | Jun. 30, 2023 | Jun. 30, 2022 | Jun. 17, 2020 | Mar. 11, 2019 | |
Stock-based compensation expense | |||||||
Equity based compensation expense recognized | $ 13,512 | $ 8,171 | $ 26,530 | $ 12,820 | |||
2020 Plan | |||||||
Stock-based compensation expense | |||||||
Number of stock-based compensation awards authorized | 10,050,000 | ||||||
Number of shares available for future grant under the Plan | 6,835,261 | 6,835,261 | |||||
AMP Plan | |||||||
Stock-based compensation expense | |||||||
Number of stock-based compensation awards authorized | 10,000,000 | ||||||
AMC Plan RSUs | |||||||
Stock-based compensation expense | |||||||
Conversion rate | 1.8926 | ||||||
RSUs | |||||||
Stock-based compensation expense | |||||||
Equity based compensation expense recognized | $ 8,720 | 4,774 | $ 15,982 | 7,494 | |||
PSUs | |||||||
Stock-based compensation expense | |||||||
Equity based compensation expense recognized | 4,442 | 3,012 | 9,847 | 4,431 | |||
Converted AM RSU Awards | |||||||
Stock-based compensation expense | |||||||
Equity based compensation expense recognized | 35 | 1 | 195 | ||||
Equity awards issued to directors | |||||||
Stock-based compensation expense | |||||||
Equity based compensation expense recognized | $ 350 | $ 350 | $ 700 | $ 700 |
Equity-Based Compensation and_4
Equity-Based Compensation and Cash Awards - Restricted Stock and RSU Awards (Details) - RSUs $ / shares in Units, $ in Millions | 6 Months Ended |
Jun. 30, 2023 USD ($) $ / shares shares | |
Number of shares | |
Total awarded and unvested at the beginning of the period (in shares) | shares | 4,676,219 |
Granted (in shares) | shares | 1,458,594 |
Vested (in shares) | shares | (2,202,895) |
Forfeited (in shares) | shares | (69,321) |
Total awarded and unvested at the end of the period (in shares) | shares | 3,862,597 |
Weighted average grant date fair value | |
Total awarded and unvested at the beginning of the period (in dollars per share) | $ / shares | $ 15.29 |
Granted (in dollars per share) | $ / shares | 25.87 |
Vested (in dollars per share) | $ / shares | 9.02 |
Forfeited (in dollars per share) | $ / shares | 22.57 |
Total awarded and unvested at the end of the period (in dollars per share) | $ / shares | $ 22.74 |
Unamortized equity-based compensation expense | $ | $ 76 |
Weighted average period for recognizing unrecognized stock-based compensation expense | 2 years 3 months 18 days |
Equity-Based Compensation and_5
Equity-Based Compensation and Cash Awards - PSU awards (Details) $ / shares in Units, $ in Millions | 1 Months Ended | 3 Months Ended | 6 Months Ended | |||
Mar. 31, 2023 period | Jul. 31, 2020 USD ($) | Jan. 31, 2020 USD ($) tranche | Jun. 30, 2023 USD ($) $ / shares shares | Jun. 30, 2023 USD ($) $ / shares shares | Dec. 31, 2022 USD ($) | |
Cash Awards | ||||||
Unvested cash awards recorded in other liabilities | $ | $ 0.4 | $ 0.4 | $ 1 | |||
2013 Plan | ||||||
Cash Awards | ||||||
Cash awards granted | $ | $ 3 | |||||
Number of tranches related to cash awards | tranche | 3 | |||||
2020 Plan | ||||||
Cash Awards | ||||||
Cash awards granted | $ | $ 3 | |||||
Vesting period for cash awards | 4 years | |||||
PSUs | ||||||
Stock-based compensation | ||||||
Number of shares of common stock awards converted into | shares | 400,000 | |||||
Number of units | ||||||
Total awarded and unvested at the beginning of the period (in shares) | shares | 1,329,725 | |||||
Granted (in shares) | shares | 417,466 | |||||
Vested (in shares) | shares | (335,000) | |||||
Total awarded and unvested at the end of the period (in shares) | shares | 1,412,191 | 1,412,191 | ||||
Weighted average grant date fair value | ||||||
Total awarded and unvested at the beginning of the period (in dollars per share) | $ / shares | $ 23.18 | |||||
Granted (in dollars per share) | $ / shares | 28.51 | |||||
Vested (in dollars per share) | $ / shares | 2.97 | |||||
Total awarded and unvested at the end of the period (in dollars per share) | $ / shares | $ 29.54 | $ 29.54 | ||||
Additional disclosures | ||||||
Unamortized equity-based compensation expense | $ | $ 29 | $ 29 | ||||
