Range Announces Fourth Quarter 2023 Results and 2024 Guidance
FORT WORTH, Texas, Feb. 21, 2024 (GLOBE NEWSWIRE) -- RANGE RESOURCES CORPORATION (NYSE: RRC) today announced its fourth quarter 2023 financial results and plans for 2024.
Full-Year 2023 Highlights –
- Cash flow from operating activities of $978 million
- Cash flow from operations, before working capital changes, of $1.1 billion
- Reduced net debt by $292 million, paid $77 million in dividends, and repurchased $19 million of shares
- Net production averaged 2,139 Mmcfe per day, approximately 69% natural gas
- All-in capital spending of $614 million, or $0.79 per mcfe
- Proved reserves of 18.1 Tcfe with positive performance revisions
- Increased hedge positions for 2024 and 2025 to approximately 55% and 25% of natural gas production with weighted-average floors of $3.70 and $4.11 per MMBtu, respectively
- Net Debt to EBITDAX of 1.3x (Non-GAAP) at year-end 2023
Commenting on the 2023 results and 2024 plans, Dennis Degner, the Company’s CEO said, “Range had a successful year – operating safely and efficiently, while generating free cash flow despite lower natural gas prices. Range’s 2023 free cash flow was allocated towards debt reduction and shareholder returns, while also building operational flexibility into our program. With the strongest balance sheet in company history, consistent operational performance, and a low capital reinvestment rate, we are targeting resilient free cash flow in 2024 and beyond. As demand for domestic and international natural gas and NGLs continues to increase in coming years, we believe Range is well-positioned on the low-end of the cost curve with a globally competitive emissions intensity and a high-return, long-life inventory of de-risked wells, measured in decades.”
2024 Capital and Production Guidance
Range’s 2024 all-in capital budget is expected to be $620 to $670 million, which consists of:
- Approximately $575 million of all-in maintenance capital including land and facilities,
- $30 - $45 million drilling and completion capital that adds to year-end 2024 well-in-process inventory,
- Up to $30 million on targeted acreage which increases planned lateral lengths and future inventory, and
- $15 - $20 million in water infrastructure/other, lowering future water-related costs
Range’s development plan for 2024 will target holding production flat for the year at approximately 2.12 – 2.16 Bcfe per day. For the year, Range plans to run two drilling rigs and one frac crew. As a result of operational efficiencies captured in 2023, this level of activity will result in Range building in-process well inventory during 2024, as was done in 2023. This increased inventory of wells that have been drilled and/or completed, increases operational and capital flexibility for future years. Like last year, there is approximately $30 to $45 million included in the 2024 capital plan for the associated well inventory additions. Separately, up to $30 million is planned for investment in non-maintenance acreage that increases lateral lengths and adds incremental inventory to Range’s year-end total of 28 million high-quality, undrilled lateral feet. Additionally, $15 to $20 million is planned for infrastructure and other investments primarily associated with water infrastructure expansions that will allow for more efficient water logistics, thereby lowering future drilling and completion costs and lease operating expense.
The table below summarizes 2023 activity and expected 2024 plans regarding the number of wells to sales in each area. To maintain current production levels, Range will turn to sales approximately 650,000 lateral feet in a year. Five wells that were planned for early 2024 were turned to sales in late 2023 because of faster drilling and completion times, though Range remained within the original 2023 capital guidance.
| Planned Wells TIL in 2024 | Wells TIL in 2023 | |||
| SW PA Super-Rich | 9 | 3 | ||
| SW PA Wet | 27 | 29 | ||
| SW PA Dry | 11 | 20 | ||
| NE PA Dry | 2 | 3 | ||
| Total Appalachia | 49 | 55 |
Financial Discussion
Except for generally accepted accounting principles (“GAAP”) reported amounts, specific expense categories exclude non-cash impairments, unrealized mark-to-market adjustment on derivatives, stock compensation and other items shown separately on the attached tables. “Unit costs” as used in this release are composed of direct operating, transportation, gathering, processing and compression, taxes other than income, general and administrative, interest and depletion, depreciation and amortization costs divided by production. See “Non-GAAP Financial Measures” for a definition of each of the non-GAAP financial measures and the tables that reconcile each of the non-GAAP measures to their most directly comparable GAAP financial measure.
