HESS CORP - Quarter Report: 2022 June (Form 10-Q)
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
Form 10-Q
| ☒ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |||||||||||||
For the quarter ended June 30, 2022
or
| ☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |||||||
For the transition period from to
Commission File Number 1-1204
HESS CORPORATION
(Exact Name of Registrant as Specified in Its Charter)
DELAWARE
(State or Other Jurisdiction of Incorporation or Organization)
13-4921002
(I.R.S. Employer Identification Number)
1185 AVENUE OF THE AMERICAS, NEW YORK, NY
(Address of Principal Executive Offices)
10036
(Zip Code)
(Registrant’s Telephone Number, Including Area Code is (212) 997-8500)
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol | Name of exchange on which registered | ||||||
| Common Stock | HES | New York Stock Exchange | ||||||
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ý No ¨
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ý No ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
| Large accelerated filer | ☒ | Accelerated filer | ☐ | |||||||||||||||||
| Non-accelerated filer | ☐ | Smaller reporting company | ☐ | |||||||||||||||||
| Emerging growth company | ☐ | |||||||||||||||||||
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ý
At June 30, 2022, there were 309,614,906 shares of Common Stock outstanding.
HESS CORPORATION
Form 10-Q
TABLE OF CONTENTS
| Item No. | Page Number | |||||||
| 2. | ||||||||
Unless the context indicates otherwise, references to “Hess”, the “Corporation”, “Registrant”, “we”, “us”, “our” and “its” refer to the consolidated business operations of Hess Corporation and its subsidiaries.
PART I - FINANCIAL INFORMATION
Item 1. Financial Statements.
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
CONSOLIDATED BALANCE SHEET (UNAUDITED)
| June 30, 2022 | December 31, 2021 | ||||||||||
| (In millions, except share amounts) | |||||||||||
| Assets | |||||||||||
| Current Assets: | |||||||||||
| Cash and cash equivalents | $ | 2,159 | $ | 2,713 | |||||||
| Accounts receivable: | |||||||||||
| From contracts with customers | 1,265 | 1,062 | |||||||||
| Joint venture and other | 141 | 149 | |||||||||
| Inventories | 317 | 223 | |||||||||
| Other current assets | 87 | 199 | |||||||||
| Total current assets | 3,969 | 4,346 | |||||||||
| Property, plant and equipment: | |||||||||||
| Total — at cost | 32,402 | 31,178 | |||||||||
| Less: Reserves for depreciation, depletion, amortization and lease impairment | 17,584 | 16,996 | |||||||||
| Property, plant and equipment — net | 14,818 | 14,182 | |||||||||
| Operating lease right-of-use assets — net | 446 | 352 | |||||||||
| Finance lease right-of-use assets — net | 136 | 144 | |||||||||
| Goodwill | 360 | 360 | |||||||||
| Deferred income taxes | 147 | 71 | |||||||||
| Post-retirement benefit assets | 603 | 409 | |||||||||
| Other assets | 701 | 651 | |||||||||
| Total Assets | $ | 21,180 | $ | 20,515 | |||||||
| Liabilities | |||||||||||
| Current Liabilities: | |||||||||||
| Accounts payable | $ | 359 | $ | 220 | |||||||
| Accrued liabilities | 1,741 | 1,710 | |||||||||
| Taxes payable | 141 | 528 | |||||||||
| Current portion of long-term debt | — | 517 | |||||||||
| Current portion of operating and finance lease obligations | 114 | 89 | |||||||||
| Total current liabilities | 2,355 | 3,064 | |||||||||
| Long-term debt | 8,332 | 7,941 | |||||||||
| Long-term operating lease obligations | 457 | 394 | |||||||||
| Long-term finance lease obligations | 190 | 200 | |||||||||
| Deferred income taxes | 544 | 383 | |||||||||
| Asset retirement obligations | 1,028 | 1,005 | |||||||||
| Other liabilities and deferred credits | 516 | 502 | |||||||||
| Total Liabilities | 13,422 | 13,489 | |||||||||
| Equity | |||||||||||
| Hess Corporation stockholders’ equity: | |||||||||||
Common stock, par value $1.00; Authorized — 600,000,000 shares | |||||||||||
Issued 309,614,906 shares (2021: 309,744,953) | 310 | 310 | |||||||||
| Capital in excess of par value | 6,236 | 6,017 | |||||||||
| Retained earnings | 1,075 | 379 | |||||||||
| Accumulated other comprehensive income (loss) | (485) | (406) | |||||||||
| Total Hess Corporation stockholders’ equity | 7,136 | 6,300 | |||||||||
| Noncontrolling interests | 622 | 726 | |||||||||
| Total Equity | 7,758 | 7,026 | |||||||||
| Total Liabilities and Equity | $ | 21,180 | $ | 20,515 | |||||||
See accompanying Notes to Consolidated Financial Statements.
2
PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
STATEMENT OF CONSOLIDATED INCOME (UNAUDITED)
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In millions, except per share amounts) | |||||||||||||||||||||||
| Revenues and Non-Operating Income | |||||||||||||||||||||||
| Sales and other operating revenues | $ | 2,955 | $ | 1,579 | $ | 5,268 | $ | 3,477 | |||||||||||||||
| Gains on asset sales, net | 3 | — | 25 | — | |||||||||||||||||||
| Other, net | 30 | 19 | 66 | 40 | |||||||||||||||||||
| Total revenues and non-operating income | 2,988 | 1,598 | 5,359 | 3,517 | |||||||||||||||||||
| Costs and Expenses | |||||||||||||||||||||||
| Marketing, including purchased oil and gas | 843 | 322 | 1,525 | 840 | |||||||||||||||||||
| Operating costs and expenses | 356 | 315 | 669 | 580 | |||||||||||||||||||
| Production and severance taxes | 67 | 44 | 128 | 81 | |||||||||||||||||||
| Exploration expenses, including dry holes and lease impairment | 33 | 48 | 76 | 81 | |||||||||||||||||||
| General and administrative expenses | 95 | 84 | 205 | 178 | |||||||||||||||||||
| Interest expense | 121 | 118 | 244 | 235 | |||||||||||||||||||
| Depreciation, depletion and amortization | 391 | 385 | 728 | 781 | |||||||||||||||||||
| Impairment and other | — | 147 | — | 147 | |||||||||||||||||||
| Total costs and expenses | 1,906 | 1,463 | 3,575 | 2,923 | |||||||||||||||||||
| Income (Loss) Before Income Taxes | 1,082 | 135 | 1,784 | 594 | |||||||||||||||||||
| Provision (benefit) for income taxes | 328 | 122 | 525 | 245 | |||||||||||||||||||
| Net Income (Loss) | 754 | 13 | 1,259 | 349 | |||||||||||||||||||
| Less: Net income (loss) attributable to noncontrolling interests | 87 | 86 | 175 | 170 | |||||||||||||||||||
| Net Income (Loss) Attributable to Hess Corporation | $ | 667 | $ | (73) | $ | 1,084 | $ | 179 | |||||||||||||||
| Net Income (Loss) Attributable to Hess Corporation Per Common Share: | |||||||||||||||||||||||
| Basic | $ | 2.15 | $ | (0.24) | $ | 3.50 | $ | 0.58 | |||||||||||||||
| Diluted | $ | 2.15 | $ | (0.24) | $ | 3.49 | $ | 0.58 | |||||||||||||||
| Weighted Average Number of Common Shares Outstanding: | |||||||||||||||||||||||
| Basic | 309.7 | 307.5 | 309.3 | 306.7 | |||||||||||||||||||
| Diluted | 310.9 | 307.5 | 310.6 | 308.7 | |||||||||||||||||||
| Common Stock Dividends Per Share | $ | 0.375 | $ | 0.250 | $ | 0.750 | $ | 0.500 | |||||||||||||||
See accompanying Notes to Consolidated Financial Statements.
3
PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
STATEMENT OF CONSOLIDATED COMPREHENSIVE INCOME (UNAUDITED)
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In millions) | |||||||||||||||||||||||
| Net Income (Loss) | $ | 754 | $ | 13 | $ | 1,259 | $ | 349 | |||||||||||||||
| Other Comprehensive Income (Loss): | |||||||||||||||||||||||
| Derivatives designated as cash flow hedges | |||||||||||||||||||||||
| Effect of hedge (gains) losses reclassified to income | 163 | 64 | 255 | 115 | |||||||||||||||||||
| Income taxes on effect of hedge (gains) losses reclassified to income | — | — | — | — | |||||||||||||||||||
| Net effect of hedge (gains) losses reclassified to income | 163 | 64 | 255 | 115 | |||||||||||||||||||
| Change in fair value of cash flow hedges | (39) | (129) | (494) | (231) | |||||||||||||||||||
| Income taxes on change in fair value of cash flow hedges | — | — | — | — | |||||||||||||||||||
| Net change in fair value of cash flow hedges | (39) | (129) | (494) | (231) | |||||||||||||||||||
| Change in derivatives designated as cash flow hedges, after taxes | 124 | (65) | (239) | (116) | |||||||||||||||||||
| Pension and other postretirement plans | |||||||||||||||||||||||
| (Increase) reduction in unrecognized actuarial losses | 152 | (11) | 152 | 3 | |||||||||||||||||||
| Income taxes on actuarial changes in plan liabilities | — | — | — | — | |||||||||||||||||||
| (Increase) reduction in unrecognized actuarial losses, net | 152 | (11) | 152 | 3 | |||||||||||||||||||
| Amortization of net actuarial losses | 5 | 16 | 8 | 32 | |||||||||||||||||||
| Income taxes on amortization of net actuarial losses | — | — | — | — | |||||||||||||||||||
| Net effect of amortization of net actuarial losses | 5 | 16 | 8 | 32 | |||||||||||||||||||
| Change in pension and other postretirement plans, after taxes | 157 | 5 | 160 | 35 | |||||||||||||||||||
| Other Comprehensive Income (Loss) | 281 | (60) | (79) | (81) | |||||||||||||||||||
| Comprehensive Income (Loss) | 1,035 | (47) | 1,180 | 268 | |||||||||||||||||||
| Less: Comprehensive income (loss) attributable to noncontrolling interests | 87 | 86 | 175 | 170 | |||||||||||||||||||
| Comprehensive Income (Loss) Attributable to Hess Corporation | $ | 948 | $ | (133) | $ | 1,005 | $ | 98 | |||||||||||||||
See accompanying Notes to Consolidated Financial Statements.
4
PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
STATEMENT OF CONSOLIDATED CASH FLOWS (UNAUDITED)
| Six Months Ended June 30, | |||||||||||
| 2022 | 2021 | ||||||||||
| (In millions) | |||||||||||
| Cash Flows From Operating Activities | |||||||||||
| Net income (loss) | $ | 1,259 | $ | 349 | |||||||
| Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities: | |||||||||||
| (Gains) on asset sales, net | (25) | — | |||||||||
| Depreciation, depletion and amortization | 728 | 781 | |||||||||
| Impairment and other | — | 147 | |||||||||
| Exploratory dry hole costs | — | 9 | |||||||||
| Exploration lease and other impairment | 10 | 10 | |||||||||
| Pension settlement loss | 2 | 4 | |||||||||
| Stock compensation expense | 49 | 44 | |||||||||
| Noncash (gains) losses on commodity derivatives, net | 218 | 88 | |||||||||
| Provision (benefit) for deferred income taxes and other tax accruals | 174 | 42 | |||||||||
| Changes in operating assets and liabilities: | |||||||||||
| (Increase) decrease in accounts receivable | (529) | (315) | |||||||||
| (Increase) decrease in inventories | (94) | 137 | |||||||||
| Increase (decrease) in accounts payable and accrued liabilities | 100 | (56) | |||||||||
| Increase (decrease) in taxes payable | (387) | 187 | |||||||||
| Changes in other operating assets and liabilities | (152) | (51) | |||||||||
| Net cash provided by (used in) operating activities | 1,353 | 1,376 | |||||||||
| Cash Flows From Investing Activities | |||||||||||
| Additions to property, plant and equipment - E&P | (1,098) | (687) | |||||||||
| Additions to property, plant and equipment - Midstream | (111) | (53) | |||||||||
| Proceeds from asset sales, net of cash sold | 28 | 297 | |||||||||
| Other, net | — | (2) | |||||||||
| Net cash provided by (used in) investing activities | (1,181) | (445) | |||||||||
| Cash Flows From Financing Activities | |||||||||||
| Net borrowings (repayments) of debt with maturities of 90 days or less | (13) | (75) | |||||||||
| Debt with maturities of greater than 90 days: | |||||||||||
| Borrowings | 400 | — | |||||||||
| Repayments | (510) | (5) | |||||||||
| Cash dividends paid | (235) | (157) | |||||||||
| Common stock acquired and retired | (190) | — | |||||||||
| Proceeds from sale of Class A shares of Hess Midstream LP | 146 | 70 | |||||||||
| Noncontrolling interests, net | (351) | (137) | |||||||||
| Employee stock options exercised | 40 | 75 | |||||||||
| Payments on finance lease obligations | (4) | (4) | |||||||||
| Other, net | (9) | (7) | |||||||||
| Net cash provided by (used in) financing activities | (726) | (240) | |||||||||
| Net Increase (Decrease) in Cash and Cash Equivalents | (554) | 691 | |||||||||
| Cash and Cash Equivalents at Beginning of Year | 2,713 | 1,739 | |||||||||
| Cash and Cash Equivalents at End of Period | $ | 2,159 | $ | 2,430 | |||||||
See accompanying Notes to Consolidated Financial Statements.
