Permian Resources Announces Fourth Quarter 2022 Results and Provides Improved 2023 Guidance
MIDLAND, Texas -- February 22, 2023 (BUSINESS WIRE) -- Permian Resources Corporation (“Permian Resources” or the “Company”) (NYSE: PR) today announced its fourth quarter and full year 2022 financial and operational results and 2023 operational plans.
Recent Financial and Operational Highlights
•Delivered fourth quarter oil production of 81.4 MBbls/d, exceeding the mid-point of prior outlook by 9%
•Reported net cash provided by operating activities of $528 million and adjusted free cash flow1 of $256 million
•Executed a series of portfolio optimization transactions, adding high-return inventory and generating ~$100 million of net cash proceeds
•Enhanced capital efficiency driven by strong well performance and cost control
•Delivered controllable cash costs of $7.89 per Boe
•Announced quarterly base dividend of $0.05 per share
2023 Financial and Operational Plan
•Increased 2023 oil and total production guidance by 4% and 3%, respectively, compared to previous outlook
◦Continue to target oil production growth of ~10% in the fourth quarter 2023 compared to the prior year period, despite exceeding fourth quarter 2022 production outlook
•Currently operating seven rigs, with plans to reduce to six rigs during second quarter 2023 as a result of operational synergies
•Reduced controllable cash costs by ~5% to $7.60 per Boe compared to previous outlook
•Announced 2023 total capital budget of $1.25 to $1.45 billion
◦Increase to prior outlook driven primarily by higher working interest (85% from 80% previously) and longer lateral lengths (9,300’ from 9,000’ previously)
•Variable return to be initiated based upon first quarter 2023 results
Management Commentary
“Permian Resources’ outstanding fourth quarter results reflect a continuation of our strong operational track record,” said Will Hickey, Co-CEO of Permian Resources. “In our first full quarter post-merger, our team delivered strong financial and operational results driven by well outperformance and continued cost discipline.”
“Our team has worked diligently to build an optimized 2023 plan that maximizes capital efficiency and leads to higher oil production and lower cash costs, accomplishing our ultimate goal of driving more free cash flow and higher returns for our investors,” said James Walter, Co-CEO of the Company. “We believe Permian Resources represents a unique value proposition for investors, with the benefits of scaled operations in the Delaware Basin combined with a nimble and creative approach to value creation, as exemplified by our recent portfolio optimization efforts.”
Financial Results
For the quarter, Permian Resources generated net cash provided by operating activities of $528 million and adjusted free cash flow of $256 million. The Company also reported net income attributable to Class A Common Stock during the fourth quarter of $83 million, or $0.26 per diluted share.
Average daily crude oil production for the fourth quarter was 81,378 barrels of oil per day (“Bbls/d”), and total production during the quarter averaged 158,208 barrels of oil equivalent per day (“Boe/d”).
Permian Resources maintains a strong financial position and low leverage profile. At December 31, 2022, the Company had approximately $60 million in cash on hand and $385 million of borrowings outstanding under its revolving credit facility. Net debt-to-LQA EBITDAX1 at December 31, 2022 was approximately 0.9x, and the Company has no debt maturities until 2026.
Operational Results
Permian Resources continues to optimize its Delaware Basin acreage position through large-scale, co-development well packages. The Company significantly exceeded its fourth quarter production targets, while maintaining cost discipline. Permian Resources’ robust production results during the quarter were primarily attributable to better than expected well performance, in addition to higher production runtime and reduced cycle times. Total capital expenditures incurred for the quarter were $325 million.
2023 Operational Plans and Targets
Based on recent operational results, Permian Resources increased its 2023 oil production target by 4% to approximately 85 MBbls/d and raised its total production target by 3% to approximately 162 MBoe/d, based on the mid-point of guidance. Permian Resources also lowered its full year 2023 guidance range for controllable cash costs (LOE, Cash G&A and GP&T) on a per unit basis by approximately 5%, compared to its preliminary full year outlook.
The estimated fiscal year 2023 total capital budget is approximately $1.25 billion to $1.45 billion. Permian Resources expects to turn-in-line (“TIL”) approximately 150 gross wells, with an average working interest of approximately 85% and 8/8ths net revenue interest of approximately 78%. This represents an increase from its previously expected full year working interest of 80%. The Company also expects its average completed lateral length during 2023 to increase to approximately 9,300 feet, compared to 9,000 feet previously.
Due to recent efficiency gains, Permian Resources expects to further reduce its operated rig program from seven currently to six during the second quarter. Assuming planned activity levels, the Company is maintaining crude oil production growth of approximately 10% in the fourth quarter 2023 compared to the fourth quarter 2022.
“Through the implementation of combined best practices, our operations team has accelerated the realization of higher operational efficiencies and reduced cycle times,” said Will Hickey, Co-CEO. “This will allow us to reduce our operated rig count sooner than anticipated, while drilling and completing the same amount of wells for the full year.”
(For a detailed table summarizing Permian Resources’ 2023 operational and financial guidance, please see the Appendix of this press release.)
Shareholder Returns
Permian Resources announced today that its Board of Directors declared a quarterly cash dividend of $0.05 per share of Class A common stock, or $0.20 per share on an annualized basis. The dividend is payable on March 15, 2023 to shareholders of record as of March 7, 2023. The Company’s base dividend represents an annualized yield of 2.1%, as of February 21, 2023.
Beginning in the first quarter of 2023, Permian Resources expects to initiate its variable return of capital program, which is structured to distribute at least 50% of free cash flow after the base dividend through a variable dividend, share repurchases or a combination of both. The Company’s inaugural variable dividend will be paid during the second quarter of 2023.