Weighted average period for recognizing unrecognized stock-based compensation expense | 1 year 8 months 12 days | |||||
PSU Awards Based on Absolute TSR | ||||||
Stock-based compensation | ||||||
Vesting percentage achieved | 112% | |||||
Weighted-average assumptions used to calculate fair value of performance share units granted | ||||||
Volatility (as a percent) | 82% | |||||
Risk-free interest rate (as a percent) | 4.61% | |||||
Weighted average fair value of awards granted - Absolute TSR | $ / shares | $ 33.96 | |||||
PSU Awards Based on Absolute TSR | Minimum | ||||||
Stock-based compensation | ||||||
Number of PSUs that may vest, as a percent | 0% | |||||
PSU Awards Based on Absolute TSR | Maximum | ||||||
Stock-based compensation | ||||||
Number of PSUs that may vest, as a percent | 200% | |||||
PSU Awards Based on Absolute TSR | One Year Period | ||||||
Stock-based compensation | ||||||
Service period | 1 year | |||||
Number of performance periods | period | 3 | |||||
PSU Awards Based on Absolute TSR | Three Year Period | ||||||
Stock-based compensation | ||||||
Service period | 3 years | |||||
Number of cumulative performance periods | period | 1 | |||||
PSU Awards Based On Relative TSR | ||||||
Stock-based compensation | ||||||
Vesting percentage achieved | 126% | |||||
2023 PSU Awards Based on Leverage Ratio | ||||||
Stock-based compensation | ||||||
Service period | 1 year | |||||
Number of performance periods | period | 3 | |||||
2023 PSU Awards Based on Leverage Ratio | Minimum | ||||||
Stock-based compensation | ||||||
Number of PSUs that may vest, as a percent | 0% | |||||
2023 PSU Awards Based on Leverage Ratio | Maximum | ||||||
Stock-based compensation | ||||||
Number of PSUs that may vest, as a percent | 200% |
Equity-Based Compensation and_6
Equity-Based Compensation and Cash Awards - Converted AM RSU Awards (Details) - Converted AM RSU Awards | 6 Months Ended |
Jun. 30, 2023 $ / shares shares | |
Number of units | |
Total awarded and unvested at the beginning of the period (in shares) | shares | 2,827 |
Vested (in shares) | shares | (2,827) |
Weighted average grant date fair value | |
Total awarded and unvested at the beginning of the period (in dollars per share) | $ / shares | $ 12.38 |
Vested (in dollars per share) | $ / shares | $ 12.38 |
Fair Value (Details)
Fair Value (Details) - USD ($) $ in Thousands | Jun. 30, 2023 | Dec. 31, 2022 |
Fair value | Level 2 market data | ||
Financial Instruments | ||
Value | $ 1,268,914 | $ 1,474,146 |
Fair value | Level 2 market data | 8.375% Senior Notes Due 2026 | ||
Financial Instruments | ||
Value | 100,076 | 100,987 |
Fair value | Level 2 market data | 7.625% Senior Notes Due 2029 | ||
Financial Instruments | ||
Value | 412,204 | 410,860 |
Fair value | Level 2 market data | 5.375% senior notes due 2030 | ||
Financial Instruments | ||
Value | 548,220 | 556,260 |
Fair value | Level 2 market data | 4.25% convertible senior notes due 2026 | ||
Financial Instruments | ||
Value | 208,414 | 406,039 |
Carrying value | ||
Financial Instruments | ||
Value | 1,132,370 | 1,148,676 |
Carrying value | 8.375% Senior Notes Due 2026 | ||
Financial Instruments | ||
Value | 96,235 | 96,123 |
Carrying value | 7.625% Senior Notes Due 2029 | ||
Financial Instruments | ||
Value | 403,151 | 402,872 |
Carrying value | 5.375% senior notes due 2030 | ||
Financial Instruments | ||
Value | 594,260 | 593,908 |
Carrying value | 4.25% convertible senior notes due 2026 | ||
Financial Instruments | ||
Value | $ 38,724 | $ 55,773 |
Derivative Instruments - Commod
Derivative Instruments - Commodity derivatives (Details) | Jun. 30, 2023 MMBTU / d bbl / d $ / MMBTU $ / bbl |
Natural gas. | Henry Hub | July-December 2023 | |
Derivative Instruments | |
Notional amount | MMBTU / d | 55,000 |
Natural gas. | Henry Hub | January-December 2024 | |
Derivative Instruments | |
Notional amount | MMBTU / d | 53,000 |
Natural gas. | Henry Hub | January-December 2025 | |
Derivative Instruments | |
Notional amount | MMBTU / d | 44,000 |
Natural gas. | Henry Hub | January-December 2026 | |