5
PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
STATEMENT OF CONSOLIDATED EQUITY (UNAUDITED)
| Common Stock | Capital in Excess of Par | Retained Earnings | Accumulated Other Comprehensive Income (Loss) | Total Hess Stockholders' Equity | Noncontrolling Interests | Total Equity | |||||||||||||||||||||||||||||||||||
| For the Three Months Ended June 30, 2022 | |||||||||||||||||||||||||||||||||||||||||
| Balance at April 1, 2022 | $ | 311 | $ | 6,083 | $ | 680 | $ | (766) | $ | 6,308 | $ | 740 | $ | 7,048 | |||||||||||||||||||||||||||
| Net income (loss) | — | — | 667 | — | 667 | 87 | 754 | ||||||||||||||||||||||||||||||||||
| Other comprehensive income (loss) | — | — | — | 281 | 281 | — | 281 | ||||||||||||||||||||||||||||||||||
| Share-based compensation | 1 | 24 | — | — | 25 | — | 25 | ||||||||||||||||||||||||||||||||||
| Dividends on common stock | — | — | (117) | — | (117) | — | (117) | ||||||||||||||||||||||||||||||||||
| Sale of Class A shares of Hess Midstream LP | — | 130 | — | — | 130 | 88 | 218 | ||||||||||||||||||||||||||||||||||
| Repurchase of Class B units of Hess Midstream Operations LP | — | 32 | — | — | 32 | (215) | (183) | ||||||||||||||||||||||||||||||||||
| Common stock acquired and retired | (2) | (33) | (155) | — | (190) | — | (190) | ||||||||||||||||||||||||||||||||||
| Noncontrolling interests, net | — | — | — | — | — | (78) | (78) | ||||||||||||||||||||||||||||||||||
| Balance at June 30, 2022 | $ | 310 | $ | 6,236 | $ | 1,075 | $ | (485) | $ | 7,136 | $ | 622 | $ | 7,758 | |||||||||||||||||||||||||||
| For the Three Months Ended June 30, 2021 | |||||||||||||||||||||||||||||||||||||||||
| Balance at April 1, 2021 | $ | 308 | $ | 5,779 | $ | 305 | $ | (776) | 5,616 | $ | 1,027 | $ | 6,643 | ||||||||||||||||||||||||||||
| Net income (loss) | — | — | (73) | — | (73) | 86 | 13 | ||||||||||||||||||||||||||||||||||
| Other comprehensive income (loss) | — | — | — | (60) | (60) | — | (60) | ||||||||||||||||||||||||||||||||||
| Share-based compensation | 2 | 80 | — | — | 82 | — | 82 | ||||||||||||||||||||||||||||||||||
| Dividends on common stock | — | — | (77) | — | (77) | — | (77) | ||||||||||||||||||||||||||||||||||
| Noncontrolling interests, net | — | — | — | — | — | (69) | (69) | ||||||||||||||||||||||||||||||||||
| Balance at June 30, 2021 | $ | 310 | $ | 5,859 | $ | 155 | $ | (836) | $ | 5,488 | $ | 1,044 | $ | 6,532 | |||||||||||||||||||||||||||
| For the Six Months Ended June 30, 2022 | |||||||||||||||||||||||||||||||||||||||||
| Balance at January 1, 2022 | $ | 310 | $ | 6,017 | $ | 379 | $ | (406) | $ | 6,300 | $ | 726 | $ | 7,026 | |||||||||||||||||||||||||||
| Net income (loss) | — | — | 1,084 | — | 1,084 | 175 | 1,259 | ||||||||||||||||||||||||||||||||||
| Other comprehensive income (loss) | — | — | — | (79) | (79) | — | (79) | ||||||||||||||||||||||||||||||||||
| Share-based compensation | 2 | 90 | — | — | 92 | — | 92 | ||||||||||||||||||||||||||||||||||
| Dividends on common stock | — | — | (233) | — | (233) | — | (233) | ||||||||||||||||||||||||||||||||||
| Sale of Class A shares of Hess Midstream LP | — | 130 | — | — | 130 | 88 | 218 | ||||||||||||||||||||||||||||||||||
| Repurchase of Class B units of Hess Midstream Operations LP | — | 32 | — | — | 32 | (215) | (183) | ||||||||||||||||||||||||||||||||||
| Common stock acquired and retired | (2) | (33) | (155) | — | (190) | — | (190) | ||||||||||||||||||||||||||||||||||
| Noncontrolling interests, net | — | — | — | — | — | (152) | (152) | ||||||||||||||||||||||||||||||||||
| Balance at June 30, 2022 | $ | 310 | $ | 6,236 | $ | 1,075 | $ | (485) | $ | 7,136 | $ | 622 | $ | 7,758 | |||||||||||||||||||||||||||
| For the Six Months Ended June 30, 2021 | |||||||||||||||||||||||||||||||||||||||||
| Balance at January 1, 2021 | $ | 307 | $ | 5,684 | $ | 130 | $ | (755) | 5,366 | $ | 969 | $ | 6,335 | ||||||||||||||||||||||||||||
| Net income (loss) | — | — | 179 | — | 179 | 170 | 349 | ||||||||||||||||||||||||||||||||||
| Other comprehensive income (loss) | — | — | — | (81) | (81) | — | (81) | ||||||||||||||||||||||||||||||||||
| Share-based compensation | 3 | 119 | — | — | 122 | — | 122 | ||||||||||||||||||||||||||||||||||
| Dividends on common stock | — | — | (154) | — | (154) | — | (154) | ||||||||||||||||||||||||||||||||||
| Sale of Class A shares of Hess Midstream LP | — | 56 | — | — | 56 | 41 | 97 | ||||||||||||||||||||||||||||||||||
| Noncontrolling interests, net | — | — | — | — | — | (136) | (136) | ||||||||||||||||||||||||||||||||||
| Balance at June 30, 2021 | $ | 310 | $ | 5,859 | $ | 155 | $ | (836) | $ | 5,488 | $ | 1,044 | $ | 6,532 | |||||||||||||||||||||||||||
See accompanying Notes to Consolidated Financial Statements.
6
PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
1. Basis of Presentation
The financial statements included in this report reflect all normal and recurring adjustments which, in the opinion of management, are necessary for a fair presentation of our consolidated financial position at June 30, 2022 and December 31, 2021, the consolidated results of operations for the three and six months ended June 30, 2022 and 2021, and consolidated cash flows for the six months ended June 30, 2022 and 2021. The unaudited results of operations for the interim periods reported are not necessarily indicative of results to be expected for the full year.
The financial statements were prepared in accordance with the requirements of the Securities and Exchange Commission (SEC) for interim reporting. As permitted under those rules, certain notes or other financial information that are normally required by generally accepted accounting principles (GAAP) in the United States have been condensed or omitted from these interim financial statements. These statements, therefore, should be read in conjunction with the consolidated financial statements and related notes included in the Corporation’s Annual Report on Form 10-K for the year ended December 31, 2021.
2. Inventories
Inventories consisted of the following:
| June 30, 2022 | December 31, 2021 | ||||||||||
| (In millions) | |||||||||||
| Crude oil and natural gas liquids | $ | 142 | $ | 52 | |||||||
| Materials and supplies | 175 | 171 | |||||||||
| Total Inventories | $ | 317 | $ | 223 | |||||||
3. Property, Plant and Equipment
Capitalized Exploratory Well Costs:
The following table discloses the net changes in capitalized exploratory well costs pending determination of proved reserves during the six months ended June 30, 2022 (in millions):
| Balance at January 1, 2022 | $ | 681 | |||
| Additions to capitalized exploratory well costs pending the determination of proved reserves | 194 | ||||
| Reclassifications to wells, facilities and equipment based on the determination of proved reserves | (93) | ||||
| Balance at June 30, 2022 | $ | 782 | |||
Additions to capitalized exploratory well costs pending determination of proved reserves are related to wells drilled on the Stabroek Block (Hess 30%), offshore Guyana and drilling at the Huron prospect (Hess 40%) in the Gulf of Mexico. Reclassifications to wells, facilities and equipment based on the determination of proved reserves resulted from the sanction of the Yellowtail Field development project, the fourth sanctioned project on the Stabroek Block.
At June 30, 2022, exploratory well costs capitalized for greater than one year following completion of drilling of $417 million was comprised of the following:
Guyana: Approximately 89% of the capitalized well costs in excess of one year relate to successful exploration wells where hydrocarbons were encountered on the Stabroek Block. The operator plans further appraisal drilling on the Block and is conducting pre-development planning for additional phases of development.
Joint Development Area (JDA): Approximately 9% of the capitalized well costs in excess of one year relates to the JDA (Hess 50%) in the Gulf of Thailand, where hydrocarbons were encountered in three successful exploration wells drilled in the western part of Block A-18. The operator has submitted a development plan concept to the regulator to facilitate ongoing commercial negotiations for an extension of the existing gas sales contract to include development of the western part of the Block.
Malaysia: Approximately 2% of the capitalized well costs in excess of one year relate to the North Malay Basin (Hess 50%), offshore Peninsular Malaysia, where hydrocarbons were encountered in one successful exploration well. Subsurface evaluation and pre-development studies are ongoing.
7
PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
4. Hess Midstream LP
At June 30, 2022, Hess Midstream LP (Hess Midstream), a variable interest entity that is fully consolidated by Hess Corporation, had liabilities totaling $3,078 million (December 31, 2021: $2,694 million) that are on a nonrecourse basis to Hess Corporation, while Hess Midstream assets available to settle the obligations of Hess Midstream included cash and cash equivalents totaling $2 million (December 31, 2021: $2 million), property, plant and equipment with a carrying value of $3,145 million (December 31, 2021: $3,125 million) and an equity-method investment in the Little Missouri 4 (LM4) gas processing plant of $97 million (December 31, 2021: $102 million).
LM4 is a 200 million standard cubic feet per day gas processing plant located south of the Missouri River in McKenzie County, North Dakota, that was constructed as part of a 50/50 joint venture between Hess Midstream and Targa Resources Corp. Hess Midstream has a natural gas processing agreement with LM4 under which it pays a processing fee and reimburses LM4 for its proportionate share of electricity costs. The processing fees included in Operating costs and expenses in the Statement of Consolidated Income for the three and six months ended June 30, 2022 were $4 million and $9 million, respectively, compared with $7 million and $14 million for the three and six months ended June 30, 2021, respectively.
In April 2022, Hess Midstream LP completed an underwritten public equity offering of approximately 10.2 million Hess Midstream LP Class A shares held by a subsidiary of Hess Corporation and an affiliate of Global Infrastructure Partners (GIP). We received net proceeds of $146 million from the public offering. The transaction resulted in an increase in Capital in excess of par and Noncontrolling interests of $130 million and $88 million, respectively. The increase to Noncontrolling interests of $88 million is comprised of $16 million resulting from the change in ownership interest and $72 million from an increase to deferred tax assets resulting from a change in the temporary difference between the carrying amount and tax basis of Hess Midstream LP's investment in Hess Midstream Operations LP (HESM Opco).
Concurrent with the April 2022 public offering, HESM Opco, a consolidated subsidiary of Hess Midstream LP, repurchased approximately 13.6 million HESM Opco Class B units held by a subsidiary of Hess Corporation and an affiliate of GIP for $400 million. HESM Opco issued $400 million in aggregate principal amount of 5.500% fixed-rate senior unsecured notes due 2030 in a private offering to repay borrowings under its revolving credit facility used to finance the repurchase. The transaction resulted in an increase in Capital in excess of par and a decrease in Noncontrolling interests of $32 million, and an increase in deferred tax assets and Noncontrolling interests of $17 million resulting from a change in the temporary difference between the carrying amount and tax basis of Hess Midstream LP's investment in HESM Opco. The $200 million paid to GIP reduced Noncontrolling Interests. We owned an approximate 41% interest in Hess Midstream LP, on a consolidated basis, at June 30, 2022.
In March 2021, Hess Midstream LP completed an underwritten public equity offering of 6.9 million Hess Midstream LP Class A shares held by a subsidiary of Hess Corporation and an affiliate of GIP. We received net proceeds of $70 million from the public offering. The transaction resulted in an increase in Capital in excess of par and Noncontrolling interests of $56 million and $41 million, respectively. The increase to Noncontrolling interests of $41 million is comprised of $14 million resulting from the change in ownership interest and $27 million from an increase to deferred tax assets resulting from a change in the temporary difference between the carrying amount and tax basis of Hess Midstream LP's investment in HESM Opco.
5. Accrued Liabilities
Accrued Liabilities consisted of the following:
| June 30, 2022 | December 31, 2021 | ||||||||||
| (In millions) | |||||||||||
| Accrued operating and marketing expenditures | $ | 508 | $ | 462 | |||||||
| Accrued capital expenditures | 515 | 479 | |||||||||
| Accrued payments to royalty and working interest owners | 263 | 253 | |||||||||
| Current portion of asset retirement obligations | 232 | 185 | |||||||||
| Accrued interest on debt | 143 | 138 | |||||||||
| Accrued compensation and benefits | 62 | 124 | |||||||||
| Other accruals | 18 | 69 | |||||||||
| Total Accrued Liabilities | $ | 1,741 | $ | 1,710 | |||||||
6. Debt
In April 2022, HESM Opco issued $400 million in aggregate principal amount of 5.500% fixed-rate senior unsecured notes due 2030 in a private offering to repay borrowings under its revolving credit facility used to finance the repurchase of approximately
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PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
13.6 million HESM Opco Class B units held by a subsidiary of Hess Corporation and an affiliate of GIP. The covenants of the 5.500% fixed-rate senior unsecured notes are substantially similar to the terms of the other existing HESM Opco fixed-rate senior unsecured notes.
In February 2022, we repaid the remaining $500 million outstanding under our $1.0 billion term loan previously scheduled to mature in March 2023.