Year-End 2022 Proved Reserves
Permian Resources reported year-end 2022 total proved reserves of 582 MMBoe compared to 305 MMBoe at prior year-end. At year-end 2022, proved reserves consisted of 49% oil, 30% natural gas and 21% natural gas liquids. Proved developed reserves were 341 MMBoe (59% of total proved reserves) at December 31, 2022. Permian Resources had a standardized measure of discounted future net cash flows of $9.4 billion at December 31, 2022. The pre-tax present value at 10% (“Pre-tax PV 10%”, a non-GAAP financial measure reconciled within the Appendix) of Permian Resources’ total proved reserves was $11.7 billion at year-end.
Netherland Sewell & Associates, Inc., an independent reserve engineering firm, prepared Permian Resources’ year-end reserves estimates for the year ended December 31, 2022. (For additional information relating to our reserves, please see the Appendix of this press release.)
Annual Report on Form 10-K
Permian Resources’ financial statements and related footnotes will be available in its Annual Report on Form 10-K for the year ended December 31, 2022, which is expected to be filed with the Securities and Exchange Commission (“SEC”) on February 23, 2023.
Conference Call and Webcast
Permian Resources will host an investor conference call on Thursday, February 23, 2023 at 8:00 a.m. Central (9:00 a.m. Eastern) to discuss fourth quarter and full year 2022 operating and financial results. Interested parties may join the webcast by visiting Permian Resources’ website at www.permianres.com and clicking on the webcast link or by dialing (888) 886-7786 (Conference ID: 74862610) at least 15 minutes prior to the start of the call. A replay of the call will be available on the Company’s website or by phone at (877) 674-7070 (Access Code: 862610) for a 14-day period following the call.
About Permian Resources
Headquartered in Midland, Texas, Permian Resources is an independent oil and natural gas company focused on the responsible acquisition, optimization and development of high-return oil and natural gas properties. The Company’s assets and operations are located in the core of the Delaware Basin. For more information, please visit www.permianres.com.
Cautionary Note Regarding Forward-Looking Statements
The information in this press release includes “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. All statements, other than statements of historical fact included in this press release, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this press release, the words “could,” “may,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “project,” “goal,” “plan,” “target” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. These forward-looking statements are based on management’s current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events.
Forward-looking statements may include statements about:
•volatility of oil, natural gas and NGL prices or a prolonged period of low oil, natural gas or NGL prices and the effects of actions by, or disputes among or between, members of the Organization of Petroleum Exporting Countries, such as Saudi Arabia, and other oil and natural gas producing countries, such as Russia, with respect to production levels or other matters related to the price of oil;
•political and economic conditions in or affecting other producing regions or countries, including the Middle East, Russia, Eastern Europe, Africa and South America;
•the effects of excess supply of oil and natural gas resulting from the reduced demand caused by the Coronavirus Disease 2019 pandemic and the actions by certain oil and natural gas producing countries;
•our business strategy and future drilling plans;
•our reserves and our ability to replace the reserves we produce through drilling and property acquisitions;
•our drilling prospects, inventories, projects and programs;
•our financial strategy, return of capital program, leverage, liquidity and capital required for our development program;
•our realized oil, natural gas and NGL prices;
•the timing and amount of our future production of oil, natural gas and NGLs;
•our ability to identify, complete and effectively integrate acquisitions of properties or businesses;
•our ability to realize the anticipated benefits and synergies from the Merger and effectively integrate the assets of CRP and Colgate;
•our hedging strategy and results;
•our competition and government regulations;
•our ability to obtain permits and governmental approvals;
•our pending legal or environmental matters;
•the marketing and transportation of our oil, natural gas and NGLs;
•our leasehold or business acquisitions;
•cost of developing or operating our properties;
•our anticipated rate of return;
•general economic conditions;
•weather conditions in the areas where we operate;
•credit markets;
•our ability to make dividends and share repurchases;
•uncertainty regarding our future operating results;
•our plans, objectives, expectations and intentions contained in this press release that are not historical; and
•the other factors described in our most recent Annual Report on Form 10-K, and any updates to those factors set forth in our subsequent Quarterly Reports on Form 10-Q or Current Reports on Form 8-K.
We caution you that these forward-looking statements are subject to all of the risks and uncertainties, most of which are difficult to predict and many of which are beyond our control, incident to the development, production,
gathering and sale of oil and natural gas. These risks include, but are not limited to, commodity price volatility, inflation, lack of availability of drilling and production equipment and services, risks relating to the merger, environmental risks, drilling and other operating risks, regulatory changes, the uncertainty inherent in estimating oil and gas reserves and in projecting future rates of production, cash flow and access to capital, the timing of development expenditures and the other risks described in our filings with the SEC.
Reserve engineering is a process of estimating underground accumulations of oil and natural gas that cannot be measured in an exact way. The accuracy of any oil and gas reserve estimate depends on the quality of available data, the interpretation of such data, and price and cost assumptions made by reserve engineers. In addition, the results of drilling, testing and production activities may justify revisions of estimates that were made previously. If significant, such revisions would change the schedule of any further production and development drilling. Accordingly, reserve estimates may differ significantly from the quantities of oil and natural gas that are ultimately recovered.
Should one or more of the risks or uncertainties described in this press release occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. All forward-looking statements, expressed or implied, included in this press release are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue.
Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements, all of which are expressly qualified by the statements in this section, to reflect events or circumstances after the date of this press release.
1) Adjusted Free Cash Flow and Net Debt-to-LQA EBITDAX are non-GAAP financial measures. See “Non-GAAP Financial Measures” included within the Appendix of this press release for related disclosures and reconciliations to the most directly comparable financial measures calculated and presented in accordance with GAAP.