Derivative Instruments | |
Notional amount | MMBTU / d | 32,000 |
Natural gas. | NYMEX to TCO | July-December 2023 | |
Derivative Instruments | |
Notional amount | MMBTU / d | 50,000 |
Weighted average hedged differential | 0.525 |
Natural gas. | NYMEX to TCO | January-December 2024 | |
Derivative Instruments | |
Notional amount | MMBTU / d | 50,000 |
Weighted average hedged differential | 0.530 |
Swaps | Natural gas. | Henry Hub | July-December 2023 | |
Derivative Instruments | |
Notional amount | MMBTU / d | 43,000 |
Weighted average index price | 2.37 |
Swaps | Natural gas. | Henry Hub | July-December 2023 | VIE, Martica | |
Derivative Instruments | |
Notional amount | MMBTU / d | 32,496 |
Weighted average index price | 2.35 |
Swaps | Natural gas. | Henry Hub | January-December 2024 | VIE, Martica | |
Derivative Instruments | |
Notional amount | MMBTU / d | 23,885 |
Weighted average index price | 2.33 |
Swaps | Natural gas. | Henry Hub | January-March 2025 | VIE, Martica | |
Derivative Instruments | |
Notional amount | MMBTU / d | 18,021 |
Weighted average index price | 2.53 |
Swaps | Natural Gasoline | Mont Belvieu Natural Gasoline-OPIS Non-TET | July-December 2023 | VIE, Martica | |
Derivative Instruments | |
Notional amount | bbl / d | 227 |
Weighted average index price | $ / bbl | 40.74 |
Swaps | Oil | West Texas Intermediate | July-December 2023 | VIE, Martica | |
Derivative Instruments | |
Notional amount | bbl / d | 77 |
Weighted average index price | $ / bbl | 44.72 |
Swaps | Oil | West Texas Intermediate | January-December 2024 | VIE, Martica | |
Derivative Instruments | |
Notional amount | bbl / d | 43 |
Weighted average index price | $ / bbl | 44.02 |
Swaps | Oil | West Texas Intermediate | January-March 2025 | VIE, Martica | |
Derivative Instruments | |
Notional amount | bbl / d | 39 |
Weighted average index price | $ / bbl | 45.06 |
Call option and embedded put option | Natural gas. | Put option | Henry Hub | July-December 2023 | |
Derivative Instruments | |
Strike price | 2.466 |
Call option and embedded put option | Natural gas. | Put option | Henry Hub | January-December 2024 | |
Derivative Instruments | |
Strike price | 2.527 |
Call option and embedded put option | Natural gas. | Put option | Henry Hub | January-December 2025 | |
Derivative Instruments | |
Strike price | 2.614 |
Call option and embedded put option | Natural gas. | Put option | Henry Hub | January-December 2026 | |
Derivative Instruments | |
Strike price | 2.679 |
Call option and embedded put option | Natural gas. | Call Option | Henry Hub | July-December 2023 | |
Derivative Instruments | |
Strike price | 2.466 |
Call option and embedded put option | Natural gas. | Call Option | Henry Hub | January-December 2024 | |
Derivative Instruments | |
Strike price | 2.477 |
Call option and embedded put option | Natural gas. | Call Option | Henry Hub | January-December 2025 | |
Derivative Instruments | |
Strike price | 2.564 |
Call option and embedded put option | Natural gas. | Call Option | Henry Hub | January-December 2026 | |
Derivative Instruments | |
Strike price | 2.629 |
Derivative Instruments - Fair v
Derivative Instruments - Fair value (Details) - USD ($) $ in Thousands | Jun. 30, 2023 | Dec. 31, 2022 |
Fair value of derivative instruments | ||
Current portion of fair value of derivative assets | $ 3,099 | $ 1,900 |
Noncurrent portion of fair value of derivative assets | 7,934 | 9,844 |
Current portion of fair value of derivative liabilities | 35,509 | 97,765 |
Noncurrent portion of fair value of derivative liabilities | 59,224 | 345,280 |
Derivatives not designated as hedges for accounting purposes | ||
Fair value of derivative instruments | ||
Total asset derivatives | 11,033 | 11,744 |
Total liability derivatives | 94,733 | 443,045 |
Net derivatives liability | (83,700) | (431,301) |
Derivatives not designated as hedges for accounting purposes | Commodity derivatives | ||
Fair value of derivative instruments | ||
Current portion of fair value of derivative liabilities | 35,509 | 97,765 |