7. Revenue
Revenue from contracts with customers on a disaggregated basis was as follows (in millions):
| Exploration and Production | Midstream | Eliminations | Total | ||||||||||||||||||||||||||||||||||||||||||||
| United States | Guyana | Malaysia and JDA | Other (a) | E&P Total | |||||||||||||||||||||||||||||||||||||||||||
| Three Months Ended June 30, 2022 | |||||||||||||||||||||||||||||||||||||||||||||||
| Sales of our net production volumes: | |||||||||||||||||||||||||||||||||||||||||||||||
| Crude oil revenue | $ | 895 | $ | 681 | $ | 37 | $ | 170 | $ | 1,783 | $ | — | $ | — | $ | 1,783 | |||||||||||||||||||||||||||||||
| Natural gas liquids revenue | 173 | — | — | — | 173 | — | — | 173 | |||||||||||||||||||||||||||||||||||||||
| Natural gas revenue | 126 | — | 215 | 5 | 346 | — | — | 346 | |||||||||||||||||||||||||||||||||||||||
| Sales of purchased oil and gas | 761 | 18 | — | 36 | 815 | — | — | 815 | |||||||||||||||||||||||||||||||||||||||
| Intercompany revenue | — | — | — | — | — | 314 | (314) | — | |||||||||||||||||||||||||||||||||||||||
| Total revenues from contracts with customers | 1,955 | 699 | 252 | 211 | 3,117 | 314 | (314) | 3,117 | |||||||||||||||||||||||||||||||||||||||
| Other operating revenues (b) | (95) | (52) | — | (15) | (162) | — | — | (162) | |||||||||||||||||||||||||||||||||||||||
| Total sales and other operating revenues | $ | 1,860 | $ | 647 | $ | 252 | $ | 196 | $ | 2,955 | $ | 314 | $ | (314) | $ | 2,955 | |||||||||||||||||||||||||||||||
| Three Months Ended June 30, 2021 | |||||||||||||||||||||||||||||||||||||||||||||||
| Sales of our net production volumes: | |||||||||||||||||||||||||||||||||||||||||||||||
| Crude oil revenue | $ | 661 | $ | 134 | $ | 27 | $ | 135 | $ | 957 | $ | — | $ | — | $ | 957 | |||||||||||||||||||||||||||||||
| Natural gas liquids revenue | 120 | — | — | — | 120 | — | — | 120 | |||||||||||||||||||||||||||||||||||||||
| Natural gas revenue | 61 | — | 178 | 1 | 240 | — | — | 240 | |||||||||||||||||||||||||||||||||||||||
| Sales of purchased oil and gas | 299 | 4 | — | 26 | 329 | — | — | 329 | |||||||||||||||||||||||||||||||||||||||
| Intercompany revenue | — | — | — | — | — | 294 | (294) | — | |||||||||||||||||||||||||||||||||||||||
| Total revenues from contracts with customers | 1,141 | 138 | 205 | 162 | 1,646 | 294 | (294) | 1,646 | |||||||||||||||||||||||||||||||||||||||
| Other operating revenues (b) | (53) | (6) | — | (8) | (67) | — | — | (67) | |||||||||||||||||||||||||||||||||||||||
| Total sales and other operating revenues | $ | 1,088 | $ | 132 | $ | 205 | $ | 154 | $ | 1,579 | $ | 294 | $ | (294) | $ | 1,579 | |||||||||||||||||||||||||||||||
| Six Months Ended June 30, 2022 | |||||||||||||||||||||||||||||||||||||||||||||||
| Sales of our net production volumes: | |||||||||||||||||||||||||||||||||||||||||||||||
| Crude oil revenue | $ | 1,731 | $ | 907 | $ | 68 | $ | 316 | $ | 3,022 | $ | — | $ | — | $ | 3,022 | |||||||||||||||||||||||||||||||
| Natural gas liquids revenue | 354 | — | — | — | 354 | — | — | 354 | |||||||||||||||||||||||||||||||||||||||
| Natural gas revenue | 211 | — | 405 | 10 | 626 | — | — | 626 | |||||||||||||||||||||||||||||||||||||||
| Sales of purchased oil and gas | 1,421 | 22 | — | 71 | 1,514 | — | — | 1,514 | |||||||||||||||||||||||||||||||||||||||
| Intercompany revenue | — | — | — | — | — | 626 | (626) | — | |||||||||||||||||||||||||||||||||||||||
| Total revenues from contracts with customers | 3,717 | 929 | 473 | 397 | 5,516 | 626 | (626) | 5,516 | |||||||||||||||||||||||||||||||||||||||
| Other operating revenues (b) | (153) | (67) | — | (28) | (248) | — | — | (248) | |||||||||||||||||||||||||||||||||||||||
| Total sales and other operating revenues | $ | 3,564 | $ | 862 | $ | 473 | $ | 369 | $ | 5,268 | $ | 626 | $ | (626) | $ | 5,268 | |||||||||||||||||||||||||||||||
| Six Months Ended June 30, 2021 | |||||||||||||||||||||||||||||||||||||||||||||||
| Sales of our net production volumes: | |||||||||||||||||||||||||||||||||||||||||||||||
| Crude oil revenue | $ | 1,546 | $ | 315 | $ | 49 | $ | 251 | $ | 2,161 | $ | — | $ | — | $ | 2,161 | |||||||||||||||||||||||||||||||
| Natural gas liquids revenue | 263 | — | — | — | 263 | — | — | 263 | |||||||||||||||||||||||||||||||||||||||
| Natural gas revenue | 174 | — | 341 | 4 | 519 | — | — | 519 | |||||||||||||||||||||||||||||||||||||||
| Sales of purchased oil and gas | 597 | 8 | — | 45 | 650 | — | — | 650 | |||||||||||||||||||||||||||||||||||||||
| Intercompany revenue | — | — | — | — | — | 583 | (583) | — | |||||||||||||||||||||||||||||||||||||||
| Total revenues from contracts with customers | 2,580 | 323 | 390 | 300 | 3,593 | 583 | (583) | 3,593 | |||||||||||||||||||||||||||||||||||||||
| Other operating revenues (b) | (94) | (10) | — | (12) | (116) | — | — | (116) | |||||||||||||||||||||||||||||||||||||||
| Total sales and other operating revenues | $ | 2,486 | $ | 313 | $ | 390 | $ | 288 | $ | 3,477 | $ | 583 | $ | (583) | $ | 3,477 | |||||||||||||||||||||||||||||||
(a)Other includes Libya and our interests in Denmark, which were sold in the third quarter of 2021.
(b)Includes gains (losses) on commodity derivatives.
There have been no significant changes to contracts with customers or the composition thereof during the six months ended
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PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
June 30, 2022. Generally, we receive payments from customers on a monthly basis, shortly after the physical delivery of the crude oil, natural gas liquids, or natural gas. At June 30, 2022, contract liabilities of $24 million (December 31, 2021: $24 million) resulted from a take-or-pay deficiency payment received in the fourth quarter of 2021 that is subject to a make-up period expiring in December 2023. At June 30, 2022 and December 31, 2021, there were no contract assets.
8. Impairment and Other
In June 2021, the U.S. Bankruptcy Court approved the bankruptcy plan for Fieldwood Energy LLC (Fieldwood) which includes transferring abandonment obligations of Fieldwood to predecessors in title of certain of its assets, who are jointly and severally liable for the obligations. Second quarter 2021 results include a charge of $147 million ($147 million after income taxes) in connection with abandonment obligations in the West Delta 79/86 Field (West Delta Field), which we sold to a Fieldwood predecessor in 2004.
9. Retirement Plans
Components of net periodic benefit cost consisted of the following:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In millions) | |||||||||||||||||||||||
| Service cost | $ | 12 | $ | 13 | $ | 25 | $ | 27 | |||||||||||||||
| Interest cost (a) | 17 | 14 | 33 | 28 | |||||||||||||||||||
| Expected return on plan assets (a) | (52) | (49) | (105) | (99) | |||||||||||||||||||
| Amortization of unrecognized net actuarial losses (a) | 3 | 13 | 6 | 28 | |||||||||||||||||||
| Settlement loss (a) | 2 | 3 | 2 | 4 | |||||||||||||||||||
| Net periodic benefit cost (income) (a) | $ | (18) | $ | (6) | $ | (39) | $ | (12) | |||||||||||||||
(a) Net non-service cost included in Other, net in the Statement of Consolidated Income for the three and six months ended June 30, 2022 was income of $30 million and $64 million, respectively, compared with income of $19 million and $39 million for the three and six months ended June 30, 2021.
In the second quarter of 2022, the Hess Corporation Employees’ Pension Plan purchased a single premium annuity contract at a cost of approximately $170 million using assets of the plan to settle and transfer certain of its obligations to a third party. This partial settlement resulted in a noncash charge of $13 million to recognize unamortized actuarial losses. In connection with this settlement transaction, as required under U.S. accounting standards, we remeasured the funded status of the plan, which increased by $154 million primarily due to a change in the weighted average discount rate used to value the projected benefit obligation, and an update to the fair value of plan assets. The change in the funded status is reflected in Post-retirement benefit assets in the Consolidated Balance Sheet.
In the second quarter of 2022, the HOVENSA Legacy Employees' Pension Plan paid lump sums of approximately $20 million to certain participants, and purchased a single premium annuity contract at a cost of approximately $80 million, to settle the plan's projected benefit obligation. The settlement transactions resulted in a noncash gain of $11 million to recognize unamortized actuarial gains. In connection with these settlement transactions, as required under U.S. accounting standards, we remeasured the funded status of the plan, which increased by $6 million. The change in the funded status is reflected in Post-retirement benefit assets in the Consolidated Balance Sheet.
For the full year 2022, we forecast service cost for our pension and postretirement medical plans to be approximately $45 million and net non-service cost to be approximately $118 million of income, which is comprised of expected return on plan assets of approximately $200 million, interest cost of approximately $70 million, amortization of unrecognized net actuarial losses of approximately $10 million, and net settlement losses of $2 million. In 2022, we expect to contribute approximately $45 million to our funded pension plans.
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PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
10. Weighted Average Common Shares
The Net income (loss) and weighted average number of common shares used in the basic and diluted earnings per share computations were as follows:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In millions) | |||||||||||||||||||||||
| Net income (loss) attributable to Hess Corporation: | |||||||||||||||||||||||
| Net income (loss) | $ | 754 | $ | 13 | $ | 1,259 | $ | 349 | |||||||||||||||
| Less: Net income (loss) attributable to noncontrolling interests | 87 | 86 | 175 | 170 | |||||||||||||||||||
| Net income (loss) attributable to Hess Corporation | $ | 667 | $ | (73) | $ | 1,084 | $ | 179 | |||||||||||||||
| Weighted average number of common shares outstanding: | |||||||||||||||||||||||
| Basic | 309.7 | 307.5 | 309.3 | 306.7 | |||||||||||||||||||
| Effect of dilutive securities | |||||||||||||||||||||||
| Restricted common stock | 0.6 | — | 0.6 | 0.7 | |||||||||||||||||||
| Stock options | 0.6 | — | 0.6 | 0.5 | |||||||||||||||||||
| Performance share units | — | — | 0.1 | 0.8 | |||||||||||||||||||
| Diluted | 310.9 | 307.5 | 310.6 | 308.7 | |||||||||||||||||||
The following table summarizes the number of antidilutive shares excluded from the computation of diluted shares:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| Restricted common stock | — | 1,641,860 | 48 | 94,726 | |||||||||||||||||||
| Stock options | 269,748 | 2,562,983 | 172,581 | 832,454 | |||||||||||||||||||
| Performance share units | 29,668 | 1,161,324 | 30,510 | 39,608 | |||||||||||||||||||
During the six months ended June 30, 2022, we granted 565,318 shares of restricted stock (2021: 705,489), 178,008 performance share units (2021: 205,155) and 269,748 stock options (2021: 319,295).
At December 31, 2021, the remaining amount under our Board authorized $7.5 billion stock repurchase plan was $650 million. In the second quarter of 2022, we repurchased approximately 1.8 million shares of common stock for $190 million. No shares of common stock were repurchased during 2021.
11. Guarantees and Contingencies
We are subject to loss contingencies with respect to various claims, lawsuits and other proceedings. A liability is recognized in our consolidated financial statements when it is probable that a loss has been incurred and the amount can be reasonably estimated. If the risk of loss is probable, but the amount cannot be reasonably estimated or the risk of loss is only reasonably possible, a liability is not accrued; however, we disclose the nature of those contingencies. We cannot predict with certainty if, how or when existing claims, lawsuits and proceedings will be resolved or what the eventual relief, if any, may be, particularly for proceedings that are in their early stages of development or where plaintiffs seek indeterminate damages.
We, along with many companies that have been or continue to be engaged in refining and marketing of gasoline, have been a party to lawsuits and claims related to the use of methyl tertiary butyl ether (MTBE) in gasoline. A series of similar lawsuits, many involving water utilities or governmental entities, were filed in jurisdictions across the United States against producers of MTBE and petroleum refiners who produced gasoline containing MTBE, including us. The principal allegation in all cases was that gasoline containing MTBE was a defective product and that these producers and refiners are strictly liable in proportion to their share of the gasoline market for damage to groundwater resources and are required to take remedial action to ameliorate the alleged effects on the environment of releases of MTBE. The majority of the cases asserted against us have been settled. There are two remaining active cases, filed by Pennsylvania and Maryland. In June 2014, the Commonwealth of Pennsylvania filed a lawsuit alleging that we and all major oil companies with operations in Pennsylvania, have damaged the groundwater by introducing thereto gasoline with MTBE. The Pennsylvania suit has been forwarded to the existing MTBE multidistrict litigation pending in the Southern District of New York. In December 2017, the State of Maryland filed a lawsuit alleging that we and other major oil companies damaged the groundwater in
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PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
Maryland by introducing thereto gasoline with MTBE. The suit, filed in Maryland state court, was served on us in January 2018 and has been removed to federal court by the defendants.
In September 2003, we received a directive from the New Jersey Department of Environmental Protection (NJDEP) to remediate contamination in the sediments of the Lower Passaic River. The NJDEP is also seeking natural resource damages. The directive, insofar as it affects us, relates to alleged releases from a petroleum bulk storage terminal in Newark, New Jersey we previously owned. We and over 70 companies entered into an Administrative Order on Consent with the Environmental Protection Agency (EPA) to study the same contamination; this work remains ongoing. We and other parties settled a cost recovery claim by the State of New Jersey and agreed with the EPA to fund remediation of a portion of the site. Since 2016, the EPA has issued a Record of Decision (ROD) selecting a dredge and cap remedy for both the lower eight miles and the upper nine miles of the Lower Passaic River at an estimated cost of approximately $1.82 billion. The ROD does not address the Newark Bay, which may require additional remedial action. In addition, the federal trustees for natural resources have begun a separate assessment of damages to natural resources in the Passaic River. Given that the EPA has not selected a final remedy for the Newark Bay, total remedial costs cannot be reliably estimated at this time. Based on currently known facts and circumstances, we do not believe that this matter will result in a significant liability to us because our former terminal did not store or use contaminants which are of concern in the river sediments and could not have contributed contamination along the river’s length. Further, there are numerous other parties who we expect will bear the cost of remediation and damages.
In March 2014, we received an Administrative Order from the EPA requiring us and 26 other parties to undertake the Remedial Design for the remedy selected by the EPA for the Gowanus Canal Superfund Site in Brooklyn, New York. Our alleged liability derives from our former ownership and operation of a fuel oil terminal and connected shipbuilding and repair facility adjacent to the Canal. The remedy selected by the EPA includes dredging of surface sediments and the placement of a cap over the deeper sediments throughout the Canal and in-situ stabilization of certain contaminated sediments that will remain in place below the cap. The EPA’s original estimate was that this remedy would cost $506 million; however, the ultimate costs that will be incurred in connection with the design and implementation of the remedy remain uncertain. We have complied with the EPA’s March 2014 Administrative Order and contributed funding for the Remedial Design based on an allocation of costs among the parties determined by a third-party expert. In January 2020, we received an additional Administrative Order from the EPA requiring us and several other parties to begin Remedial Action along the uppermost portion of the Canal. We intend to comply with this Administrative Order. The remediation work began in the fourth quarter of 2020. Based on currently known facts and circumstances, we do not believe that this matter will result in a significant liability to us, and the costs will continue to be allocated amongst the parties, as they were for the Remedial Design.