Financial Position
During the fourth quarter, Range purchased 315,000 shares at an average price of approximately $29.75 per share. As of year-end, Range had approximately $1.1 billion of availability under the current share repurchase program.
During 2023, Range reduced net debt by $292 million, representing the Company’s sixth consecutive year of debt reduction. At year-end, Range’s net debt was approximately $1.58 billion, consisting of $1.79 billion of senior notes and $212 million in cash. On a trailing twelve-month basis, Range’s leverage ratio, a non-GAAP metric, defined as Net-Debt-to-EBITDAX was approximately 1.3x.
In fourth quarter 2023, Range realized a total of $8.0 million in contingent derivative settlement gains related to an asset divestiture completed in 2020. Range expects to receive these cash proceeds in the first half of 2024.
Capital Expenditures
Fourth quarter 2023 drilling and completions expenditures were $118.3 million and $16.7 million was invested in acreage and gathering facilities. Total 2023 capital budget expenditures were $614 million, including $568 million on drilling and completion, and a combined $46 million on acreage, gas gathering systems and other investments.
Fourth Quarter 2023 Results
Revenues for fourth quarter 2023 totaled $941 million, net cash provided from operating activities (including changes in working capital) was $226 million, and net income was $310 million ($1.27 per diluted share). Fourth quarter earnings results include a $291 million mark-to-market derivative gain due to decreases in commodity prices.
Non-GAAP revenues for fourth quarter 2023 totaled $715 million, and cash flow from operations before changes in working capital, a non-GAAP measure, was $300 million. Adjusted net income comparable to analysts’ estimates, a non-GAAP measure, was $153 million ($0.63 per diluted share) in fourth quarter 2023.
The following table details Range’s fourth quarter 2023 unit costs per mcfe(a):
| Expenses | 4Q 2023 (per mcfe) | 4Q 2022 (per mcfe) | Increase (Decrease) | ||||||
| Direct operating | $ | 0.11 | $ | 0.11 | 0% | ||||
| Transportation, gathering, processing and compression | 1.39 | 1.45 | (4%) | ||||||
| Taxes other than income | 0.02 | 0.06 | (67%) | ||||||
| General and administrative(a) | 0.17 | 0.15 | 13% | ||||||
| Interest expense(a) | 0.14 | 0.18 | (22%) | ||||||
| Total cash unit costs(b) | 1.83 | 1.95 | (6%) | ||||||
| Depletion, depreciation and amortization (DD&A) | 0.45 | 0.45 | - | ||||||
| Total unit costs plus DD&A(b) | $ | 2.28 | $ | 2.39 | (5%) | ||||
(a) Excludes stock-based compensation, legal settlements and amortization of deferred financing costs.
(b) May not add due to rounding.
The following table details Range’s average production and realized pricing for fourth quarter 2023:
| 4Q23 Production & Realized Pricing | |||||||||||||||
| Natural Gas (Mcf) | Oil (Bbl) | NGLs (Bbl) | Natural Gas Equivalent (Mcfe) | ||||||||||||
| Net production per day | 1,540,399 | 7,136 | 104,038 | 2,207,446 | |||||||||||
| Average NYMEX price | $ | 2.88 | $ | 78.28 | $ | 22.49 | |||||||||
| Differential, including basis hedging | (0.48 | ) | (10.56 | ) | 2.42 | ||||||||||
| Realized prices before NYMEX hedges | 2.40 | 67.72 | 24.91 | $ | 3.07 | ||||||||||
| Settled NYMEX hedges | 0.28 | (4.30 | ) | — | 0.18 | ||||||||||
| Average realized prices after hedges | $ | 2.68 | $ | 63.42 | $ | 24.91 | $ | 3.25 | |||||||
Fourth quarter 2023 natural gas, NGLs and oil price realizations (including the impact of cash-settled hedges and derivative settlements) averaged $3.25 per mcfe.