Contact:
Hays Mabry
Sr. Director, Investor Relations
(832) 240-3265
ir@permianres.com
SOURCE Permian Resources Corporation
Details of our 2023 operational and financial guidance are presented below:
| 2023 FY Guidance | |||||||||||
| Net average daily production (Boe/d) | 155,000 | — | 168,000 | ||||||||
| Net average daily oil production (Bbls/d) | 82,000 | — | 88,000 | ||||||||
| Production costs | |||||||||||
| Lease operating expenses ($/Boe) | $4.90 | — | $5.50 | ||||||||
| Gathering, processing and transportation expenses ($/Boe) | $1.00 | — | $1.20 | ||||||||
Cash general and administrative ($/Boe)1 | $1.20 | — | $1.40 | ||||||||
| Severance and ad valorem taxes (% of revenue) | 6.5% | — | 8.5% | ||||||||
| Total capital expenditure program ($MM) | $1,250 | — | $1,450 | ||||||||
| Operated drilling program | |||||||||||
| TILs (gross) | ~150 | ||||||||||
| Average working interest | ~85% | ||||||||||
| Average lateral length (feet) | ~9,300 | ||||||||||
(1) Excludes stock-based compensation.
Permian Resources Corporation
Operating Highlights
| Three Months Ended December 31, | Year Ended December 31, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| Net revenues (in thousands): | |||||||||||||||||||||||
| Oil sales | $ | 612,490 | $ | 230,791 | $ | 1,622,035 | $ | 743,069 | |||||||||||||||
| Natural gas sales | 76,454 | 43,212 | 276,957 | 149,478 | |||||||||||||||||||
| NGL sales | 72,612 | 42,416 | 232,273 | 137,345 | |||||||||||||||||||
Oil and gas sales | $ | 761,556 | $ | 316,419 | $ | 2,131,265 | $ | 1,029,892 | |||||||||||||||
| Average sales price: | |||||||||||||||||||||||
| Oil (per Bbl) | $ | 81.81 | $ | 72.78 | $ | 88.95 | $ | 63.50 | |||||||||||||||
| Effect of derivative settlements on average price (per Bbl) | 2.41 | (10.36) | (4.85) | (10.19) | |||||||||||||||||||
| Oil net of hedging (per Bbl) | $ | 84.22 | $ | 62.42 | $ | 84.10 | $ | 53.31 | |||||||||||||||
Average NYMEX price for oil (per Bbl) | $ | 82.64 | $ | 77.09 | $ | 94.24 | $ | 67.89 | |||||||||||||||
Oil differential from NYMEX | (0.84) | (4.31) | (5.29) | (4.39) | |||||||||||||||||||
| Natural gas (per Mcf) | $ | 3.11 | $ | 4.41 | $ | 4.64 | $ | 3.67 | |||||||||||||||
| Effect of derivative settlements on average price (per Mcf) | 0.43 | (1.03) | (0.53) | (0.32) | |||||||||||||||||||
| Natural gas net of hedging (per Mcf) | $ | 3.54 | $ | 3.38 | $ | 4.11 | $ | 3.35 | |||||||||||||||
| Average NYMEX price for natural gas (per Mcf) | $ | 5.55 | $ | 4.74 | $ | 6.38 | $ | 3.84 | |||||||||||||||
Natural gas differential from NYMEX | (2.44) | (0.33) | (1.74) | (0.17) | |||||||||||||||||||
| NGL (per Bbl) | $ | 24.48 | $ | 44.28 | $ | 34.41 | $ | 36.61 | |||||||||||||||
Net production: | |||||||||||||||||||||||
| Oil (MBbls) | 7,487 | 3,170 | 18,235 | 11,701 | |||||||||||||||||||
| Natural gas (MMcf) | 24,610 | 9,808 | 59,692 | 40,741 | |||||||||||||||||||
| NGL (MBbls) | 2,966 | 958 | 6,750 | 3,752 | |||||||||||||||||||
Total (MBoe)(1) | 14,556 | 5,764 | 34,934 | 22,243 | |||||||||||||||||||
Average daily net production: | |||||||||||||||||||||||
| Oil (Bbls/d) | 81,378 | 34,468 | 49,958 | 32,058 | |||||||||||||||||||
| Natural gas (Mcf/d) | 267,503 | 106,613 | 163,539 | 111,619 | |||||||||||||||||||
| NGL (Bbls/d) | 32,246 | 10,412 | 18,494 | 10,278 | |||||||||||||||||||
Total (Boe/d)(1) | 158,208 | 62,649 | 95,708 | 60,939 | |||||||||||||||||||
(1) Calculated by converting natural gas to oil equivalent barrels at a ratio of six Mcf of natural gas to one Boe.
Permian Resources Corporation
Operating Expenses
| Three Months Ended December 31, | Year Ended December 31, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| Operating costs (in thousands): | |||||||||||||||||||||||
| Lease operating expenses | $ | 73,289 | $ | 28,897 | $ | 171,867 | $ | 106,419 | |||||||||||||||
| Severance and ad valorem taxes | 54,233 | 20,973 | 155,724 | 67,140 | |||||||||||||||||||
| Gathering, processing, and transportation expense | 20,246 | 21,613 | 97,915 | 85,896 | |||||||||||||||||||
| Operating cost metrics: | |||||||||||||||||||||||
| Lease operating expenses (per Boe) | $ | 5.04 | $ | 5.01 | $ | 4.92 | $ | 4.78 | |||||||||||||||
| Severance and ad valorem taxes (% of revenue) | 7.1 | % | 6.6 | % | 7.3 | % | 6.5 | % | |||||||||||||||
| Gathering, processing, and transportation expense (per Boe) | 1.39 | 3.75 | 2.80 | 3.86 | |||||||||||||||||||
Permian Resources Corporation
Consolidated Statements of Operations
(in thousands, except per share data)
| Three Months Ended December 31, | Year Ended December 31, | ||||||||||||||||||||||
| 2022 | 2021 | 2022 | 2021 | ||||||||||||||||||||
| Operating revenues | |||||||||||||||||||||||
| Oil and gas sales | $ | 761,556 | $ | 316,419 | $ | 2,131,265 | $ | 1,029,892 | |||||||||||||||
| Operating expenses | |||||||||||||||||||||||
| Lease operating expenses | 73,289 | 28,897 | 171,867 | 106,419 | |||||||||||||||||||
| Severance and ad valorem taxes | 54,233 | 20,973 | 155,724 | 67,140 | |||||||||||||||||||
| Gathering, processing and transportation expenses | 20,246 | 21,613 | 97,915 | 85,896 | |||||||||||||||||||
| Depreciation, depletion and amortization | 182,052 | 75,863 | 444,678 | 289,122 | |||||||||||||||||||
| General and administrative expenses | 75,617 | 20,643 | 159,554 | 110,454 | |||||||||||||||||||