From time to time, we are involved in other judicial and administrative proceedings relating to environmental matters. We periodically receive notices from the EPA that we are a “potential responsible party” under the Superfund legislation with respect to various waste disposal sites. Under this legislation, all potentially responsible parties may be jointly and severally liable. For any site for which we have received such a notice, the EPA’s claims or assertions of liability against us relating to these sites have not been fully developed, or the EPA’s claims have been settled or a settlement is under consideration, in all cases for amounts that are not material. Beginning in 2017, certain states, municipalities and private associations in California, Delaware, Maryland, Rhode Island and South Carolina separately filed lawsuits against oil, gas and coal producers, including us, for alleged damages purportedly caused by climate change. These proceedings include claims for monetary damages and injunctive relief. Beginning in 2013, various parishes in Louisiana filed suit against approximately 100 oil and gas companies, including us, alleging that the companies’ operations and activities in certain fields violated the State and Local Coastal Resource Management Act of 1978, as amended, and caused contamination, subsidence and other environmental damages to land and water bodies located in the coastal zone of Louisiana. The plaintiffs seek, among other things, the payment of the costs necessary to clear, re-vegetate and otherwise restore the allegedly impacted areas. The ultimate impact of such climate and other aforementioned environmental proceedings, and of any related proceedings by private parties, on our business or accounts cannot be predicted at this time due to the large number of other potentially responsible parties and the speculative nature of clean-up cost estimates.
Hess Corporation and its subsidiary HONX, Inc. have also been named as defendants in various personal injury claims alleging exposure to asbestos and/or other alleged toxic substances while working at a former refinery (owned and operated by subsidiaries or related entities) located in St. Croix, U.S. Virgin Islands. HONX, Inc. has initiated a Chapter 11 § 524G process to resolve these asbestos-related claims. While the ultimate outcome and impact to us cannot be predicted with certainty, we believe that the resolution of these proceedings will not have a material adverse effect on our consolidated financial position, results of operations or cash flows.
We are also involved in other judicial and administrative proceedings from time to time in addition to the matters described above, including claims related to post-production deductions from royalty and working interest payments. We may also be exposed to future decommissioning liabilities for divested assets in the event the current or future owners of facilities previously owned by us are determined to be unable to perform such actions, whether due to bankruptcy or otherwise. We cannot predict with certainty if,
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PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
how or when such proceedings will be resolved or what the eventual relief, if any, may be, particularly for proceedings that are in their early stages of development or where plaintiffs seek indeterminate damages. Numerous issues may need to be resolved, including through potentially lengthy discovery and determination of important factual matters before a loss or range of loss can be reasonably estimated for any proceeding.
Subject to the foregoing, in management’s opinion, based upon currently known facts and circumstances, the outcome of lawsuits, claims and proceedings, including the matters disclosed above, is not expected to have a material adverse effect on our financial condition, results of operations or cash flows. However, we could incur judgments, enter into settlements, or revise our opinion regarding the outcome of certain matters, and such developments could have a material adverse effect on our results of operations in the period in which the amounts are accrued and our cash flows in the period in which the amounts are paid.
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PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
12. Segment Information
We currently have two operating segments, Exploration and Production and Midstream. All unallocated costs are reflected under Corporate, Interest and Other. The following table presents operating segment financial data:
| Exploration and Production | Midstream | Corporate, Interest and Other | Eliminations | Total | |||||||||||||||||||||||||
| (In millions) | |||||||||||||||||||||||||||||
| For the Three Months Ended June 30, 2022 | |||||||||||||||||||||||||||||
| Sales and Other Operating Revenues - Third parties | $ | 2,955 | $ | — | $ | — | $ | — | $ | 2,955 | |||||||||||||||||||
| Intersegment Revenues | — | 314 | — | (314) | — | ||||||||||||||||||||||||
| Sales and Other Operating Revenues | $ | 2,955 | $ | 314 | $ | — | $ | (314) | $ | 2,955 | |||||||||||||||||||
| Net Income (Loss) attributable to Hess Corporation | $ | 723 | $ | 65 | $ | (121) | $ | — | $ | 667 | |||||||||||||||||||
| Depreciation, Depletion and Amortization | 345 | 44 | 2 | — | 391 | ||||||||||||||||||||||||
| Provision (Benefit) for Income Taxes | 321 | 7 | — | — | 328 | ||||||||||||||||||||||||
| Capital Expenditures | 593 | 72 | — | — | 665 | ||||||||||||||||||||||||
| For the Three Months Ended June 30, 2021 | |||||||||||||||||||||||||||||
| Sales and Other Operating Revenues - Third parties | $ | 1,579 | $ | — | $ | — | $ | — | $ | 1,579 | |||||||||||||||||||
| Intersegment Revenues | — | 294 | — | (294) | — | ||||||||||||||||||||||||
| Sales and Other Operating Revenues | $ | 1,579 | $ | 294 | $ | — | $ | (294) | $ | 1,579 | |||||||||||||||||||
| Net Income (Loss) attributable to Hess Corporation | $ | (25) | $ | 76 | $ | (124) | $ | — | $ | (73) | |||||||||||||||||||
| Depreciation, Depletion and Amortization | 344 | 41 | — | — | 385 | ||||||||||||||||||||||||
| Impairment and other | 147 | — | — | — | 147 | ||||||||||||||||||||||||
| Provision (Benefit) for Income Taxes | 119 | 3 | — | — | 122 | ||||||||||||||||||||||||
| Capital Expenditures | 396 | 47 | — | — | 443 | ||||||||||||||||||||||||
| For the Six Months Ended June 30, 2022 | |||||||||||||||||||||||||||||
| Sales and Other Operating Revenues - Third parties | $ | 5,268 | $ | — | $ | — | $ | — | $ | 5,268 | |||||||||||||||||||
| Intersegment Revenues | — | 626 | — | (626) | — | ||||||||||||||||||||||||
| Sales and Other Operating Revenues | $ | 5,268 | $ | 626 | $ | — | $ | (626) | $ | 5,268 | |||||||||||||||||||
| Net Income (Loss) attributable to Hess Corporation | $ | 1,183 | $ | 137 | $ | (236) | $ | — | $ | 1,084 | |||||||||||||||||||
| Depreciation, Depletion and Amortization | 637 | 89 | 2 | — | 728 | ||||||||||||||||||||||||
| Provision (Benefit) for Income Taxes | 513 | 12 | — | — | 525 | ||||||||||||||||||||||||
| Capital Expenditures | 1,136 | 109 | — | — | 1,245 | ||||||||||||||||||||||||
| For the Six Months Ended June 30, 2021 | |||||||||||||||||||||||||||||
| Sales and Other Operating Revenues - Third parties | $ | 3,477 | $ | — | $ | — | $ | — | $ | 3,477 | |||||||||||||||||||
| Intersegment Revenues | — | 583 | — | (583) | — | ||||||||||||||||||||||||
| Sales and Other Operating Revenues | $ | 3,477 | $ | 583 | $ | — | $ | (583) | $ | 3,477 | |||||||||||||||||||
| Net Income (Loss) attributable to Hess Corporation | $ | 283 | $ | 151 | $ | (255) | $ | — | $ | 179 | |||||||||||||||||||
| Depreciation, Depletion and Amortization | 699 | 81 | 1 | — | 781 | ||||||||||||||||||||||||
| Impairment and other | 147 | — | — | — | 147 | ||||||||||||||||||||||||
| Provision (Benefit) for Income Taxes | 239 | 6 | — | — | 245 | ||||||||||||||||||||||||
| Capital Expenditures | 676 | 70 | — | — | 746 | ||||||||||||||||||||||||
14
PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
Identifiable assets by operating segment were as follows:
| June 30, 2022 | December 31, 2021 | ||||||||||
| (In millions) | |||||||||||
| Exploration and Production | $ | 14,886 | $ | 14,173 | |||||||
| Midstream | 3,755 | 3,671 | |||||||||
| Corporate, Interest and Other | 2,539 | 2,671 | |||||||||
| Total | $ | 21,180 | $ | 20,515 | |||||||
13. Financial Risk Management Activities
In the normal course of our business, we are exposed to commodity risks related to changes in the prices of crude oil and natural gas, as well as changes in interest rates and foreign currency values. Financial risk management activities include transactions designed to reduce risk in the selling prices of crude oil or natural gas we produce or by reducing our exposure to foreign currency or interest rate movements. Generally, futures, swaps or option strategies may be used to fix the forward selling price, or establish a floor price or a range banded with a floor and ceiling price, for a portion of our crude oil or natural gas production. Forward contracts or swaps may also be used to purchase certain currencies in which we conduct business with the intent of reducing exposure to foreign currency fluctuations. At June 30, 2022, these instruments relate to the British Pound and Malaysian Ringgit. Interest rate swaps may be used to convert interest payments on certain long-term debt from fixed to floating rates.
The notional amounts of outstanding financial risk management derivative contracts were as follows:
| June 30, 2022 | December 31, 2021 | ||||||||||
| (In millions) | |||||||||||
| Commodity - crude oil hedge contracts (millions of barrels) | 27.6 | 54.8 | |||||||||
| Foreign exchange forwards | $ | 157 | $ | 145 | |||||||
| Interest rate swaps | $ | 100 | $ | 100 | |||||||
At December 31, 2021, we had hedged 90,000 barrels of oil per day (bopd) with WTI collars with an average monthly floor price of $60 per barrel and an average monthly ceiling price of $100 per barrel and 60,000 bopd with Brent collars with an average monthly floor price of $65 per barrel and an average monthly ceiling price of $105 per barrel for calendar 2022. In the first quarter of 2022, we purchased WTI and Brent call options to remove the ceiling price on our price collars for the period April 1, 2022 through December 31, 2022 for $325 million. As a result, during this period, we are able to realize WTI and Brent selling prices above $100 per barrel and $105 per barrel, respectively, to the extent that market prices exceed these thresholds. The WTI $60 per barrel put options for 90,000 bopd and the Brent $65 per barrel put options for 60,000 bopd in our price collars remain outstanding through December 31, 2022.
15
PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
The table below reflects the fair values of risk management derivative instruments.
| Assets | Liabilities | ||||||||||
| (In millions) | |||||||||||
| June 30, 2022 | |||||||||||
| Derivative Contracts Designated as Hedging Instruments: | |||||||||||
| Crude oil put options | $ | 26 | $ | — | |||||||
| Interest rate swaps | — | (3) | |||||||||
| Total derivative contracts designated as hedging instruments | 26 | (3) | |||||||||
| Derivative Contracts Not Designated as Hedging Instruments: | |||||||||||
Foreign exchange forwards and swaps | 5 | — | |||||||||
| Total derivative contracts not designated as hedging instruments | 5 | — | |||||||||
| Gross fair value of derivative contracts | 31 | (3) | |||||||||
| Gross amounts offset in the Consolidated Balance Sheet | — | — | |||||||||
| Net Amounts Presented in the Consolidated Balance Sheet | $ | 31 | $ | (3) | |||||||
| December 31, 2021 | |||||||||||
| Derivative Contracts Designated as Hedging Instruments: | |||||||||||
| Crude oil collars | $ | 155 | $ | — | |||||||
| Interest rate swaps | 2 | — | |||||||||
| Total derivative contracts designated as hedging instruments | 157 | — | |||||||||
| Derivative Contracts Not Designated as Hedging Instruments: | |||||||||||
Foreign exchange forwards and swaps | — | (1) | |||||||||
| Total derivative contracts not designated as hedging instruments | — | (1) | |||||||||
| Gross fair value of derivative contracts | 157 | (1) | |||||||||
| Gross amounts offset in the Consolidated Balance Sheet | — | — | |||||||||
| Net Amounts Presented in the Consolidated Balance Sheet | $ | 157 | $ | (1) | |||||||
At June 30, 2022 and December 31, 2021, the fair value of our crude oil hedge contracts is presented within Other current assets in our Consolidated Balance Sheet. The fair value of our foreign exchange forwards and swaps is presented within Other current assets at June 30, 2022 and within Accrued liabilities at December 31, 2021 in our Consolidated Balance Sheet. The fair value of our interest rate swaps is presented within Other liabilities and deferred credits at June 30, 2022 and within Other assets at December 31, 2021 in our Consolidated Balance Sheet. All fair values in the table above are based on Level 2 inputs.
Derivative contracts designated as hedging instruments:
Crude oil derivatives designated as cash flow hedges: Crude oil hedging contracts decreased Sales and other operating revenues by $163 million and $255 million in the three and six months ended June 30, 2022, respectively. In the three and six months ended June 30, 2021, crude oil hedging contracts decreased Sales and other operating revenues by $64 million and $115 million, respectively. At June 30, 2022, pre-tax deferred losses in Accumulated other comprehensive income (loss) related to outstanding crude oil hedging contracts were $306 million ($306 million after income taxes), all of which will be reclassified into earnings during the remainder of 2022 as the hedged crude oil sales are recognized in earnings.
Interest rate swaps designated as fair value hedges: We had interest rate swaps with gross notional amounts totaling $100 million at June 30, 2022 and December 31, 2021, that convert interest payments from fixed to floating rates. Changes in the fair value of interest rate swaps and the hedged fixed-rate debt are recorded in Interest expense in the Statement of Consolidated Income. In the three and six months ended June 30, 2022, the change in fair value of interest rate swaps was a decrease of $1 million and $5 million, respectively, compared with a decrease of nil and $1 million in the three and six months ended June 30, 2021, respectively, with a corresponding adjustment in the carrying value of the hedged fixed-rate debt.
Derivative contracts not designated as hedging instruments:
Foreign exchange: Foreign exchange gains and losses, which are reported in Other, net in Revenues and non-operating income in the Statement of Consolidated Income, were losses of $3 million in both the three and six months ended June 30, 2022, compared with losses of $1 million and $2 million in the three and six months ended June 30, 2021, respectively. A component of foreign exchange gains and losses is the result of foreign exchange derivative contracts that are not designated as hedges, which amounted to net gains of $10 million and $14 million in the three and six months ended June 30, 2022, respectively, compared with net gains of $1 million and nil in the three and six months ended June 30, 2021, respectively.
16
PART I - FINANCIAL INFORMATION (CONT’D.)
HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
Fair Value Measurement:
At June 30, 2022, our total long-term debt, which was substantially comprised of fixed-rate debt instruments, had a carrying value of $8,332 million and a fair value of $8,297 million based on Level 2 inputs in the fair value measurement hierarchy. We also have short-term financial instruments, primarily cash equivalents, accounts receivable and accounts payable, for which the carrying value approximated fair value at June 30, 2022 and December 31, 2021.