Noncurrent portion of fair value of derivative liabilities | 59,224 | 345,280 |
Derivatives not designated as hedges for accounting purposes | Commodity derivatives | VIE, Martica | ||
Fair value of derivative instruments | ||
Current portion of fair value of derivative liabilities | 10,000 | 28,000 |
Noncurrent portion of fair value of derivative liabilities | 7,000 | 19,000 |
Total liability derivatives | 17,000 | 47,000 |
Derivatives not designated as hedges for accounting purposes | Embedded derivatives | ||
Fair value of derivative instruments | ||
Current portion of fair value of derivative assets | 3,099 | 1,900 |
Noncurrent portion of fair value of derivative assets | $ 7,934 | $ 9,844 |
Derivative Instruments - Assets
Derivative Instruments - Assets and liabilities (Details) - USD ($) $ in Thousands | Jun. 30, 2023 | Dec. 31, 2022 |
Commodity derivatives | ||
Commodity derivative assets | ||
Gross amounts on balance sheet | $ 422 | $ 276 |
Gross amounts offset on balance sheet | (422) | (276) |
Commodity derivative liabilities | ||
Gross amounts on balance sheet | (95,155) | (443,321) |
Gross amounts offset on balance sheet | 422 | 276 |
Total liability derivatives | (94,733) | (443,045) |
Embedded derivatives | ||
Commodity derivative assets | ||
Gross amounts on balance sheet | 11,033 | 11,744 |
Total asset derivatives | $ 11,033 | $ 11,744 |
Derivative Instruments - Fair_2
Derivative Instruments - Fair value gains (losses) (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2023 | Jun. 30, 2022 | Jun. 30, 2023 | Jun. 30, 2022 | |
Summary of realized and unrealized gains (losses) on derivative instruments | ||||
Derivative fair value gains (losses) | $ 134,476 | $ (1,277,042) | ||
Payments for derivative monetizations | 202,339 | |||
Commodity derivatives | ||||
Summary of realized and unrealized gains (losses) on derivative instruments | ||||
Payments for derivative monetizations | 202,000 | |||
Commodity derivatives | Revenue. | ||||
Summary of realized and unrealized gains (losses) on derivative instruments | ||||
Derivative fair value gains (losses) | $ 6,232 | $ (237,680) | 133,312 | (1,232,163) |
Embedded derivatives | Revenue. | ||||
Summary of realized and unrealized gains (losses) on derivative instruments | ||||
Derivative fair value gains (losses) | $ 2,052 | $ (27,982) | $ 1,164 | $ (44,879) |
Leases (Details)
Leases (Details) | 6 Months Ended |
Jun. 30, 2023 | |
Leases | |
Options to renew - Operating lease | true |
Minimum | |
Leases | |
Renewal terms - Operating lease | 1 year |
Maximum | |
Leases | |
Renewal terms - Operating lease | 20 years |
Leases - Supplemental Balance S
Leases - Supplemental Balance Sheet Information Related to Leases (Details) - USD ($) $ in Thousands | Jun. 30, 2023 | Dec. 31, 2022 |
Lease Assets | ||
Operating leases right-of-use assets | $ 3,262,253 | $ 3,444,331 |
Short-term operating lease obligation | $ 553,107 | $ 556,137 |
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List] | Operating And Finance Lease Liability Current | Operating And Finance Lease Liability Current |
Long-term operating lease obligation | $ 2,709,146 | $ 2,888,194 |
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List] | Operating And Finance Lease Liability Noncurrent | Operating And Finance Lease Liability Noncurrent |
Total operating lease obligation | $ 3,262,253 | $ 3,444,331 |
Finance leases, right of use assets | 3,435 | 2,159 |
Short-term finance lease obligation | $ 846 | $ 499 |
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List] | Operating And Finance Lease Liability Current | Operating And Finance Lease Liability Current |
Long-term finance lease obligation | $ 2,589 | $ 1,660 |
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List] | Operating And Finance Lease Liability Noncurrent | Operating And Finance Lease Liability Noncurrent |
Total finance lease obligation | $ 3,435 | $ 2,159 |
Finance leases, accumulated amortization | 1,000 | 1,000 |
Vehicles | ||
Lease Assets | ||
Operating leases right-of-use assets | $ 109 | $ 756 |