| Merger and integration expense | 12,469 | — | 77,424 | — | |||||||||||||||||||
| Impairment and abandonment expense | 244 | 6,400 | 3,875 | 32,511 | |||||||||||||||||||
| Exploration and other expenses | 4,765 | 3,185 | 11,378 | 7,883 | |||||||||||||||||||
| Total operating expenses | 422,915 | 177,574 | 1,122,415 | 699,425 | |||||||||||||||||||
| Net gain (loss) on sale of long-lived assets | 13 | 34,422 | (1,314) | 34,168 | |||||||||||||||||||
| Proceeds from terminated sale of assets | — | — | — | 5,983 | |||||||||||||||||||
| Income (loss) from operations | 338,654 | 173,267 | 1,007,536 | 370,618 | |||||||||||||||||||
| Other income (expense) | |||||||||||||||||||||||
| Interest expense | (39,358) | (13,931) | (95,645) | (61,288) | |||||||||||||||||||
| Gain (loss) on extinguishment of debt | — | — | — | (22,156) | |||||||||||||||||||
| Net gain (loss) on derivative instruments | (60,019) | 1,860 | (42,368) | (148,825) | |||||||||||||||||||
| Other income (expense) | 291 | 124 | 609 | 395 | |||||||||||||||||||
| Total other income (expense) | (99,086) | (11,947) | (137,404) | (231,874) | |||||||||||||||||||
| Income (loss) before income taxes | 239,568 | 161,320 | 870,132 | 138,744 | |||||||||||||||||||
| Income tax (expense) benefit | (40,860) | (569) | (120,292) | (569) | |||||||||||||||||||
| Net income (loss) | 198,708 | 160,751 | 749,840 | 138,175 | |||||||||||||||||||
| Less: Net (income) loss attributable to noncontrolling interest | (115,658) | — | (234,803) | — | |||||||||||||||||||
Net income (loss) attributable to Class A Common Stock | $ | 83,050 | $ | 160,751 | $ | 515,037 | $ | 138,175 | |||||||||||||||
| Income (loss) per share of Class A Common Stock: | |||||||||||||||||||||||
| Basic | $ | 0.29 | $ | 0.57 | $ | 1.80 | $ | 0.49 | |||||||||||||||
| Diluted | $ | 0.26 | $ | 0.51 | $ | 1.61 | $ | 0.46 | |||||||||||||||
| Weighted average Class A Common Stock outstanding: | |||||||||||||||||||||||
| Basic | 288,512 | 281,183 | 286,160 | 280,871 | |||||||||||||||||||
| Diluted | 329,454 | 315,748 | 322,816 | 310,170 | |||||||||||||||||||
Permian Resources Corporation
Consolidated Balance Sheets
(in thousands, except share and per share amounts)
| December 31, 2022 | December 31, 2021 | ||||||||||
| ASSETS | |||||||||||
| Current assets | |||||||||||
| Cash and cash equivalents | $ | 59,545 | $ | 9,380 | |||||||
| Accounts receivable, net | 282,846 | 71,295 | |||||||||
| Derivative instruments | 100,797 | — | |||||||||
| Prepaid and other current assets | 20,602 | 5,860 | |||||||||
| Total current assets | 463,790 | 86,535 | |||||||||
| Property and equipment | |||||||||||
| Oil and natural gas properties, successful efforts method | |||||||||||
| Unproved properties | 1,424,744 | 1,040,386 | |||||||||
| Proved properties | 8,869,174 | 4,623,726 | |||||||||
| Accumulated depreciation, depletion and amortization | (2,419,692) | (1,989,489) | |||||||||
| Total oil and natural gas properties, net | 7,874,226 | 3,674,623 | |||||||||
| Other property and equipment, net | 15,173 | 11,197 | |||||||||
| Total property and equipment, net | 7,889,399 | 3,685,820 | |||||||||
| Noncurrent assets | |||||||||||
| Operating lease right-of-use assets | 64,792 | 16,385 | |||||||||
| Other noncurrent assets | 74,611 | 15,854 | |||||||||
| TOTAL ASSETS | $ | 8,492,592 | $ | 3,804,594 | |||||||
| LIABILITIES AND EQUITY | |||||||||||
| Current liabilities | |||||||||||
| Accounts payable and accrued expenses | $ | 562,156 | $ | 130,256 | |||||||
| Operating lease liabilities | 29,759 | 1,413 | |||||||||
| Derivative instruments | 1,998 | 35,150 | |||||||||
| Other current liabilities | 11,656 | 1,080 | |||||||||
| Total current liabilities | 605,569 | 167,899 | |||||||||
| Noncurrent liabilities | |||||||||||
| Long-term debt, net | 2,140,798 | 825,565 | |||||||||
| Asset retirement obligations | 40,947 | 17,240 | |||||||||
| Deferred income taxes | 4,430 | 2,589 | |||||||||
| Operating lease liabilities | 41,341 | 16,002 | |||||||||
| Other noncurrent liabilities | 3,211 | 24,579 | |||||||||
| Total liabilities | 2,836,296 | 1,053,874 | |||||||||
| Shareholders’ equity | |||||||||||
| Common stock, $0.0001 par value, 1,500,000,000 shares authorized: | |||||||||||
| Class A: 298,640,260 shares issued and 288,532,257 shares outstanding at December 31, 2022 and 294,260,623 shares issued and 284,696,972 shares outstanding at December 31, 2021 | 30 | 29 | |||||||||
| Class C: 269,300,000 shares issued and outstanding at December 31, 2022 and no shares issued or outstanding at December 31, 2021 | 27 | — | |||||||||
| Additional paid-in capital | 2,698,465 | 3,013,017 | |||||||||
| Retained earnings (accumulated deficit) | 237,226 | (262,326) | |||||||||
| Total shareholders’ equity | 2,935,748 | 2,750,720 | |||||||||
| Noncontrolling interest | 2,720,548 | — | |||||||||
| Total equity | 5,656,296 | 2,750,720 | |||||||||
| TOTAL LIABILITIES AND EQUITY | $ | 8,492,592 | $ | 3,804,594 | |||||||
Permian Resources Corporation
Consolidated Statements of Cash Flows
(in thousands)
| Year Ended December 31, | |||||||||||
| 2022 | 2021 | ||||||||||
| Cash flows from operating activities: | |||||||||||
| Net income (loss) | $ | 749,840 | $ | 138,175 | |||||||
| Adjustments to reconcile net income (loss) to net cash provided by operating activities: | |||||||||||