14. Subsequent Events
In July 2022, Hess Corporation replaced its $3.5 billion revolving credit facility expiring in May 2024 with a new $3.25 billion revolving credit facility maturing in July 2027. Borrowings on the facility will bear interest based on the Secured Overnight Financing Rate (SOFR), plus the applicable margins specified in the credit agreement, which generally vary based on the credit rating of the Corporation's senior, unsecured, non-credit enhanced long-term debt. The new credit agreement has substantially similar terms to the prior agreement, including covenants.
In July 2022, HESM Opco amended and restated its credit agreement for its $1.4 billion senior secured syndicated credit facilities, consisting of a $1.0 billion revolving credit facility and a fully drawn $400 million term loan. The amended and restated credit agreement, among other things, extended the maturity date from December 2024 to July 2027, increased the accordion feature to up to an additional $750 million, which does not represent a lending commitment from the lenders, and replaced the London Interbank Offered Rate (LIBOR) as the benchmark interest rate with SOFR. The amended and restated credit agreement has substantially similar terms to the prior agreement, including commitment amounts, guarantees, secured collateral and covenants.
17
PART I - FINANCIAL INFORMATION (CONT'D.)
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
The following Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read together with the unaudited consolidated financial statements and accompanying footnotes for the quarter ended June 30, 2022 included under Item 1. Financial Statements of this Form 10-Q and the audited consolidated financial statements and related notes included in Item 8 of our Annual Report on Form 10-K for the year ended December 31, 2021. This discussion contains forward-looking statements that involve risks and uncertainties. Our actual results could differ materially from those discussed below. Factors that could cause or contribute to such differences include, but are not limited to, those discussed in Item 1A. Risk Factors of our Annual Report on Form 10-K for the year ended December 31, 2021.
Overview
Hess Corporation is a global E&P company engaged in exploration, development, production, transportation, purchase and sale of crude oil, natural gas liquids, and natural gas with production operations located in the United States, Guyana, the Malaysia/Thailand Joint Development Area (JDA), Malaysia, and Libya. We conduct exploration activities primarily offshore Guyana, in the U.S. Gulf of Mexico, and offshore Suriname and Canada. At the Stabroek Block (Hess 30%), offshore Guyana, we and our partners have discovered a significant resource base and are executing a multi-phased development of the Block. The Liza Phase 1 development reached its new production capacity of more than 140,000 gross bopd in June 2022 following the completion of production optimization work. The Liza Phase 2 development achieved first production in February 2022 and reached its production capacity of approximately 220,000 gross bopd in July. A third development, Payara, was sanctioned in the third quarter of 2020 and is expected to achieve first production in late 2023 with production capacity of approximately 220,000 gross bopd. A fourth development, Yellowtail, was sanctioned in April 2022 and is expected to achieve first production in 2025, with production capacity of approximately 250,000 gross bopd. We currently plan to have at least six floating production, storage and offloading vessels (FPSO) with an aggregate expected production capacity of more than 1 million gross bopd on the Stabroek Block in 2027, and the potential for up to ten FPSOs to develop the current discovered recoverable resource base.
Our Midstream operating segment provides fee-based services, including gathering, compressing and processing natural gas and fractionating natural gas liquids (NGL); gathering, terminaling, loading and transporting crude oil and NGL; storing and terminaling propane, and water handling services primarily in the Bakken shale play in the Williston Basin area of North Dakota.
In April 2022, Hess Midstream completed a public offering of approximately 10.2 million Hess Midstream LP Class A shares held by a subsidiary of Hess Corporation and an affiliate of GIP. We received net proceeds of $146 million from the public offering. Concurrent with the public offering, HESM Opco repurchased approximately 13.6 million HESM Opco Class B units from a subsidiary of Hess Corporation and an affiliate of GIP for $400 million, of which we received net proceeds of $200 million. HESM Opco issued $400 million in aggregate principal amount of 5.500% fixed-rate senior unsecured notes due 2030 in a private offering to repay borrowings under its revolving credit facility used to finance the repurchase. After giving effect to these transactions, we own an approximate 41% interest in Hess Midstream LP, on a consolidated basis.
2022 Highlights and Outlook
Following the startup of the Liza Phase 2 project in February 2022, we repaid the remaining $500 million outstanding under our $1.0 billion term loan, and in March 2022, we announced a 50% increase to our quarterly dividend on common stock. In June 2022, we repurchased approximately 1.8 million shares of common stock for $190 million. We intend to utilize the remaining amount authorized under our stock repurchase plan of $460 million by the end of the year. Excluding our Midstream Segment, we ended the second quarter of 2022 with approximately $2.16 billion in cash and cash equivalents.
Oil and gas net production in 2022, excluding Libya, is forecast to be approximately 320,000 barrels of oil equivalent per day (boepd). Our E&P capital and exploratory expenditures for 2022 are forecast to be approximately $2.7 billion. For the remainder of 2022, we have WTI put options for 90,000 bopd with an average monthly floor price of $60 per barrel and Brent put options for 60,000 bopd with an average monthly floor price of $65 per barrel.
Second Quarter Results
In the second quarter of 2022, net income was $667 million, compared with a net loss of $73 million in the second quarter of 2021. Excluding items affecting comparability of earnings between periods detailed on pages 25 and 27, adjusted net income was $74 million in the second quarter of 2021. The improvement in after-tax earnings in the second quarter of 2022 compared with the prior-year quarter adjusted results was primarily due to higher realized selling prices in the second quarter of 2022.
18
PART I - FINANCIAL INFORMATION (CONT'D.)
Exploration and Production Results
In the second quarter of 2022, E&P had net income of $723 million compared with a net loss of $25 million in the second quarter of 2021. Excluding items affecting comparability of earnings between periods, adjusted net income was $122 million in the second quarter of 2021. Total net production, excluding Libya, averaged 303,000 boepd in the second quarter 2022, compared with 307,000 boepd in the second quarter of 2021, or 302,000 boepd pro forma for assets sold. The average realized crude oil selling price, including hedging, was $99.16 per barrel in the second quarter of 2022, compared with $59.79 per barrel in the second quarter of 2021. The average realized NGL selling price in the second quarter of 2022 was $40.92 per barrel, compared with $23.12 per barrel in the prior-year quarter, while the average realized natural gas selling price was $6.45 per thousand cubic feet (mcf) in the second quarter of 2022, compared with $4.05 per mcf in the second quarter of 2021.
The following is an update of our ongoing E&P activities:
•In North Dakota, net production from the Bakken averaged 140,000 boepd for the second quarter of 2022 (2021 Q2: 159,000 boepd), reflecting unplanned production shut-ins caused by severe weather in April and May. We operated three rigs, drilled 20 wells, completed 19 wells, and brought 19 new wells online during the second quarter of 2022. In July, we added a fourth drilling rig. We forecast net production to be in the range of 155,000 boepd to 160,000 boepd for the third quarter, in the range of 160,000 boepd to 165,000 boepd for the fourth quarter, and in the range of 150,000 boepd to 155,000 boepd for the full year 2022.
•In the Gulf of Mexico, net production for the second quarter of 2022 averaged 29,000 boepd (2021 Q2: 52,000 boepd), primarily due to field decline and unplanned downtime at the Stampede and Penn State fields. We forecast Gulf of Mexico net production to be in the range of 25,000 boepd to 30,000 boepd for the third quarter and approximately 30,000 boepd for the full year 2022. In June, we completed drilling operations on the Huron prospect (Hess 40%) located at Green Canyon Block 69. Well results are being evaluated and an appraisal sidetrack is planned.
•At the Stabroek Block (Hess 30%), offshore Guyana, net production totaled 67,000 bopd for the second quarter of 2022 (2021 Q2: 26,000 bopd). The Liza Destiny FPSO reached its new production capacity of more than 140,000 gross bopd in June following the completion of production optimization work. Net production from the Liza Unity FPSO, which commenced in February, was 35,000 bopd in the second quarter of 2022, and reached its production capacity of 220,000 gross bopd in July. In the second quarter, we sold 6 one-million barrel cargos of crude oil from Guyana compared with 2 one-million barrel cargos in the prior year quarter. We forecast net production to be in the range of 90,000 bopd to 95,000 bopd for the third quarter and approximately 75,000 bopd for the full year 2022, which includes tax barrels of approximately 7,000 bopd and 6,000 bopd, respectively.
Beginning in the third quarter of 2022, we expect to use the remainder of the previously generated Guyana net operating loss carryforwards. As a result, we will start to incur a current income tax liability. Pursuant to the terms of the petroleum agreement, a portion of gross production from the block, separate from the contractors’ share of gross production for cost oil and profit oil, is used to satisfy the contractors’ income tax liability. This portion of gross production, referred to as “tax barrels”, will be included in our reported production volumes and revenue will be recognized.
The third development, Payara, will utilize the Prosperity FPSO with an expected capacity of 220,000 gross bopd, with first production expected in late 2023. The fourth development, Yellowtail, was sanctioned in April and will utilize the ONE GUYANA FPSO with an expected capacity of 250,000 gross bopd, with first production expected in 2025.
In July, two new discoveries were announced at Seabob and Kiru-Kiru on the Stabroek Block. The Seabob-1 well encountered 131 feet of high quality oil bearing sandstone reservoirs. The well was drilled in 4,660 feet of water and is located approximately 12 miles southeast of the Yellowtail Field. The Kiru-Kiru-1 well, where drilling operations are ongoing, has thus far encountered 98 feet of high quality hydrocarbon bearing sandstone reservoirs. The well is being drilled in 5,760 feet of water and is located approximately 3 miles southeast of the Cataback-1 discovery.
•In the Gulf of Thailand, net production from Block A-18 of the JDA averaged 41,000 boepd for the second quarter of 2022 (2021 Q2: 38,000 boepd), while net production from North Malay Basin, offshore Peninsular Malaysia, averaged 26,000 boepd for the second quarter of 2022 (2021 Q2: 28,000 boepd). Combined net production from JDA and North Malay Basin is forecast to be approximately 55,000 boepd in the third quarter and in the range of 60,000 boepd to 65,000 boepd for the full year 2022.
19
PART I - FINANCIAL INFORMATION (CONT'D.)
Consolidated Results of Operations
The after-tax income (loss) by major operating activity is summarized below:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In millions, except per share amounts) | |||||||||||||||||||||||
| Net Income (Loss) Attributable to Hess Corporation: | |||||||||||||||||||||||
| Exploration and Production | $ | 723 | $ | (25) | $ | 1,183 | $ | 283 | |||||||||||||||
| Midstream | 65 | 76 | 137 | 151 | |||||||||||||||||||
| Corporate, Interest and Other | (121) | (124) | (236) | (255) | |||||||||||||||||||
| Total | $ | 667 | $ | (73) | $ | 1,084 | $ | 179 | |||||||||||||||
| Net Income (Loss) Attributable to Hess Corporation Per Common Share: | |||||||||||||||||||||||
| Basic | $ | 2.15 | $ | (0.24) | $ | 3.50 | $ | 0.58 | |||||||||||||||
| Diluted | $ | 2.15 | $ | (0.24) | $ | 3.49 | $ | 0.58 | |||||||||||||||
Items Affecting Comparability of Earnings Between Periods
The following table summarizes, on an after-tax basis, items of income (expense) that are included in net income (loss) and affect comparability of earnings between periods:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In millions) | |||||||||||||||||||||||
| Items Affecting Comparability of Earnings Between Periods, After-Tax: | |||||||||||||||||||||||
| Exploration and Production | $ | — | $ | (147) | $ | — | $ | (147) | |||||||||||||||
| Midstream | — | — | — | — | |||||||||||||||||||
| Corporate, Interest and Other | — | — | 13 | — | |||||||||||||||||||
| Total | $ | — | $ | (147) | $ | 13 | $ | (147) | |||||||||||||||
The items in the table above are explained on pages 25 and 27.
Reconciliations of GAAP and non-GAAP measures
The following table reconciles reported net income (loss) attributable to Hess Corporation and adjusted net income (loss) attributable to Hess Corporation:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In millions) | |||||||||||||||||||||||
| Adjusted Net Income (Loss) Attributable to Hess Corporation: | |||||||||||||||||||||||
| Net income (loss) attributable to Hess Corporation | $ | 667 | $ | (73) | $ | 1,084 | $ | 179 | |||||||||||||||
| Less: Total items affecting comparability of earnings between periods, after-tax | — | (147) | 13 | (147) | |||||||||||||||||||
| Adjusted Net Income (Loss) Attributable to Hess Corporation | $ | 667 | $ | 74 | $ | 1,071 | $ | 326 | |||||||||||||||
The following table reconciles reported net cash provided by (used in) operating activities and net cash provided by (used in) operating activities before changes in operating assets and liabilities:
| Six Months Ended June 30, | |||||||||||
| 2022 | 2021 | ||||||||||
| (In millions) | |||||||||||
| Net cash provided by operating activities before changes in operating assets and liabilities: | |||||||||||
| Net cash provided by (used in) operating activities | $ | 1,353 | $ | 1,376 | |||||||
| Changes in operating assets and liabilities | 1,062 | 98 | |||||||||
| Net cash provided by (used in) operating activities before changes in operating assets and liabilities | $ | 2,415 | $ | 1,474 | |||||||
20
PART I - FINANCIAL INFORMATION (CONT'D.)
Consolidated Results of Operations (continued)
Adjusted net income (loss) attributable to Hess Corporation is a non-GAAP financial measure, which we define as reported net income (loss) attributable to Hess Corporation excluding items identified as affecting comparability of earnings between periods, which are summarized on pages 25 through 27. Management uses adjusted net income (loss) to evaluate the Corporation’s operating performance and believes that investors’ understanding of our performance is enhanced by disclosing this measure, which excludes certain items that management believes are not directly related to ongoing operations and are not indicative of future business trends and operations.
Net cash provided by (used in) operating activities before changes in operating assets and liabilities presented in this report is a non-GAAP measure, which we define as reported net cash provided by (used in) operating activities excluding changes in operating assets and liabilities. Management uses net cash provided by (used in) operating activities before changes in operating assets and liabilities to evaluate the Corporation’s ability to internally fund capital expenditures, pay dividends and service debt and believes that investors’ understanding of our ability to generate cash to fund these items is enhanced by disclosing this measure, which excludes working capital and other movements that may distort assessment of our performance between periods.