- The average natural gas price, including the impact of basis hedging, was $2.40 per mcf, or a ($0.48) per mcf differential to NYMEX. Range’s 2024 natural gas differential is expected to be ($0.40) to ($0.45) relative to NYMEX.
- Crude oil and condensate price realizations, before realized hedges, averaged $67.72 per barrel, or $10.56 below WTI (West Texas Intermediate). Range’s 2024 condensate differential is expected to be ($10.00) to ($13.00) relative to NYMEX.
- Pre-hedge NGL realizations were $24.91 per barrel, approximately $2.42 above the Mont Belvieu weighted equivalent. Range’s 2024 NGL differential is expected to be ($1.00) to +$1.00 relative to a Mont Belvieu equivalent barrel.
2023 Proved Reserves
| Summary of Changes in Proved Reserves (in Bcfe) | ||
| Balance at December 31, 2022 | 18,078 | |
| Extensions, discoveries and additions | 207 | |
| Performance revisions | 611 | |
| Price revisions | (2 | ) |
| Production | (781 | ) |
| Balance at December 31, 2023 | 18,113 | |
As shown in the table below, the present value (PV10) of reserves under SEC methodology was $7.9 billion. For comparison, the PV10 using December 31, 2023 strip prices equates to $11.7 billion using the same proven reserve volumes.
| 2023 SEC Pricing(a) | Strip Price Average(b) | |||
| Natural Gas Price ($/MMBtu) | $2.62 | $3.57 | ||
| WTI Oil Price ($/Bbl) | $78.10 | $63.49 | ||
| NGL Price ($/Bbl) | $24.91 | $24.64 | ||
| Proved Reserves PV10 ($ billions) | $7.9 | $11.7 | ||
a) SEC benchmark prices adjusted for energy content, quality and basis differentials were $2.20 per mcf and $68.32 per barrel of crude oil.
b) NYMEX 10-year strip prices adjusted for energy content, quality and basis differentials realized an average gas price differential of ($0.44) and an average realized oil differential of ($10.67) per barrel, which equate to $3.17 per mcf and $52.82 per barrel over the life of the reserves.
Year-end 2023 reserves included 6.6 Tcfe of proved undeveloped reserves from approximately 3.1 million lateral feet scheduled to be developed within the next five years with an expected development cost of $0.40 per mcfe. Future development costs included in the year-end 2023 reserve report utilized estimates consistent with 2024 expected drilling and completion costs. Beyond the five-year reserve calculation window, Range has approximately 25 million undrilled lateral feet of high-quality Marcellus and millions of undrilled lateral feet in the Utica and Upper Devonian horizons. Range also has a network of more than 250 existing well pads that provide the opportunity to develop future wells while utilizing existing roads, pads and infrastructure.
Guidance - 2024
Capital & Production Guidance
Range is targeting a maintenance program in 2024, holding production approximately flat at 2.12 – 2.16 Bcfe per day, with over 30% attributed to liquids production. Range’s 2024 all-in capital budget is expected to be $620 to $670 million, which consists of:
- $575 million of all-in maintenance capital including land and facilities,
- $30 - $45 million drilling and completion capital that adds to year-end 2024 well-in-process inventory,
- Up to $30 million on targeted acreage which increases lateral lengths and future inventory, and
- $15 - $20 million in water infrastructure/other, lowering future water-related costs
Full Year 2024 Expense Guidance
| Direct operating expense: | $0.13 - $0.14 per mcfe |
| Transportation, gathering, processing and compression expense: | $1.45 - $1.55 per mcfe |
| Other tax expense: | $0.04 - $0.05 per mcfe |
| Exploration expense: | $22 - $28 million |
| G&A expense: | $0.17 - $0.19 per mcfe |
| Net interest expense: | $0.14 - $0.16 per mcfe |
| DD&A expense: | $0.45 - $0.46 per mcfe |
| Net brokered gas marketing expense: | $8 - $12 million |
Full Year 2024 Price Guidance
Based on recent market indications, Range expects to average the following price differentials for its production in 2024.
| Natural Gas:(1) | NYMEX minus $0.40 to $0.45 |
| Natural Gas Liquids (including ethane):(2) | Mont Belvieu minus $1.00 to plus $1.00 per barrel |
| Oil/Condensate: | WTI minus $10.00 to $13.00 |
(1) Including basis hedging
(2) Weighting based on 53% ethane, 27% propane, 8% normal butane, 4% iso-butane and 8% natural gasoline.