| Depreciation, depletion and amortization | 444,678 | 289,122 | |||||||||
| Stock-based compensation expense - equity awards | 116,480 | 37,541 | |||||||||
| Stock-based compensation expense - liability awards | (24,174) | 20,573 | |||||||||
| Impairment and abandonment expense | 3,875 | 32,511 | |||||||||
| Exploratory dry hole costs | — | — | |||||||||
| Deferred tax expense (benefit) | 119,679 | 569 | |||||||||
| Net (gain) loss on sale of long-lived assets | 1,314 | (34,168) | |||||||||
| Non-cash portion of derivative (gain) loss | (77,737) | 16,700 | |||||||||
| Amortization of debt issuance costs and debt discount | 15,362 | 4,992 | |||||||||
| (Gain) loss on extinguishment of debt | — | 22,156 | |||||||||
| Changes in operating assets and liabilities: | |||||||||||
| (Increase) decrease in accounts receivable | (66,824) | (21,475) | |||||||||
| (Increase) decrease in prepaid and other assets | (1,751) | 2,907 | |||||||||
| Increase (decrease) in accounts payable and other liabilities | 90,929 | 16,016 | |||||||||
| Net cash provided by operating activities | 1,371,671 | 525,619 | |||||||||
| Cash flows from investing activities: | |||||||||||
| Acquisition of oil and natural gas properties | (8,858) | (6,510) | |||||||||
| Drilling and development capital expenditures | (771,577) | (319,640) | |||||||||
| Cash paid for business acquired in the Merger, net of cash acquired | (496,671) | — | |||||||||
| Purchases of other property and equipment | (3,563) | (901) | |||||||||
| Proceeds from sales of oil and natural gas properties | 75,620 | 100,575 | |||||||||
| Net cash used in investing activities | (1,205,049) | (226,476) | |||||||||
| Cash flows from financing activities: | |||||||||||
| Proceeds from borrowings under revolving credit facility | 1,115,000 | 570,000 | |||||||||
| Repayment of borrowings under revolving credit facility | (755,000) | (875,000) | |||||||||
| Repayment of credit facility acquired in the Merger | (400,000) | — | |||||||||
| Proceeds from issuance of senior notes | — | 170,000 | |||||||||
| Debt exchange and debt issuance costs | (19,833) | (6,421) | |||||||||
| Premiums paid on capped call transactions | — | (14,688) | |||||||||
| Redemption of senior secured notes | — | (127,073) | |||||||||
| Proceeds from exercise of stock options | 109 | 132 | |||||||||
| Dividends Paid | (14,426) | — | |||||||||
| Distributions paid to noncontrolling interest owners | (13,465) | — | |||||||||
| Class A Common Stock repurchased from employees for taxes due upon share vestings | (19,010) | (14,497) | |||||||||
| Net cash (used in) provided by financing activities | (106,625) | (297,547) | |||||||||
| Net increase (decrease) in cash, cash equivalents and restricted cash | 59,997 | 1,596 | |||||||||
| Cash, cash equivalents and restricted cash, beginning of period | 9,935 | 8,339 | |||||||||
| Cash, cash equivalents and restricted cash, end of period | $ | 69,932 | $ | 9,935 | |||||||
Reconciliation of cash, cash equivalents and restricted cash presented on the consolidated statements of cash flows for the periods presented:
| Year Ended December 31, | |||||||||||
| 2022 | 2021 | ||||||||||
| Cash and cash equivalents | $ | 59,545 | $ | 9,380 | |||||||
| Restricted cash | $ | 10,387 | $ | 555 | |||||||
| Total cash, cash equivalents and restricted cash | $ | 69,932 | $ | 9,935 | |||||||
Non-GAAP Financial Measures
In addition to disclosing financial results calculated in accordance with U.S. generally accepted accounting principles (“GAAP”), our earnings release contains non-GAAP financial measures as described below.
Adjusted EBITDAX
Adjusted EBITDAX is a supplemental non-GAAP financial measure that is used by management and external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies. We define Adjusted EBITDAX as net income attributable to Class A Common Stock before net income/loss attributable to noncontrolling interest, interest expense, income taxes, depreciation, depletion and amortization, impairment and abandonment expense, non-cash gains or losses on derivatives, stock-based compensation (not cash-settled), exploration and other expenses, merger and integration expense, gain/loss from the sale of long-lived assets and non-recurring items. Adjusted EBITDAX is not a measure of net income as determined by GAAP.
Our management believes Adjusted EBITDAX is useful as it allows them to more effectively evaluate our operating performance and compare the results of our operations from period to period and against our peers, without regard to our financing methods or capital structure. We exclude the items listed above from net income in arriving at Adjusted EBITDAX because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Adjusted EBITDAX should not be considered as an alternative to, or more meaningful than, net income as determined in accordance with GAAP or as an indicator of our operating performance or liquidity. Certain items excluded from Adjusted EBITDAX are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are components of Adjusted EBITDAX. Our presentation of Adjusted EBITDAX should not be construed as an inference that our results will be unaffected by unusual or nonrecurring items. Our computations of Adjusted EBITDAX may not be comparable to other similarly titled measures of other companies.