These measures are not, and should not be viewed as, substitutes for U.S. GAAP net income (loss) and net cash provided by (used in) operating activities.
In the following discussion and elsewhere in this report, the financial effects of certain transactions are disclosed on an after-tax basis. Management reviews segment earnings on an after-tax basis and uses after-tax amounts in its review of variances in segment earnings. Management believes that after-tax amounts are a preferable method of explaining variances in earnings, since they show the entire effect of a transaction rather than only the pre-tax amount. After-tax amounts are determined by applying the income tax rate in each tax jurisdiction to pre-tax amounts.
Comparison of Results
Exploration and Production
Following is a summarized income statement of our E&P operations:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In millions) | |||||||||||||||||||||||
| Revenues and Non-Operating Income | |||||||||||||||||||||||
| Sales and other operating revenues | $ | 2,955 | $ | 1,579 | $ | 5,268 | $ | 3,477 | |||||||||||||||
| Other, net | 26 | 14 | 59 | 30 | |||||||||||||||||||
| Total revenues and non-operating income | 2,981 | 1,593 | 5,327 | 3,507 | |||||||||||||||||||
| Costs and Expenses | |||||||||||||||||||||||
| Marketing, including purchased oil and gas | 858 | 343 | 1,561 | 885 | |||||||||||||||||||
| Operating costs and expenses | 291 | 254 | 542 | 462 | |||||||||||||||||||
| Production and severance taxes | 67 | 44 | 128 | 81 | |||||||||||||||||||
| Midstream tariffs | 296 | 270 | 583 | 532 | |||||||||||||||||||
| Exploration expenses, including dry holes and lease impairment | 33 | 48 | 76 | 81 | |||||||||||||||||||
| General and administrative expenses | 47 | 49 | 104 | 98 | |||||||||||||||||||
| Depreciation, depletion and amortization | 345 | 344 | 637 | 699 | |||||||||||||||||||
| Impairment and other | — | 147 | — | 147 | |||||||||||||||||||
| Total costs and expenses | 1,937 | 1,499 | 3,631 | 2,985 | |||||||||||||||||||
| Results of Operations Before Income Taxes | 1,044 | 94 | 1,696 | 522 | |||||||||||||||||||
| Provision (benefit) for income taxes | 321 | 119 | 513 | 239 | |||||||||||||||||||
| Net Income (Loss) Attributable to Hess Corporation | $ | 723 | $ | (25) | $ | 1,183 | $ | 283 | |||||||||||||||
The changes in E&P results are primarily attributable to changes in selling prices, production and sales volumes, marketing expenses, cash operating costs, Midstream tariffs, depreciation, depletion and amortization, exploration expenses and income taxes, as discussed below.
21
PART I - FINANCIAL INFORMATION (CONT'D.)
Consolidated Results of Operations (continued)
Selling Prices: Higher realized selling prices in the second quarter and first six months of 2022, increased after-tax earnings by approximately $675 million and $1,105 million, respectively, compared to the corresponding periods in 2021. Average selling prices were as follows:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| Average Selling Prices (a) | |||||||||||||||||||||||
| Crude Oil – Per Barrel (Including Hedging) | |||||||||||||||||||||||
| United States | |||||||||||||||||||||||
| North Dakota (b) | $ | 93.60 | $ | 56.75 | $ | 88.98 | $ | 49.35 | |||||||||||||||
| Offshore | 95.22 | 59.33 | 90.21 | 55.99 | |||||||||||||||||||
| Total United States | 93.96 | 57.52 | 89.25 | 51.00 | |||||||||||||||||||
| Guyana | 104.19 | 65.63 | 100.55 | 62.48 | |||||||||||||||||||
| Malaysia and JDA | 106.21 | 65.88 | 97.73 | 64.69 | |||||||||||||||||||
| Other (c) | 105.21 | 64.16 | 98.14 | 60.94 | |||||||||||||||||||
| Worldwide | 99.16 | 59.79 | 93.65 | 54.04 | |||||||||||||||||||
| Crude Oil – Per Barrel (Excluding Hedging) | |||||||||||||||||||||||
| United States | |||||||||||||||||||||||
| North Dakota (b) | $ | 106.01 | $ | 61.88 | $ | 98.46 | $ | 52.91 | |||||||||||||||
| Offshore | 107.58 | 64.42 | 99.58 | 60.24 | |||||||||||||||||||
| Total United States | 106.37 | 62.63 | 98.70 | 54.73 | |||||||||||||||||||
| Guyana | 112.57 | 68.44 | 109.06 | 64.48 | |||||||||||||||||||
| Malaysia and JDA | 106.21 | 65.88 | 97.73 | 64.69 | |||||||||||||||||||
| Other (c) | 114.93 | 68.08 | 108.06 | 63.88 | |||||||||||||||||||
| Worldwide | 109.51 | 64.27 | 102.65 | 57.36 | |||||||||||||||||||
| Natural Gas Liquids – Per Barrel | |||||||||||||||||||||||
| United States | |||||||||||||||||||||||
| North Dakota | $ | 40.96 | $ | 23.23 | $ | 40.40 | $ | 26.65 | |||||||||||||||
| Offshore | 39.88 | 21.84 | 38.68 | 21.55 | |||||||||||||||||||
| Worldwide | 40.92 | 23.12 | 40.33 | 26.20 | |||||||||||||||||||
| Natural Gas – Per Mcf | |||||||||||||||||||||||
| United States | |||||||||||||||||||||||
| North Dakota | $ | 6.89 | $ | 2.40 | $ | 5.57 | $ | 4.06 | |||||||||||||||
| Offshore | 7.63 | 2.35 | 6.02 | 2.66 | |||||||||||||||||||
| Total United States | 7.06 | 2.38 | 5.67 | 3.56 | |||||||||||||||||||
| Malaysia and JDA | 6.18 | 5.22 | 6.00 | 5.13 | |||||||||||||||||||
| Other (c) | 5.36 | 2.96 | 5.07 | 2.82 | |||||||||||||||||||
| Worldwide | 6.45 | 4.05 | 5.87 | 4.47 | |||||||||||||||||||
(a)Selling prices in the United States and Guyana are adjusted for certain processing and distribution fees included in Marketing expenses. Excluding these fees worldwide selling prices for the second quarter of 2022 would be $102.80 (Q2 2021: $62.45) per barrel for crude oil (including hedging), $113.15 (Q2 2021: $66.93) per barrel for crude oil (excluding hedging), $41.36 (Q2 2021: $23.35) per barrel for NGLs and $6.55 (Q2 2021: $4.17) per mcf for natural gas. Excluding these fees worldwide selling prices for the first six months of 2022 would be $97.63 (2021: $58.97) per barrel for crude oil (including hedging), $106.63 (2021: $62.29) per barrel for crude oil (excluding hedging), $40.65 (2021: $26.43) per barrel for NGLs and $5.98 (2021: $4.59) per mcf for natural gas.
(b)Excluding the two very large crude carrier (VLCC) cargo sales totaling 4.2 million barrels in the first quarter of 2021, the North Dakota crude oil price for the first six months of 2021 excluding hedging was $57.39 per barrel and $53.08 per barrel including hedging.
(c)Other includes Libya and our former interests in Denmark, which were sold in the third quarter of 2021.
Crude oil hedging activities were a net loss of $163 million and $255 million before and after income taxes in the second quarter and first six months of 2022, respectively, and a net loss of $64 million and $115 million before and after income taxes in the second quarter and first six months of 2021, respectively. For the remainder of 2022, we have hedged 90,000 bopd with WTI put options with an average monthly floor price of $60 per barrel, and 60,000 bopd with Brent put options with an average monthly floor price of $65 per barrel. We expect noncash premium amortization, which will be reflected in realized selling prices, to reduce our third and fourth quarter results each by approximately $165 million.
22
PART I - FINANCIAL INFORMATION (CONT'D.)
Consolidated Results of Operations (continued)
Production Volumes: Our daily worldwide net production was as follows:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In thousands) | |||||||||||||||||||||||
| Crude Oil – Barrels | |||||||||||||||||||||||
| United States | |||||||||||||||||||||||
| North Dakota | 68 | 79 | 73 | 82 | |||||||||||||||||||
| Offshore | 20 | 33 | 20 | 34 | |||||||||||||||||||
| Total United States | 88 | 112 | 93 | 116 | |||||||||||||||||||
| Guyana | 67 | 26 | 49 | 29 | |||||||||||||||||||
| Malaysia and JDA | 4 | 4 | 3 | 4 | |||||||||||||||||||
| Other (a) | 17 | 24 | 18 | 23 | |||||||||||||||||||
| Total | 176 | 166 | 163 | 172 | |||||||||||||||||||
| Natural Gas Liquids – Barrels | |||||||||||||||||||||||
| United States | |||||||||||||||||||||||
| North Dakota | 47 | 52 | 48 | 50 | |||||||||||||||||||
| Offshore | 2 | 5 | 2 | 5 | |||||||||||||||||||
| Total United States | 49 | 57 | 50 | 55 | |||||||||||||||||||
| Natural Gas – Mcf | |||||||||||||||||||||||
| United States | |||||||||||||||||||||||
| North Dakota | 147 | 167 | 152 | 159 | |||||||||||||||||||
| Offshore | 41 | 85 | 41 | 90 | |||||||||||||||||||
| Total United States | 188 | 252 | 193 | 249 | |||||||||||||||||||
| Malaysia and JDA | 381 | 371 | 373 | 366 | |||||||||||||||||||
| Other (a) | 11 | 9 | 12 | 10 | |||||||||||||||||||
| Total | 580 | 632 | 578 | 625 | |||||||||||||||||||
| Barrels of Oil Equivalent (b) | 322 | 328 | 309 | 331 | |||||||||||||||||||
| Crude oil and natural gas liquids as a share of total production | 70 | % | 68 | % | 69 | % | 69 | % | |||||||||||||||
(a)Other includes Libya and our former interests in Denmark, which were sold in the third quarter of 2021. Net production from Libya was 19,000 boepd and 20,000 boepd in the second quarter and first six months of 2022, respectively, compared with 21,000 boepd and 20,000 boepd in the second quarter and first six months of 2021, respectively. Net production from Denmark was 4,000 boepd and 5,000 boepd in the second quarter and first six months of 2021, respectively.
(b)Reflects natural gas production converted based on relative energy content (six mcf equals one barrel). Barrel of oil equivalence does not necessarily result in price equivalence as the equivalent price of natural gas on a barrel of oil equivalent basis has been substantially lower than the corresponding price for crude oil over the recent past. In addition, NGLs do not sell at prices equivalent to crude oil. See the average selling prices in the table on page 22.
We forecast net production, excluding Libya, to be in the range of 330,000 boepd to 335,000 boepd for the third quarter, in the range of 365,000 boepd to 370,000 boepd for the fourth quarter, and approximately 320,000 boepd for the full year 2022.
United States: North Dakota net production was lower in the second quarter and first six months of 2022, compared to the corresponding periods in 2021, primarily due to unplanned production shut-ins caused by severe weather, and the sale of our Little Knife and Murphy Creek nonstrategic acreage interests in the second quarter of 2021. Total offshore net production was lower in the second quarter and first six months of 2022, compared to the corresponding periods in 2021, primarily due to field decline and unplanned downtime at the Stampede, Penn State, and Llano fields.
International: Net production in Guyana was higher in the second quarter and first six months of 2022, compared to the corresponding periods in 2021, due to production ramp up from the Liza Unity FPSO, which commenced production in February 2022. Net production from the Liza Unity FPSO averaged 35,000 bopd and 21,000 bopd in the second quarter and first six months of 2022, respectively.
23
PART I - FINANCIAL INFORMATION (CONT'D.)
Consolidated Results of Operations (continued)
Sales Volumes: Lower sales volumes in the second quarter and first six months of 2022 reduced after-tax earnings by approximately $30 million and $290 million, respectively, compared to the corresponding periods in 2021. Worldwide sales volumes from Hess net production, which excludes sales volumes of crude oil, NGLs and natural gas purchased from third parties, were as follows:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In thousands) | |||||||||||||||||||||||
| Crude oil – barrels (a) | 15,763 | 14,293 | 28,343 | 34,688 | |||||||||||||||||||
| Natural gas liquids – barrels | 4,180 | 5,142 | 8,719 | 9,944 | |||||||||||||||||||
| Natural gas – mcf | 52,811 | 57,557 | 104,709 | 113,070 | |||||||||||||||||||
| Barrels of Oil Equivalent (b) | 28,745 | 29,028 | 54,514 | 63,477 | |||||||||||||||||||
| Crude oil – barrels per day | 173 | 157 | 157 | 192 | |||||||||||||||||||
| Natural gas liquids – barrels per day | 46 | 57 | 48 | 55 | |||||||||||||||||||
| Natural gas – mcf per day | 580 | 632 | 578 | 625 | |||||||||||||||||||
| Barrels of Oil Equivalent Per Day (b) | 316 | 319 | 301 | 351 | |||||||||||||||||||
(a)Sales volumes for the first six months of 2021 include 4.2 million barrels that were stored on VLCCs at December 31, 2020 and sold in the first quarter of 2021.
(b)Reflects natural gas production converted based on relative energy content (six mcf equals one barrel). Barrel of oil equivalence does not necessarily result in price equivalence as the equivalent price of natural gas on a barrel of oil equivalent basis has been substantially lower than the corresponding price for crude oil over the recent past. In addition, NGLs do not sell at prices equivalent to crude oil. See the average selling prices in the table on page 22.
Marketing, including Purchased Oil and Gas: Marketing expense is mainly comprised of costs to purchase crude oil, NGL and natural gas from our partners in Hess operated wells or other third parties, primarily in the United States, and transportation and other distribution costs for U.S. marketing activities. Marketing expense was higher in the second quarter and first six months of 2022, compared with the corresponding periods in 2021, primarily due to higher third party crude oil volumes purchased and higher prices paid for purchased volumes. First quarter 2021 marketing expense included $173 million related to the cost of 4.2 million barrels of crude oil produced and stored on two VLCCs in 2020 that were sold in the first quarter of 2021.
Cash Operating Costs: Cash operating costs consist of operating costs and expenses, production and severance taxes and E&P general and administrative expenses. Cash operating costs increased in the second quarter and first six months of 2022 compared with the corresponding periods in 2021, primarily due to the production ramp up in Guyana from the Liza Unity FPSO, which commenced production in February 2022, and higher production and severance taxes associated with higher crude oil prices. On a per-unit basis, cash operating costs in the second quarter and first six months of 2022 reflect the higher costs and the impact of the lower production volumes compared with the corresponding periods in 2021.