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List] | Operating leases right-of-use assets | Operating leases right-of-use assets |
Finance leases, right of use assets | $ 3,435 | $ 2,159 |
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List] | Property, Plant and Equipment, Other, Gross | Property, Plant and Equipment, Other, Gross |
Other office and field equipment | ||
Lease Assets | ||
Operating leases right-of-use assets | $ 3,071 | $ 3,476 |
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List] | Operating leases right-of-use assets | Operating leases right-of-use assets |
Processing plants | ||
Lease Assets | ||
Operating leases right-of-use assets | $ 1,732,132 | $ 1,849,116 |
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List] | Operating leases right-of-use assets | Operating leases right-of-use assets |
Drilling rigs and completion services | ||
Lease Assets | ||
Operating leases right-of-use assets | $ 52,094 | $ 85,405 |
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List] | Operating leases right-of-use assets | Operating leases right-of-use assets |
Gas gathering lines and compressor stations | ||
Lease Assets | ||
Operating leases right-of-use assets | $ 1,435,070 | $ 1,463,756 |
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List] | Operating leases right-of-use assets | Operating leases right-of-use assets |
Gas gathering lines and compressor stations | Antero Midstream Corporation | ||
Lease Assets | ||
Operating leases right-of-use assets | $ 1,400,000 | |
Office space | ||
Lease Assets | ||
Operating leases right-of-use assets | $ 39,777 | $ 41,822 |
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List] | Operating leases right-of-use assets | Operating leases right-of-use assets |
Leases - Supplemental Informati
Leases - Supplemental Information Related to Leases (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2023 | Jun. 30, 2022 | Jun. 30, 2023 | Jun. 30, 2022 | Dec. 31, 2022 | Dec. 31, 2021 | |
Leases | ||||||
Total operating lease cost | $ 444,906 | $ 409,274 | $ 870,039 | $ 785,779 | ||
Total finance lease cost | 708 | 158 | 914 | 290 | ||
Short-term lease payments | $ 34,707 | $ 28,348 | 72,408 | 77,108 | ||
Cash paid for amounts included in the measurement of lease liabilities: | ||||||
Operating cash flows from operating leases | 654,938 | 675,563 | ||||
Operating cash flows from finance leases | 276 | 66 | ||||
Investing cash flows from operating leases | 61,092 | 39,781 | ||||
Financing cash flows from finance leases | 343 | 277 | ||||
Right-of-use assets obtained in exchange for new operating lease obligations | 51,737 | 215,157 | ||||
Increase (decrease) to existing right-of-use assets and lease obligations from operating lease modifications, net | $ 40,176 | $ (47,728) | ||||
Weighted average discount rate for remeasured operating leases (as a percent) | 5.80% | 5.10% | 5.80% | 5.10% | 5.20% | 4.50% |
Proved properties | ||||||
Leases | ||||||
Total operating lease cost | $ 31,602 | $ 41,100 | $ 71,372 | $ 48,859 | ||
Gathering, compression, water handling and treatment, processing, and transportation | ||||||
Leases | ||||||
Total operating lease cost | 407,445 | 365,343 | 788,728 | 731,177 | ||
General and administrative. | ||||||
Leases | ||||||
Total operating lease cost | 3,030 | 2,787 | 5,967 | 5,654 | ||
Contract termination | ||||||
Leases | ||||||
Total operating lease cost | 2,808 | 3,930 | ||||
Lease operating. | ||||||
Leases | ||||||
Total operating lease cost | 21 | 44 | 42 | 89 | ||
Depletion, depreciation and amortization | ||||||
Leases | ||||||
Amortization of right-of-use assets | 546 | 107 | 638 | 225 | ||
Interest expense | ||||||
Leases | ||||||
Interest on lease liabilities | $ 162 | $ 51 | $ 276 | $ 65 |
Leases - Maturities of Lease Li
Leases - Maturities of Lease Liabilities (Details) - USD ($) $ in Thousands | Jun. 30, 2023 | Dec. 31, 2022 |
Future minimum payments for operating lease liabilities | ||
Remainder of 2023 | $ 374,215 | |
2024 | 685,594 | |
2025 | 609,747 | |
2026 | 556,196 | |
2027 | 457,972 | |
Thereafter | 1,252,713 | |