The following table presents a reconciliation of Adjusted EBITDAX to net income, which is the most directly comparable financial measure calculated and presented in accordance with GAAP:
| Three Months Ended | |||||||||||||||||||||||||||||
| (in thousands) | 12/31/2022 | 9/30/2022 | 6/30/2022 | 3/31/2022 | 12/31/2021 | ||||||||||||||||||||||||
Adjusted EBITDAX reconciliation to net income: | |||||||||||||||||||||||||||||
Net income (loss) attributable to Class A Common Stock | $ | 83,050 | $ | 224,359 | $ | 191,826 | $ | 15,802 | $ | 160,751 | |||||||||||||||||||
Net income (loss) attributable to noncontrolling interest | 115,658 | 119,145 | — | — | — | ||||||||||||||||||||||||
Interest expense | 39,358 | 28,807 | 14,326 | 13,154 | 13,931 | ||||||||||||||||||||||||
Income tax expense (benefit) | 40,860 | 31,169 | 41,487 | 6,776 | 569 | ||||||||||||||||||||||||
Depreciation, depletion and amortization | 182,052 | 109,500 | 82,117 | 71,009 | 75,863 | ||||||||||||||||||||||||
Impairment and abandonment expense | 244 | 498 | 506 | 2,627 | 6,400 | ||||||||||||||||||||||||
Non-cash derivative (gain) loss | 88,635 | (213,503) | (39,514) | 86,645 | (44,790) | ||||||||||||||||||||||||
Stock-based compensation expense(1) | 54,342 | 18,896 | (2,487) | 18,834 | 5,594 | ||||||||||||||||||||||||
Exploration and other expenses | 4,765 | 2,352 | 1,954 | 2,307 | 3,185 | ||||||||||||||||||||||||
Merger and integration expense | 12,469 | 59,270 | 5,685 | — | — | ||||||||||||||||||||||||
(Gain) loss on sale of long-lived assets | (13) | 3 | 1,406 | (82) | (34,422) | ||||||||||||||||||||||||
Adjusted EBITDAX | $ | 621,420 | $ | 380,496 | $ | 297,306 | $ | 217,072 | $ | 187,081 | |||||||||||||||||||
(1) Includes stock-based compensation for equity awards and also for cash-based liability awards that have not yet been settled in cash, both of which relate to general and administrative employees only. Stock-based compensation amounts for geographical and geophysical personnel are included within the Exploration and other expenses line item.
Net Debt-to-LQA EBITDAX
Net debt-to-LQA EBITDAX is a non-GAAP financial measure. We define net debt as long-term debt, net, plus unamortized debt discount and debt issuance costs on our senior notes minus cash and cash equivalents.
We define net debt-to-LQA EBITDAX as net debt (defined above) divided by Adjusted EBITDAX (defined and reconciled in the section above) for the three months ended December 31, 2022, on an annualized basis. We refer to this metric to show trends that investors may find useful in understanding our ability to service our debt. This metric is widely used by professional research analysts, including credit analysts, in the valuation and comparison of companies in the oil and gas exploration and production industry. The following table presents a reconciliation of net debt to long-term debt, net and the calculation of net debt-to-LQA EBITDAX for the period presented:
(in thousands) | December 31, 2022 | ||||
Long-term debt, net | 2,140,798 | ||||
Unamortized debt discount and debt issuance costs on senior notes | 60,001 | ||||
Long-term debt | 2,200,799 | ||||
Less: cash and cash equivalents | (59,545) | ||||
Net debt (Non-GAAP) | 2,141,254 | ||||
LQA EBITDAX(1) | 2,485,680 | ||||
Net debt-to-LQA EBITDAX | 0.9 | ||||
(1) Represents adjusted EBITDAX (defined and reconciled in the section above) for the three months ended December 31, 2022, on an annualized basis.
Free Cash Flow and Adjusted Free Cash Flow
Free cash flow and adjusted free cash flow are supplemental non-GAAP financial measures that are used by management and external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies. We define free cash flow as net cash provided by operating activities before changes in working capital, less incurred capital expenditures and adjusted free cash flow as free cash flow before non-recurring merger and integration expense.
Our management believes free cash flow and adjusted free cash flow are useful indicators of the Company’s ability to internally fund its exploration and development activities and to service or incur additional debt, without regard to the timing of settlement of either operating assets and liabilities or accounts payable related to capital expenditures. The Company believes that these measures, as so adjusted, present meaningful indicators of the Company’s actual sources and uses of capital associated with its operations conducted during the applicable period. Our computations of free cash flow and adjusted free cash flow may not be comparable to other similarly titled measures of other companies. Free cash flow and adjusted free cash flow should not be considered as alternatives to, or more meaningful than, net cash provided by operating activities as determined in accordance with GAAP or as indicators of our operating performance or liquidity.