Midstream Tariffs Expense: Tariffs expense increased in the second quarter and first six months of 2022, compared with the corresponding periods in 2021, primarily due to higher minimum volume commitments. We estimate Midstream tariffs expense to be in the range of $305 million to $315 million in the third quarter of 2022 and in the range of $1,190 million to $1,215 million for the full year 2022.
Depreciation, Depletion and Amortization (DD&A): DD&A expense was lower in the first six months of 2022, compared with the corresponding period in 2021, primarily due to lower production volumes and lower DD&A rates resulting from year-end 2021 additions to proved reserves.
Unit Costs: Unit cost per boe information is based on total net production volumes. Actual and forecast unit costs per boe are as follows:
| Actual | Forecast range (a) | |||||||||||||||||||||||||||||||||||||||||||||||||
| Three Months Ended June 30, | Six Months Ended June 30, | Three Months Ended September 30, | Twelve Months Ended December 31, | |||||||||||||||||||||||||||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | 2022 | 2022 | |||||||||||||||||||||||||||||||||||||||||||||
| Cash operating costs (b) | $ | 13.90 | $ | 11.63 | $ | 13.84 | $ | 10.72 | $ | 14.00 | — | $ | 14.50 | $ | 13.50 | — | $ | 14.00 | ||||||||||||||||||||||||||||||||
| DD&A (c) | 11.79 | 11.55 | 11.39 | 11.69 | 13.00 | — | 13.50 | 12.50 | — | 13.00 | ||||||||||||||||||||||||||||||||||||||||
| Total Production Unit Costs | $ | 25.69 | $ | 23.18 | $ | 25.23 | $ | 22.41 | $ | 27.00 | — | $ | 28.00 | $ | 26.00 | — | $ | 27.00 | ||||||||||||||||||||||||||||||||
(a)Forecast information excludes any contribution from Libya.
(b)Cash operating costs per boe, excluding Libya, were $14.56 and $14.55 in the second quarter and first six months of 2022, respectively, compared with $12.16 and $11.18 in the second quarter and first six months of 2021, respectively.
(c)DD&A per boe, excluding Libya, was $12.34 and $11.96 in the second quarter and first six months of 2022, respectively, compared with $12.13 and $12.25 in the second quarter and first six months of 2021, respectively.
24
PART I - FINANCIAL INFORMATION (CONT'D.)
Consolidated Results of Operations (continued)
Exploration Expenses: Exploration expenses were as follows:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In millions) | |||||||||||||||||||||||
| Exploratory dry hole costs (a) | $ | — | $ | 9 | $ | — | $ | 9 | |||||||||||||||
| Exploration lease and other impairment | 4 | 6 | 10 | 10 | |||||||||||||||||||
| Geological and geophysical expense and exploration overhead | 29 | 33 | 66 | 62 | |||||||||||||||||||
| Total Exploration Expense | $ | 33 | $ | 48 | $ | 76 | $ | 81 | |||||||||||||||
(a)The second quarter 2021 dry hole costs primarily relates to the Koebi-1 exploration well, offshore Guyana.
Exploration expenses, excluding dry hole expense, are estimated to be in the range of $35 million to $40 million in the third quarter of 2022 and in the range of $160 million to $170 million for the full year 2022.
Income Taxes:
E&P income tax expense was $321 million and $513 million in the second quarter and first six months of 2022, respectively, compared with $119 million and $239 million in the second quarter and first six months of 2021, respectively. The increase in income tax expense, compared with the corresponding periods in 2021, was primarily due to higher pre-tax income in Libya and Guyana. Income tax expense from Libya operations was $177 million and $331 million in the second quarter and first six months of 2022, respectively, compared with $96 million and $176 million in the second quarter and first six months of 2021, respectively. We are generally not recognizing deferred tax benefit or expense in certain countries, primarily the United States (non-Midstream), and Malaysia, while we maintain valuation allowances against net deferred tax assets in these jurisdictions in accordance with the requirements of U.S. accounting standards. Excluding items affecting comparability of earnings between periods and Libyan operations, E&P income tax expense is expected to be in the range of $170 million to $180 million for the third quarter of 2022 and in the range of $540 million to $550 million for the full year 2022.
Items Affecting Comparability of Earnings Between Periods:
In the second quarter of 2021, we recorded a charge of $147 million ($147 million after income taxes) in connection with abandonment obligations in the West Delta Field in the Gulf of Mexico. These abandonment obligations were assigned to us as a former owner after they were discharged from Fieldwood as part of Fieldwood's approved bankruptcy plan. See Note 8, Impairment and Other in the Notes to Consolidated Financial Statements.
25
PART I - FINANCIAL INFORMATION (CONT'D.)
Consolidated Results of Operations (continued)
Midstream
Following is a summarized income statement for our Midstream operations:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In millions) | |||||||||||||||||||||||
| Revenues and Non-Operating Income | |||||||||||||||||||||||
| Sales and other operating revenues | $ | 314 | $ | 294 | $ | 626 | $ | 583 | |||||||||||||||
| Other, net | — | 3 | 1 | 6 | |||||||||||||||||||
| Total revenues and non-operating income | 314 | 297 | 627 | 589 | |||||||||||||||||||
| Costs and Expenses | |||||||||||||||||||||||
| Operating costs and expenses | 68 | 64 | 134 | 124 | |||||||||||||||||||
| General and administrative expenses | 5 | 4 | 11 | 11 | |||||||||||||||||||
| Interest expense | 38 | 23 | 69 | 46 | |||||||||||||||||||
| Depreciation, depletion and amortization | 44 | 41 | 89 | 81 | |||||||||||||||||||
| Total costs and expenses | 155 | 132 | 303 | 262 | |||||||||||||||||||
| Results of Operations Before Income Taxes | 159 | 165 | 324 | 327 | |||||||||||||||||||
| Provision (benefit) for income taxes | 7 | 3 | 12 | 6 | |||||||||||||||||||
| Net Income (Loss) | 152 | 162 | 312 | 321 | |||||||||||||||||||
| Less: Net income (loss) attributable to noncontrolling interests | 87 | 86 | 175 | 170 | |||||||||||||||||||
| Net Income (Loss) Attributable to Hess Corporation | $ | 65 | $ | 76 | $ | 137 | $ | 151 | |||||||||||||||
Sales and other operating revenues for the second quarter and first six months of 2022 increased, compared to the corresponding periods in 2021, primarily associated with higher minimum volume commitments.
Operating costs and expenses for the second quarter and first six months of 2022 increased, compared to the corresponding periods in 2021, primarily due to higher operating expenses on expanding gathering infrastructure. DD&A expense for the second quarter and first six months of 2022 increased, compared to the corresponding periods in 2021, primarily due to additional assets placed in service. Interest expense for the second quarter and first six months of 2022 increased, compared to the corresponding periods in 2021, primarily due to the $400 million of 5.500% fixed-rate senior unsecured notes issued in April 2022 and the $750 million of 4.250% fixed-rate senior unsecured notes issued in August 2021.
Excluding items affecting comparability of earnings, net income attributable to Hess Corporation from the Midstream segment is estimated to be in the range of $60 million to $65 million in the third quarter of 2022 and in the range of $265 million to $275 million for the full year 2022.
Corporate, Interest and Other
The following table summarizes Corporate, Interest and Other expenses:
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| (In millions) | |||||||||||||||||||||||
| Corporate and other expenses | $ | 38 | $ | 29 | $ | 74 | $ | 66 | |||||||||||||||
| Interest expense | 86 | 95 | 178 | 189 | |||||||||||||||||||
| Less: Capitalized interest | (3) | — | (3) | — | |||||||||||||||||||
| Interest expense, net | 83 | 95 | 175 | 189 | |||||||||||||||||||
| Corporate, Interest and Other expenses before income taxes | 121 | 124 | 249 | 255 | |||||||||||||||||||
| Provision (benefit) for income taxes | — | — | — | — | |||||||||||||||||||
| Net Corporate, Interest and Other expenses after income taxes | 121 | 124 | 249 | 255 | |||||||||||||||||||
| Items affecting comparability of earnings between periods, after-tax | — | — | (13) | — | |||||||||||||||||||
| Total Corporate, Interest and Other Expenses after income taxes | $ | 121 | $ | 124 | $ | 236 | $ | 255 | |||||||||||||||
Corporate and other expenses were higher in the second quarter and first six months of 2022, compared to the corresponding periods in 2021, primarily due to higher legal and professional fees.
26
PART I - FINANCIAL INFORMATION (CONT'D.)
Consolidated Results of Operations (continued)
Interest expense, net was lower in the second quarter and first six months of 2022, compared to the corresponding periods in 2021, due to the repayment of the Corporation's $1.0 billion term loan and capitalized interest that commenced upon sanctioning of the Yellowtail development in Guyana in April 2022.
Third quarter 2022 corporate expenses are expected to be approximately $40 million and approximately $150 million for the full year 2022. Interest expense, net is expected to be approximately $85 million for the third quarter and in the range of $345 million to $350 million for the full year 2022.
Items Affecting Comparability of Earnings Between Periods:
In the first quarter of 2022, results included a pre-tax gain of $22 million ($22 million after income taxes) associated with the sale of property and a charge of $9 million ($9 million after income taxes) for litigation related to our former downstream business.
Other Items Potentially Affecting Future Results
Our future results may be impacted by a variety of factors, including but not limited to, volatility in the selling prices of crude oil, NGLs and natural gas, reserve and production changes, asset sales, impairment charges and exploration expenses, industry cost inflation and/or deflation, changes in foreign exchange rates and income tax rates, changes in deferred tax asset valuation allowances, the effects of weather, crude oil storage capacity, political risk, environmental risk and catastrophic risk, including risks associated with the global COVID-19 pandemic (COVID-19). For a more comprehensive description of the risks that may affect our business, see Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2021.
Liquidity and Capital Resources
The following table sets forth certain relevant measures of our liquidity and capital resources:
| June 30, 2022 | December 31, 2021 | ||||||||||
| (In millions, except ratio) | |||||||||||
| Cash and cash equivalents (a) | $ | 2,159 | $ | 2,713 | |||||||
| Current portion of long-term debt | — | 517 | |||||||||
| Total debt (b) | 8,332 | 8,458 | |||||||||
| Total equity | 7,758 | 7,026 | |||||||||
| Debt to capitalization ratio for debt covenants (c) | 37.9 | % | 42.3 | % | |||||||
(a)Includes $3 million of cash attributable to our Midstream segment at June 30, 2022 (December 31, 2021: $2 million) of which $2 million is held by Hess Midstream LP at June 30, 2022 (December 31, 2021: $2 million).
(b)At June 30, 2022, includes $2,937 million of debt outstanding from our Midstream segment (December 31, 2021: $2,564 million) that is non-recourse to Hess Corporation.
(c)Total Consolidated Debt of Hess Corporation (including finance leases and excluding Midstream non-recourse debt) as a percentage of Total Capitalization of Hess Corporation as defined under Hess Corporation's revolving credit facility financial covenants. Total Capitalization excludes the impact of noncash impairment charges and non-controlling interests.
Cash Flows
The following table summarizes our cash flows:
| Six Months Ended June 30, | |||||||||||
| 2022 | 2021 | ||||||||||
| (In millions) | |||||||||||
| Net cash provided by (used in): | |||||||||||
| Operating activities | $ | 1,353 | $ | 1,376 | |||||||
| Investing activities | (1,181) | (445) | |||||||||
| Financing activities | (726) | (240) | |||||||||
| Net Increase (Decrease) in Cash and Cash Equivalents | $ | (554) | $ | 691 | |||||||
27
PART I - FINANCIAL INFORMATION (CONT'D.)
Liquidity and Capital Resources (continued)
Operating activities: Net cash provided by operating activities was $1,353 million in the first six months of 2022, compared with $1,376 million in the first six months of 2021. Net cash provided by operating activities before changes in operating assets and liabilities was $2,415 million in the first six months of 2022, compared with $1,474 million in the first six months of 2021 primarily due to higher realized selling prices. During the first six months of 2022, changes in operating assets and liabilities reduced net cash provided by operating activities by $1,062 million (2021: $98 million) reflecting payments made for previously accrued Libyan income tax and royalties of approximately $470 million for the period December 2020 through November 2021, premiums paid of $325 million to remove the ceiling price on outstanding WTI and Brent crude oil price collars effective April 1, 2022, and an increase in accounts receivable due to higher crude oil prices.
Investing activities: Additions to property, plant and equipment of $1,209 million in the first six months of 2022 were up $469 million compared with the corresponding period in 2021. The increase is primarily due to higher drilling and development activities in Guyana, the Bakken, Malaysia and JDA, and the Gulf of Mexico. Proceeds from asset sales in the first six months of 2022 were $28 million and $297 million in the first six months of 2021.
The following table reconciles capital expenditures incurred on an accrual basis to Additions to property, plant and equipment:
| Six Months Ended June 30, | |||||||||||
| 2022 | 2021 | ||||||||||
| (In millions) | |||||||||||
| Additions to property, plant and equipment - E&P: | |||||||||||
| Capital expenditures incurred - E&P | $ | (1,136) | $ | (676) | |||||||
| Increase (decrease) in related liabilities | 38 | (11) | |||||||||
| Additions to property, plant and equipment - E&P | $ | (1,098) | $ | (687) | |||||||
| Additions to property, plant and equipment - Midstream: | |||||||||||
| Capital expenditures incurred - Midstream | $ | (109) | $ | (70) | |||||||
| Increase (decrease) in related liabilities | (2) | 17 | |||||||||
| Additions to property, plant and equipment - Midstream | $ | (111) | $ | (53) | |||||||
Financing activities:
In the first six months of 2022, we repurchased $190 million of common stock and paid common stock dividends of $235 million (2021: $157 million) reflecting a 50% increase in our dividend on common stock. In the first six months of 2022, we repaid the remaining $500 million outstanding under our $1.0 billion term loan, previously scheduled to mature in March 2023.
In the second quarter of 2022, we received net proceeds of $146 million from the public offering of approximately 5.1 million Hess-owned Class A shares in Hess Midstream LP, and in the first quarter of 2021, we received net proceeds of $70 million from the public offering of approximately 3.5 million Hess-owned Class A shares in Hess Midstream LP. Borrowings in 2022 resulted from the issuance by HESM Opco of $400 million of 5.500% fixed-rate senior unsecured notes due 2030. Net cash outflows to noncontrolling interests were $351 million in the first six months of 2022 (2021: $137 million) which included $200 million paid to GIP for the repurchase by HESM Opco of approximately 6.8 million GIP-owned Class B units.