Total lease payments | 3,936,437 | |
Less: imputed interest | (674,184) | |
Total operating lease obligation | 3,262,253 | $ 3,444,331 |
Future minimum payments for financing lease liabilities | ||
Remainder of 2023 | 669 | |
2024 | 1,339 | |
2025 | 1,297 | |
2026 | 961 | |
2027 | 112 | |
Thereafter | 33 | |
Total lease payments | 4,411 | |
Less: imputed interest | (976) | |
Total finance lease obligation | 3,435 | $ 2,159 |
Future minimum payments for total lease liabilities | ||
Remainder of 2023 | 374,884 | |
2024 | 686,933 | |
2025 | 611,044 | |
2026 | 557,157 | |
2027 | 458,084 | |
Thereafter | 1,252,746 | |
Total lease payments | 3,940,848 | |
Less: imputed interest | (675,160) | |
Total | $ 3,265,688 |
Leases - Lease Term and Discoun
Leases - Lease Term and Discount Rate (Details) | Jun. 30, 2023 | Dec. 31, 2022 |
Leases | ||
Weighted-average remaining lease term: Operating lease | 6 years 10 months 24 days | 7 years 2 months 12 days |
Weighted-average discount rate: Operating lease | 5.60% | 5.30% |
Weighted-average remaining lease term: Finance lease | 3 years 4 months 24 days | 3 years 6 months |
Weighted-average discount rate: Finance lease | 8.10% | 7.40% |
Leases - Related Party Lease Di
Leases - Related Party Lease Disclosure (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||||
Dec. 08, 2019 | Jun. 30, 2023 | Jun. 30, 2022 | Jun. 30, 2023 | Jun. 30, 2022 | Dec. 31, 2022 | |
Antero Midstream Corporation | ||||||
Leases | ||||||
Minimum volume commitments that require Antero to utilize or pay certain percentage of the capacity of new construction for high pressure lines (as a percent) | 75% | |||||
Minimum volume commitments that require Antero to utilize or pay certain percentage of the capacity of new construction of compressor stations (as a percent) | 70% | |||||
Term of lease | 10 years | |||||
Notice period | 180 days | |||||
Rebate received | $ 12,000 | $ 12,000 | $ 24,000 | $ 24,000 | ||
Gathering and compression fees paid | 185,000 | $ 164,000 | 361,000 | $ 327,000 | ||
Percentage of rate of return | 13% | |||||
Term for rate of return on constructions | 7 years | |||||
Antero Midstream Corporation | Marcellus | ||||||
Leases | ||||||
Minimum volume commitments that require Antero to utilize or pay certain percentage of the capacity of new construction of compressor stations (as a percent) | 25% | |||||
Term of lease | 10 years | |||||
Affiliated Entity | ||||||
Leases | ||||||
Accounts payable | 95,360 | 95,360 | $ 80,708 | |||
Affiliated Entity | Antero Midstream Corporation | ||||||
Leases | ||||||
Accounts payable | $ 69,000 | $ 69,000 | $ 59,000 |
Commitments (Details)
Commitments (Details) $ in Thousands | 6 Months Ended |
Jun. 30, 2023 USD ($) MMBTU / d | |
Future minimum payments | |
Remainder of 2023 | $ 1,007,534 |
2024 | 1,903,926 |
2025 | 1,802,080 |
2026 | 1,709,977 |
2027 | 1,602,718 |
Thereafter | 6,778,086 |
Total | $ 14,804,321 |
Commitments | |
Early termination of commitment per day (in MMBtu/d) | MMBTU / d | 200,000 |
Cash payment for early termination | $ 24,000 |
Firm transportation | |
Future minimum payments | |
Remainder of 2023 | 594,682 |
2024 | 1,147,772 |
2025 | 1,134,296 |
2026 | 1,131,882 |
2027 | 1,127,234 |
Thereafter | 5,444,784 |
Total | 10,580,650 |
Processing, Gathering, Compression and Water Service | |
Future minimum payments | |
Remainder of 2023 | 35,382 |
2024 | 63,212 |
2025 | 51,865 |
2026 | 18,688 |
2027 | 17,400 |
Thereafter | 80,556 |
Total | 267,103 |
Operating and Financing Leases | |
Future minimum payments | |
Remainder of 2023 | 286,449 |
2024 | 533,031 |
2025 | 486,261 |
2026 | 459,146 |
2027 | 384,429 |
Thereafter | 1,116,372 |
Total | 3,265,688 |
Imputed Interest for Leases | |
Future minimum payments | |
Remainder of 2023 | 88,435 |
2024 | 153,902 |
2025 | 124,783 |
2026 | 98,011 |
2027 | 73,655 |
Thereafter | 136,374 |
Total | 675,160 |
Other. | |
Future minimum payments | |
Remainder of 2023 | 2,586 |
2024 | 6,009 |
2025 | 4,875 |
2026 | 2,250 |
Total | $ 15,720 |
Reportable Segments (Details)