Free cash flow and adjusted free cash flow are not financial measures that are determined in accordance with GAAP. Accordingly, the following table presents a reconciliation of free cash flow and adjusted free cash flow to net cash provided by operating activities, which is the most directly comparable financial measure calculated and presented in accordance with GAAP:
| Three Months Ended December 31, | |||||||||||
| (in thousands) | 2022 | 2021 | |||||||||
| Net cash provided by operating activities | $ | 528,295 | $ | 192,487 | |||||||
| Changes in working capital: | |||||||||||
| Accounts receivable | 60,071 | (21,523) | |||||||||
| Prepaid and other assets | 1,713 | (1,104) | |||||||||
| Accounts payable and other liabilities | (21,290) | 1,433 | |||||||||
| Operating cash flow before working capital changes | 568,789 | 171,293 | |||||||||
| Less: total capital expenditures incurred | (325,200) | (86,500) | |||||||||
| Free cash flow | 243,589 | 84,793 | |||||||||
| Merger and integration expense | 12,469 | — | |||||||||
| Adjusted free cash flow | $ | 256,058 | $ | 84,793 | |||||||
The following table summarizes the approximate volumes and average contract prices of the hedge contracts the Company had in place as of December 31, 2022 and additional contracts entered into through February 17, 2023:
| Period | Volume (Bbls) | Volume (Bbls/d) | Wtd. Avg. Crude Price ($/Bbl)(1) | ||||||||||||||||||||
| Crude oil swaps | January 2023 - March 2023 | 1,575,000 | 17,500 | $90.58 | |||||||||||||||||||
| April 2023 - June 2023 | 1,592,500 | 17,500 | 87.64 | ||||||||||||||||||||
| July 2023 - September 2023 | 1,472,000 | 16,000 | 86.36 | ||||||||||||||||||||
| October 2023 - December 2023 | 1,472,000 | 16,000 | 84.11 | ||||||||||||||||||||
| January 2024 - March 2024 | 1,092,000 | 12,000 | 78.46 | ||||||||||||||||||||
| April 2024 - June 2024 | 1,092,000 | 12,000 | 77.30 | ||||||||||||||||||||
| July 2024 - September 2024 | 1,104,000 | 12,000 | 76.21 | ||||||||||||||||||||
| October 2024 - December 2024 | 1,104,000 | 12,000 | 75.27 | ||||||||||||||||||||
| Period | Volume (Bbls) | Volume (Bbls/d) | Wtd. Avg. Collar Price Ranges ($/Bbl)(2) | ||||||||||||||||||||
| Crude oil collars | January 2023 - March 2023 | 810,000 | 9,000 | $75.56 - $91.15 | |||||||||||||||||||
| April 2023 - June 2023 | 819,000 | 9,000 | 75.56 - 91.15 | ||||||||||||||||||||
| July 2023 - September 2023 | 644,000 | 7,000 | 76.43 - 92.70 | ||||||||||||||||||||
| October 2023 - December 2023 | 644,000 | 7,000 | 76.43 - 92.70 | ||||||||||||||||||||
| Period | Volume (Bbls) | Volume (Bbls/d) | Wtd. Avg. Differential ($/Bbl)(3) | ||||||||||||||||||||
| Crude oil basis differential swaps | January 2023 - March 2023 | 729,999 | 8,111 | $0.55 | |||||||||||||||||||
| April 2023 - June 2023 | 739,499 | 8,126 | 0.55 | ||||||||||||||||||||
| July 2023 - September 2023 | 749,000 | 8,141 | 0.52 | ||||||||||||||||||||
| October 2023 - December 2023 | 749,002 | 8,141 | 0.52 | ||||||||||||||||||||
| January 2024 - March 2024 | 637,000 | 7,000 | 0.43 | ||||||||||||||||||||
| April 2024 - June 2024 | 637,000 | 7,000 | 0.43 | ||||||||||||||||||||
| July 2024 - September 2024 | 644,000 | 7,000 | 0.43 | ||||||||||||||||||||
| October 2024 - December 2024 | 644,000 | 7,000 | 0.43 | ||||||||||||||||||||
| Period | Volume (Bbls) | Volume (Bbls/d) | Wtd. Avg. Differential ($/Bbl)(4) | ||||||||||||||||||||
Crude oil roll differential swaps | January 2023 - March 2023 | 1,350,000 | 15,000 | $1.34 | |||||||||||||||||||
| April 2023 - June 2023 | 1,365,000 | 15,000 | 1.25 | ||||||||||||||||||||
| July 2023 - September 2023 | 1,380,000 | 15,000 | 1.23 | ||||||||||||||||||||
| October 2023 - December 2023 | 1,380,000 | 15,000 | 1.22 | ||||||||||||||||||||
| January 2024 - March 2024 | 637,000 | 7,000 | 0.75 | ||||||||||||||||||||
| April 2024 - June 2024 | 637,000 | 7,000 | 0.74 | ||||||||||||||||||||
| July 2024 - September 2024 | 644,000 | 7,000 | 0.73 | ||||||||||||||||||||
| October 2024 - December 2024 | 644,000 | 7,000 | 0.72 | ||||||||||||||||||||
(1) These crude oil swap transactions are settled based on the NYMEX WTI index price on each trading day within the specified monthly settlement period versus the contractual swap price for the volumes stipulated.
(2) These crude oil collars are settled based on the NYMEX WTI index price on each trading day within the specified monthly settlement period versus the contractual floor and ceiling prices for the volumes stipulated.
(3) These crude oil basis swap transactions are settled based on the difference between the arithmetic average of ARGUS MIDLAND WTI and ARGUS WTI CUSHING indices, during each applicable monthly settlement period.
(4) These crude oil roll swap transactions are settled based on the difference between the arithmetic average of NYMEX WTI calendar month prices and the physical crude oil delivery month price.