Future Capital Requirements and Resources
At June 30, 2022, we had $2.16 billion in cash and cash equivalents, excluding Midstream, and total liquidity, including available committed credit facilities, of approximately $5.73 billion. In June 2022, we repurchased $190 million (1.8 million shares) of our common stock. We intend to utilize the remaining amount authorized under our stock repurchase plan of $460 million by the end of the year. In March 2022, we announced a 50% increase in our dividend on common stock. As we become increasingly free cash flow positive, we plan to return up to 75% of our annual adjusted free cash flow to shareholders through further dividend increases and/or common stock repurchases.
In 2022, based on current forward strip crude oil prices, we expect cash flow from operating activities and cash and cash equivalents at June 30, 2022, will be sufficient to fund our capital investment and capital return programs. Depending on market conditions, we may take any of the following steps, or a combination thereof, to improve our liquidity and financial position: reduce the planned capital program and other cash outlays, including dividends, pursue asset sales, borrow against our committed revolving credit facility, or issue debt or equity securities.
28
PART I - FINANCIAL INFORMATION (CONT'D.)
Liquidity and Capital Resources (continued)
The table below summarizes the capacity, usage, and available capacity for borrowings and letters of credit under committed and uncommitted credit facilities at June 30, 2022:
| Expiration Date | Capacity | Borrowings | Letters of Credit Issued | Total Used | Available Capacity | ||||||||||||||||||||||||||||||
| (In millions) | |||||||||||||||||||||||||||||||||||
| Hess Corporation | |||||||||||||||||||||||||||||||||||
| Revolving credit facility | May 2024 | $ | 3,500 | $ | — | $ | — | $ | — | $ | 3,500 | ||||||||||||||||||||||||
| Committed lines | Various (a) | 100 | — | 29 | 29 | 71 | |||||||||||||||||||||||||||||
| Uncommitted lines | Various (a) | 121 | — | 121 | 121 | — | |||||||||||||||||||||||||||||
| Total - Hess Corporation | $ | 3,721 | $ | — | $ | 150 | $ | 150 | $ | 3,571 | |||||||||||||||||||||||||
| Midstream | |||||||||||||||||||||||||||||||||||
| Revolving credit facility (b) | December 2024 | $ | 1,000 | $ | 91 | $ | — | $ | 91 | $ | 909 | ||||||||||||||||||||||||
| Total - Midstream | $ | 1,000 | $ | 91 | $ | — | $ | 91 | $ | 909 | |||||||||||||||||||||||||
(a)Committed and uncommitted lines have expiration dates through 2022.
(b)This credit facility may only be utilized by HESM Opco and is non-recourse to Hess Corporation.
Hess Corporation:
At June 30, 2022, we had a $3.5 billion revolving credit facility expiring in May 2024. The revolving credit facility can be used for borrowings and letters of credit. Borrowings on the facility will generally bear interest at 1.40% above LIBOR, though the interest rate is subject to adjustment if the Corporation’s credit rating changes. The revolving credit facility is subject to customary representations, warranties, customary events of default and covenants, including a financial covenant limiting the ratio of Total Consolidated Debt to Total Capitalization of the Corporation and its consolidated subsidiaries to 65%, and a financial covenant limiting the ratio of secured debt to Consolidated Net Tangible Assets of the Corporation and its consolidated subsidiaries to 15% (as these capitalized terms are defined in the credit agreement for the revolving credit facility). The indentures for the Corporation's fixed-rate public notes limit the ratio of secured debt to Consolidated Net Tangible Assets (as that term is defined in the indentures) to 15%. As of June 30, 2022, Hess Corporation was in compliance with these financial covenants.
In July 2022, we replaced our $3.5 billion revolving credit facility expiring in May 2024 with a new $3.25 billion revolving credit facility maturing in July 2027. See Note 14, Subsequent Events in the Notes to Consolidated Financial Statements.
All three major credit rating agencies that rate our debt have assigned an investment grade credit rating. In June 2022, Moody’s Investors Service upgraded the senior unsecured ratings of Hess Corporation from Ba1 to Baa3 with a stable outlook. In March 2022, Standard and Poor’s Ratings Services affirmed our credit rating at BBB- with stable outlook. Fitch Ratings affirmed our BBB- credit rating and revised the outlook from stable to positive in August 2021.
We have a shelf registration under which we may issue additional debt securities, warrants, common stock or preferred stock.
Midstream:
At June 30, 2022, HESM Opco, a consolidated subsidiary of Hess Midstream LP, had $1.4 billion of senior secured syndicated credit facilities maturing in December 2024, consisting of a $1.0 billion revolving credit facility and a fully drawn $400 million term loan. The revolving credit facility can be used for borrowings and letters of credit to fund HESM Opco’s operating activities, capital expenditures, distributions and for other general corporate purposes. Borrowings under the five year term loan A facility will generally bear interest at LIBOR plus an applicable margin ranging from 1.55% to 2.50%, while the applicable margin for the five year syndicated revolving credit facility ranges from 1.275% to 2.000%. Pricing levels for the facility fee and interest-rate margins are based on HESM Opco’s ratio of total debt to EBITDA (as defined in the credit facilities). If HESM Opco obtains an investment grade credit rating, the pricing levels will be based on HESM Opco’s credit ratings in effect from time to time. The credit facilities contain covenants that require HESM Opco to maintain a ratio of total debt to EBITDA (as defined in the credit facilities) for the prior four fiscal quarters of not greater than 5.00 to 1.00 as of the last day of each fiscal quarter (5.50 to 1.00 during the specified period following certain acquisitions) and, prior to HESM Opco obtaining an investment grade credit rating, a ratio of secured debt to EBITDA for the prior four fiscal quarters of not greater than 4.00 to 1.00 as of the last day of each fiscal quarter. HESM Opco was in compliance with these financial covenants at June 30, 2022. The credit facilities are secured by first-priority perfected liens on substantially all of the assets of HESM Opco and its direct and indirect wholly owned material domestic subsidiaries, including equity interests directly owned by such entities, subject to certain customary exclusions. At June 30, 2022, borrowings of $91 million were drawn under HESM Opco’s revolving credit facility, and borrowings of $380 million, excluding deferred issuance costs, were drawn under HESM Opco’s term loan A facility. Borrowings under these credit facilities are non-recourse to Hess Corporation.
In July 2022, HESM Opco amended and restated the credit agreement for its senior secured syndicated credit facilities. See Note 14, Subsequent Events in the Notes to Consolidated Financial Statements.
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PART I - FINANCIAL INFORMATION (CONT'D.)
Market Risk Disclosures
We are exposed in the normal course of business to commodity risks related to changes in the prices of crude oil and natural gas, as well as changes in interest rates and foreign currency values. See Note 13, Financial Risk Management Activities, in the Notes to Consolidated Financial Statements.
We have outstanding foreign exchange contracts with notional amounts totaling $157 million at June 30, 2022 that are used to reduce our exposure to fluctuating foreign exchange rates for various currencies. A 10% strengthening or weakening in the U.S. Dollar exchange rate is estimated to be a gain or loss, respectively, of approximately $15 million at June 30, 2022.
At June 30, 2022, consolidated long-term debt, which was substantially comprised of fixed-rate instruments, had a carrying value of $8,332 million and a fair value of $8,297 million. A 15% increase or decrease in interest rates would decrease or increase the fair value of debt by approximately $460 million or $555 million, respectively. Any changes in interest rates do not impact our cash outflows associated with fixed-rate interest payments or settlement of debt principal, unless a debt instrument is repurchased prior to maturity.
At June 30, 2022, we have WTI put options with an average monthly floor price of $60 per barrel for 90,000 bopd, and Brent put options with an average monthly floor price of $65 per barrel for 60,000 bopd. As of June 30, 2022, an assumed 10% increase in the forward WTI and Brent crude oil prices used in determining the fair value of our put options would reduce the fair value of these derivative instruments by approximately $5 million, while an assumed 10% decrease in the same crude oil prices would increase the fair value of these derivative instruments by approximately $10 million.
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PART I - FINANCIAL INFORMATION (CONT'D.)
Cautionary Note Regarding Forward-Looking Statements
This Quarterly Report on Form 10-Q, including information incorporated by reference herein, contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Words such as “anticipate,” “estimate,” “expect,” “forecast,” “guidance,” “could,” “may,” “should,” “would,” “believe,” “intend,” “project,” “plan,” “predict,” “will,” “target” and similar expressions identify forward-looking statements, which are not historical in nature. Our forward-looking statements may include, without limitation: our future financial and operational results; our business strategy; estimates of our crude oil and natural gas reserves and levels of production; benchmark prices of crude oil, natural gas liquids and natural gas and our associated realized price differentials; our projected budget and capital and exploratory expenditures; expected timing and completion of our development projects; and future economic and market conditions in the oil and gas industry.
Forward-looking statements are based on our current understanding, assessments, estimates and projections of relevant factors and reasonable assumptions about the future. Forward-looking statements are subject to certain known and unknown risks and uncertainties that could cause actual results to differ materially from our historical experience and our current projections or expectations of future results expressed or implied by these forward-looking statements. The following important factors could cause actual results to differ materially from those in our forward-looking statements:
•fluctuations in market prices of crude oil, natural gas liquids and natural gas and competition in the oil and gas exploration and production industry, including as a result of COVID-19;
•reduced demand for our products, including due to COVID-19, perceptions regarding the oil and gas industry, competing or alternative energy products and political conditions and events;
•potential failures or delays in increasing oil and gas reserves, including as a result of unsuccessful exploration activity, drilling risks and unforeseen reservoir conditions, and in achieving expected production levels;
•changes in tax, property, contract and other laws, regulations and governmental actions applicable to our business, including legislative and regulatory initiatives regarding environmental concerns, such as measures to limit greenhouse gas emissions and flaring, fracking bans as well as restrictions on oil and gas leases;
•operational changes and expenditures due to climate change and sustainability related initiatives;
•disruption or interruption of our operations due to catastrophic events, such as accidents, severe weather, geological events, shortages of skilled labor, cyber-attacks, health measures related to COVID-19, or climate change;
•the ability of our contractual counterparties to satisfy their obligations to us, including the operation of joint ventures under which we may not control and exposure to decommissioning liabilities for divested assets in the event the current or future owners are unable to perform;
•unexpected changes in technical requirements for constructing, modifying or operating exploration and production facilities and/or the inability to timely obtain or maintain necessary permits;
•availability and costs of employees and other personnel, drilling rigs, equipment, supplies and other required services;
•any limitations on our access to capital or increase in our cost of capital, including as a result of limitations on investment in oil and gas activities or negative outcomes within commodity and financial markets;
•liability resulting from environmental obligations and litigation, including heightened risks associated with being a general partner of Hess Midstream LP; and
•other factors described in the section entitled “Risk Factors” in Item 1A—Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2021 as well as any additional risks described in our other filings with the SEC.
As and when made, we believe that our forward-looking statements are reasonable. However, given these risks and uncertainties, caution should be taken not to place undue reliance on any such forward-looking statements since such statements speak only as of the date when made and there can be no assurance that such forward-looking statements will occur and actual results may differ materially from those contained in any forward-looking statement we make. Except as required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether because of new information, future events or otherwise.
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PART I - FINANCIAL INFORMATION (CONT'D.)
Item 3. Quantitative and Qualitative Disclosures about Market Risk.
The information required by this item is presented under Item 2, “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Market Risk Disclosures.”
Item 4. Controls and Procedures.
Based upon their evaluation of the Corporation’s disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of June 30, 2022, John B. Hess, Chief Executive Officer, and John P. Rielly, Chief Financial Officer, concluded that these disclosure controls and procedures were effective as of June 30, 2022.
There was no change in internal control over financial reporting identified in connection with the evaluation required by paragraph (d) of Rules 13a-15 or 15d-15 in the quarter ended June 30, 2022 that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.
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PART II – OTHER INFORMATION
Item 1. Legal Proceedings.
Information regarding legal proceedings is contained in Note 11, Guarantees and Contingencies in the Notes to Consolidated Financial Statements and is incorporated herein by reference.
Item 2. Share Repurchase Activities.
Our common stock repurchase activities for the three months ended June 30, 2022, were as follows:
| Period | Total Number of Shares Purchased (a) | Average Price Paid per Share (a) | Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs (b) | Maximum Approximate Dollar Value of Shares that May Yet be Purchased Under the Plans or Programs (c) (In millions) | ||||||||||||||||||||||
| April | — | $ | — | — | $ | 650 | ||||||||||||||||||||
| May | — | — | — | 650 | ||||||||||||||||||||||
| June | 1,753,918 | 108.49 | 1,753,918 | 460 | ||||||||||||||||||||||
| Total | 1,753,918 | $ | 108.49 | 1,753,918 | ||||||||||||||||||||||
(a)Repurchased in open-market transactions. The average price paid per share was inclusive of transaction fees.
(b)Since initiation of the buyback program in August 2013, total shares repurchased through June 30, 2022 amounted to 93.6 million at a total cost of $7.04 billion including transaction fees.
(c)In March 2013, we announced that our Board of Directors approved a stock repurchase program that authorized the purchase of common stock up to a value of $4.0 billion. In May 2014, the share repurchase program was increased to $6.5 billion and in March 2018, it was increased further to $7.5 billion.
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PART II – OTHER INFORMATION (CONT'D)
Item 6. Exhibits.
| Exhibits | |||||
| 101(INS) | Inline XBRL Instance Document- the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document. | ||||
| 101(SCH) | Inline XBRL Taxonomy Extension Schema Document. | ||||
| 101(CAL) | Inline XBRL Taxonomy Extension Calculation Linkbase Document. | ||||
| 101(LAB) | Inline XBRL Taxonomy Extension Label Linkbase Document. | ||||
| 101(PRE) | Inline XBRL Taxonomy Extension Presentation Linkbase Document. | ||||
| 101(DEF) | Inline XBRL Taxonomy Extension Definition Linkbase Document. | ||||
| 104 | The cover page from the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2022, has been formatted in Inline XBRL. | ||||
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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
| HESS CORPORATION | ||||||||
| (REGISTRANT) | ||||||||
| By | /s/ John B. Hess | |||||||
| JOHN B. HESS | ||||||||
| CHIEF EXECUTIVE OFFICER | ||||||||
| By | /s/ John P. Rielly | |||||||
| JOHN P. RIELLY | ||||||||
| EXECUTIVE VICE PRESIDENT AND | ||||||||
| CHIEF FINANCIAL OFFICER | ||||||||
Date: August 4, 2022
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