Reportable Segments (Details) $ in Thousands | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2023 USD ($) | Jun. 30, 2022 USD ($) | Jun. 30, 2023 USD ($) segment | Jun. 30, 2022 USD ($) | Dec. 31, 2022 USD ($) | |
Operating results and assets of reportable segments | |||||
Number of reportable segments | segment | 3 | ||||
Sales and revenues: | |||||
Sales and revenues - Third-party | $ 952,885 | $ 2,201,294 | $ 2,360,890 | $ 2,987,713 | |
Sales and revenues - Intersegment | 420 | 391 | 763 | 812 | |
Revenues | 953,305 | 2,201,685 | 2,361,653 | 2,988,525 | |
Operating expenses: | |||||
Lease operating | 28,748 | 25,253 | 58,069 | 43,033 | |
General and administrative | 53,901 | 44,439 | 111,162 | 80,130 | |
Depletion, depreciation and amortization | 171,406 | 173,395 | 338,988 | 341,783 | |
Impairment of property and equipment | 15,710 | 23,363 | 31,270 | 45,825 | |
Other | 108,501 | 217,505 | 270,463 | 374,345 | |
Total operating expenses | 1,042,241 | 1,140,167 | 2,119,099 | 2,131,606 | |
Operating income (loss) | (88,936) | 1,061,518 | 242,554 | 856,919 | |
Equity in earnings of unconsolidated affiliate | 19,098 | 14,713 | 36,779 | 39,891 | |
Capital expenditures for segment assets | 637,096 | 260,864 | 637,096 | 476,740 | |
Investments in unconsolidated affiliates | 218,196 | 218,196 | $ 220,429 | ||
Total assets | 13,766,810 | 13,766,810 | 14,118,039 | ||
Gathering, compression, water handling and treatment, processing, and transportation | |||||
Operating expenses: | |||||
Cost of goods and services sold | 663,975 | 656,212 | 1,309,147 | 1,246,490 | |
Operating segments | Exploration and production | |||||
Sales and revenues: | |||||
Sales and revenues - Third-party | 909,092 | 2,095,144 | 2,258,568 | 2,812,525 | |
Sales and revenues - Intersegment | 420 | 391 | 763 | 812 | |
Revenues | 909,512 | 2,095,535 | 2,259,331 | 2,813,337 | |
Operating expenses: | |||||
Lease operating | 28,748 | 25,253 | 58,069 | 43,033 | |
General and administrative | 53,901 | 44,439 | 111,162 | 80,130 | |
Depletion, depreciation and amortization | 171,406 | 173,395 | 338,988 | 341,783 | |
Impairment of property and equipment | 15,710 | 23,363 | 31,270 | 45,825 | |
Other | 42,326 | 86,207 | 99,164 | 144,151 | |
Total operating expenses | 976,066 | 1,008,869 | 1,947,800 | 1,901,412 | |
Operating income (loss) | (66,554) | 1,086,666 | 311,531 | 911,925 | |
Equity in earnings of unconsolidated affiliate | 19,098 | 14,713 | 36,779 | 39,891 | |
Capital expenditures for segment assets | 637,096 | 260,864 | 637,096 | 476,740 | |
Investments in unconsolidated affiliates | 218,196 | 218,196 | 220,429 | ||
Total assets | 13,747,226 | 13,747,226 | 14,081,077 | ||
Operating segments | Exploration and production | Gathering, compression, water handling and treatment, processing, and transportation | |||||
Operating expenses: | |||||
Cost of goods and services sold | 663,975 | 656,212 | 1,309,147 | 1,246,490 | |
Operating segments | Marketing | |||||
Sales and revenues: | |||||
Sales and revenues - Third-party | 43,793 | 106,150 | 102,322 | 175,188 | |
Revenues | 43,793 | 106,150 | 102,322 | 175,188 | |
Operating expenses: | |||||
Other | 66,175 | 131,298 | 171,299 | 230,194 | |
Total operating expenses | 66,175 | 131,298 | 171,299 | 230,194 | |
Operating income (loss) | (22,382) | (25,148) | (68,977) | (55,006) | |
Total assets | 19,584 | 19,584 | 36,962 | ||
Operating segments | Antero Midstream Corporation | |||||
Sales and revenues: | |||||
Sales and revenues - Third-party | 274 | 242 | 546 | 637 | |
Sales and revenues - Intersegment | 258,013 | 228,665 | 517,216 | 446,761 | |
Revenues | 258,287 | 228,907 | 517,762 | 447,398 | |
Operating expenses: | |||||
General and administrative | 18,162 | 16,079 | 35,509 | 34,010 | |
Depletion, depreciation and amortization | 35,233 | 35,675 | 70,429 | 63,975 | |
Impairment of property and equipment | 3,702 | 3,702 | |||
Other | 6,774 | 1,756 | 7,488 | 2,850 | |
Total operating expenses | 112,764 | 100,511 | 223,894 | 189,848 | |
Operating income (loss) | 145,523 | 128,396 | 293,868 | 257,550 | |