| Period | Volume (MMBtu) | Volume (MMBtu/d) | Wtd Avg. Gas Price ($/MMBtu)(1) | ||||||||||||||||||||
| Natural gas swaps | January 2023 - March 2023 | 1,670,157 | 18,557 | $7.64 | |||||||||||||||||||
| April 2023 - June 2023 | 1,572,752 | 17,283 | 4.70 | ||||||||||||||||||||
| July 2023 - September 2023 | 1,486,925 | 16,162 | 4.70 | ||||||||||||||||||||
| October 2023 - December 2023 | 1,413,628 | 15,366 | 4.90 | ||||||||||||||||||||
| January 2024 - March 2024 | 464,919 | 5,109 | 5.01 | ||||||||||||||||||||
| April 2024 - June 2024 | 446,321 | 4,905 | 3.93 | ||||||||||||||||||||
| July 2024 - September 2024 | 429,388 | 4,667 | 4.01 | ||||||||||||||||||||
| October 2024 - December 2024 | 413,899 | 4,499 | 4.32 | ||||||||||||||||||||
| Period | Volume (MMBtu) | Volume (MMBtu/d) | Wtd. Avg. Collar Price Ranges ($/MMBtu)(2) | ||||||||||||||||||||
| Natural gas collars | January 2023 - March 2023 | 7,104,843 | 78,943 | $4.67 - $10.33 | |||||||||||||||||||
| April 2023 - June 2023 | 6,389,748 | 70,217 | 3.64 - 7.62 | ||||||||||||||||||||
| July 2023 - September 2023 | 6,563,075 | 71,338 | 3.64 - 7.52 | ||||||||||||||||||||
| October 2023 - December 2023 | 6,636,372 | 72,134 | 3.66 - 8.22 | ||||||||||||||||||||
| January 2024 - March 2024 | 3,175,081 | 34,891 | 3.36 - 9.44 | ||||||||||||||||||||
| April 2024 - June 2024 | 1,373,679 | 15,095 | 3.00 - 6.45 | ||||||||||||||||||||
| July 2024 - September 2024 | 1,410,612 | 15,333 | 3.00 - 6.52 | ||||||||||||||||||||
| October 2024 - December 2024 | 1,426,101 | 15,501 | 3.25 - 7.30 | ||||||||||||||||||||
| Period | Volume (MMBtu) | Volume (MMBtu/d) | Wtd. Avg. Differential ($/MMBtu)(3) | ||||||||||||||||||||
| Natural gas basis differential swaps | January 2023 - March 2023 | 6,075,000 | 67,500 | $(1.10) | |||||||||||||||||||
| April 2023 - June 2023 | 6,142,500 | 67,500 | (1.30) | ||||||||||||||||||||
| July 2023 - September 2023 | 6,210,000 | 67,500 | (1.30) | ||||||||||||||||||||
| October 2023 - December 2023 | 6,210,000 | 67,500 | (1.30) | ||||||||||||||||||||
| January 2024 - March 2024 | 1,820,000 | 20,000 | (0.59) | ||||||||||||||||||||
| April 2024 - June 2024 | 1,820,000 | 20,000 | (0.67) | ||||||||||||||||||||
| July 2024 - September 2024 | 1,840,000 | 20,000 | (0.66) | ||||||||||||||||||||
| October 2024 - December 2024 | 1,840,000 | 20,000 | (0.64) | ||||||||||||||||||||
(1) These natural gas swap contracts are settled based on the NYMEX Henry Hub price on each trading day within the specified monthly settlement period versus the contractual swap price for the volumes stipulated.
(2) These natural gas collars are settled based on the NYMEX Henry Hub price on each trading day within the specified monthly settlement period versus the contractual floor and ceiling prices for the volumes stipulated.
(3) These natural gas basis swap contracts are settled based on the difference between the inside FERC’s West Texas WAHA price and the NYMEX price of natural gas, during each applicable monthly settlement period.
The following table summarizes estimated proved reserves, pre-tax PV 10%, and standardized measure of discounted future cash flows for the periods indicated:
| December 31, 2022 | December 31, 2021 | December 31, 2020 | |||||||||||||||
| Proved developed reserves: | |||||||||||||||||
| Oil (MBbls) | 156,941 | 77,973 | 70,716 | ||||||||||||||
| Natural gas (MMcf) | 652,270 | 326,223 | 279,556 | ||||||||||||||
| NGL (MBbls) | 74,940 | 30,318 | 31,672 | ||||||||||||||
Total proved developed reserves (MBoe)(1) | 340,593 | 162,662 | 148,981 | ||||||||||||||
| Proved undeveloped reserves: | |||||||||||||||||
| Oil (MBbls) | 130,091 | 75,480 | 79,776 | ||||||||||||||
| Natural gas (MMcf) | 381,301 | 250,782 | 248,231 | ||||||||||||||
| NGL (MBbls) | 47,911 | 25,265 | 28,773 | ||||||||||||||
Total proved undeveloped reserves (MBoe)(1) | 241,553 | 142,542 | 149,921 | ||||||||||||||
| Total proved reserves: | |||||||||||||||||
| Oil (MBbls) | 287,032 | 153,453 | 150,492 | ||||||||||||||
| Natural gas (MMcf) | 1,033,571 | 577,005 | 527,787 | ||||||||||||||
| NGL (MBbls) | 122,851 | 55,583 | 60,445 | ||||||||||||||
Total proved reserves (MBoe)(1) | 582,146 | 305,204 | 298,902 | ||||||||||||||
| Proved developed reserves % | 59 | % | 53 | % | 50 | % | |||||||||||
| Proved undeveloped reserves % | 41 | % | 47 | % | 50 | % | |||||||||||
| Reserve values (in millions): | |||||||||||||||||
| Standard measure of discounted future net cash flows | $ | 9,425.6 | $ | 3,396.3 | $ | 1,184.7 | |||||||||||
| Discounted future income tax expense | 2,289.1 | 481.2 | 4.4 | ||||||||||||||
Total proved pre-tax PV 10%(2) | $ | 11,714.7 | $ | 3,877.5 | $ | 1,189.1 | |||||||||||
(1) Calculated by converting natural gas to oil equivalent barrels at a ratio of six Mcf of natural gas to one Boe.
(2) Total proved pre-tax PV 10% (“Pre-tax PV 10%”) is a supplemental non-GAAP financial measure that is used by management and external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies, and it is derived from the standardized measure of discounted future net cash flows (the ‘‘Standardized Measure’’), which is the most directly comparable GAAP financial measure. Pre-tax PV 10% is computed on the same basis as the Standardized Measure but without deducting future income taxes. We believe Pre-tax PV 10% is a useful measure for investors when evaluating the relative monetary significance of our oil and natural gas properties. We further believe investors may utilize our Pre-tax PV 10% as a basis for comparison of the relative size and value of our proved reserves to other companies because many factors that are unique to each individual company impact the amount of future income taxes to be paid. However, Pre-tax PV 10% is not a substitute for the Standardized Measure. Our Pre-tax PV 10% and Standardized Measure do not purport to present the fair value of our proved oil, NGL and natural gas reserves.