Equity in earnings of unconsolidated affiliate | 25,972 | 22,824 | 50,428 | 46,056 | |
Capital expenditures for segment assets | 41,782 | 77,767 | 84,739 | 162,034 | |
Investments in unconsolidated affiliates | 639,887 | 639,887 | 652,767 | ||
Total assets | 5,752,883 | 5,752,883 | 5,791,320 | ||
Operating segments | Antero Midstream Corporation | Gathering, compression, water handling and treatment, processing, and transportation | |||||
Operating expenses: | |||||
Cost of goods and services sold | 52,595 | 43,299 | 110,468 | 85,311 | |
Elimination of intersegment transaction | |||||
Sales and revenues: | |||||
Sales and revenues - Third-party | (274) | (242) | (546) | (637) | |
Sales and revenues - Intersegment | (258,013) | (228,665) | (517,216) | (446,761) | |
Revenues | (258,287) | (228,907) | (517,762) | (447,398) | |
Operating expenses: | |||||
General and administrative | (18,162) | (16,079) | (35,509) | (34,010) | |
Depletion, depreciation and amortization | (35,233) | (35,675) | (70,429) | (63,975) | |
Impairment of property and equipment | (3,702) | (3,702) | |||
Other | (6,774) | (1,756) | (7,488) | (2,850) | |
Total operating expenses | (112,764) | (100,511) | (223,894) | (189,848) | |
Operating income (loss) | (145,523) | (128,396) | (293,868) | (257,550) | |
Equity in earnings of unconsolidated affiliate | (25,972) | (22,824) | (50,428) | (46,056) | |
Capital expenditures for segment assets | (41,782) | (77,767) | (84,739) | (162,034) | |
Investments in unconsolidated affiliates | (639,887) | (639,887) | (652,767) | ||
Total assets | (5,752,883) | (5,752,883) | $ (5,791,320) | ||
Elimination of intersegment transaction | Gathering, compression, water handling and treatment, processing, and transportation | |||||
Operating expenses: | |||||
Cost of goods and services sold | $ (52,595) | $ (43,299) | $ (110,468) | $ (85,311) |
Subsidiary Guarantors - Balance
Subsidiary Guarantors - Balance Sheets (Details) - USD ($) $ in Thousands | Jun. 30, 2023 | Dec. 31, 2022 |
Current assets: | ||
Total current assets | $ 384,728 | $ 787,525 |
Total assets | 13,766,810 | 14,118,039 |
Liabilities and Stockholders' Equity | ||
Other current liabilities | 6,728 | 1,707 |
Total current liabilities | 1,506,864 | 1,774,909 |
Total liabilities | 6,698,482 | 7,100,885 |
Parent (Antero) And Guarantor Subsidiaries | ||
Current assets: | ||
Total current assets | 363,698 | 739,104 |
Noncurrent assets | 12,775,341 | 12,663,911 |
Total assets | 13,139,039 | 13,403,015 |
Liabilities and Stockholders' Equity | ||
Other current liabilities | 1,398,840 | 1,668,426 |
Total current liabilities | 1,494,200 | 1,749,134 |
Noncurrent liabilities | 5,184,049 | 5,306,539 |
Total liabilities | 6,678,249 | 7,055,673 |
Affiliated Entity | ||
Liabilities and Stockholders' Equity | ||
Accounts payable | 95,360 | 80,708 |
Affiliated Entity | Parent (Antero) And Guarantor Subsidiaries | ||
Liabilities and Stockholders' Equity | ||
Accounts payable | $ 95,360 | $ 80,708 |
Subsidiary Guarantors - Stateme
Subsidiary Guarantors - Statements of Operations (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2023 | Mar. 31, 2023 | Jun. 30, 2022 | Mar. 31, 2022 | Jun. 30, 2023 | Jun. 30, 2022 | |
Statement of Operations | ||||||
Revenues | $ 936,983 | $ 2,456,717 | $ 2,211,248 | $ 4,245,146 | ||
Operating expenses | 1,042,241 | 1,140,167 | 2,119,099 | 2,131,606 | ||
Income (loss) from operations | (88,936) | 1,061,518 | 242,554 | 856,919 | ||
Net income and comprehensive income including noncontrolling interests | (67,933) | $ 261,202 | 812,033 | $ (174,696) | 193,269 | 637,337 |
Net income and comprehensive income attributable to Antero Resources Corporation | $ (83,084) | $ 765,135 | 130,347 | $ 608,716 | ||
Parent (Antero) And Guarantor Subsidiaries | ||||||
Statement of Operations | ||||||
Revenues | 2,275,190 | |||||
Operating expenses | 2,095,558 | |||||
Income (loss) from operations | 179,632 | |||||
Net income and comprehensive income including noncontrolling interests | 130,347 | |||||
Net income and comprehensive income attributable to Antero Resources Corporation | $ 130,347 |