Hedging Status
Range hedges portions of its expected future production volumes to increase the predictability of cash flow and to help improve and maintain a strong, flexible financial position. Please see the detailed hedging schedule posted on the Range website under Investor Relations - Financial Information.
Range has also hedged basis across the Company’s numerous natural gas sales points to limit volatility between benchmark and regional prices. The combined fair value of natural gas basis hedges as of December 31, 2023, was a net gain of $18.3 million.
Conference Call Information
A conference call to review the financial results is scheduled on Thursday, February 22 at 8:00 AM Central Time (9:00 AM Eastern Time).
Please to pre-register for the conference call and obtain a dial-in number with passcode.
A simultaneous webcast of the call may be accessed at . The webcast will be archived for replay on the Company's website until March 22nd.
Non-GAAP Financial Measures
Adjusted net income comparable to analysts’ estimates as set forth in this release represents income or loss from operations before income taxes adjusted for certain non-cash items (detailed in the accompanying table) less income taxes. We believe adjusted net income comparable to analysts’ estimates is calculated on the same basis as analysts’ estimates and that many investors use this published research in making investment decisions and evaluating operational trends of the Company and its performance relative to other oil and gas producing companies. Diluted earnings per share (adjusted) as set forth in this release represents adjusted net income comparable to analysts’ estimates on a diluted per share basis. A table is included which reconciles income or loss from operations to adjusted net income comparable to analysts’ estimates and diluted earnings per share (adjusted). On its website, the Company provides additional comparative information on prior periods along with non-GAAP revenue disclosures.
Cash flow from operations before changes in working capital (sometimes referred to as “adjusted cash flow”) as defined in this release represents net cash provided by operations before changes in working capital and exploration expense adjusted for certain non-cash compensation items. Cash flow from operations before changes in working capital is widely accepted by the investment community as a financial indicator of an oil and gas company’s ability to generate cash to internally fund exploration and development activities and to service debt. Cash flow from operations before changes in working capital is also useful because it is widely used by professional research analysts in valuing, comparing, rating and providing investment recommendations of companies in the oil and gas exploration and production industry. In turn, many investors use this published research in making investment decisions. Cash flow from operations before changes in working capital is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operations, investing, or financing activities as an indicator of cash flows, or as a measure of liquidity. A table is included which reconciles net cash provided by operations to cash flow from operations before changes in working capital as used in this release. On its website, the Company provides additional comparative information on prior periods for cash flow, cash margins and non-GAAP earnings as used in this release.
The cash prices realized for oil and natural gas production, including the amounts realized on cash-settled derivatives and net of transportation, gathering, processing and compression expense, is a critical component in the Company’s performance tracked by investors and professional research analysts in valuing, comparing, rating and providing investment recommendations and forecasts of companies in the oil and gas exploration and production industry. In turn, many investors use this published research in making investment decisions. Due to the GAAP disclosures of various derivative transactions and third-party transportation, gathering, processing and compression expense, such information is now reported in various lines of the income statement. The Company believes that it is important to furnish a table reflecting the details of the various components of each income statement line to better inform the reader of the details of each amount and provide a summary of the realized cash-settled amounts and third-party transportation, gathering, processing and compression expense, which were historically reported as natural gas, NGLs and oil sales. This information is intended to bridge the gap between various readers’ understanding and fully disclose the information needed.
The Company discloses in this release the detailed components of many of the single line items shown in the GAAP financial statements included in the Company’s Annual or Quarterly Reports on Form 10-K or 10-Q. The Company believes that it is important to furnish this detail of the various components comprising each line of the Statements of Operations to better inform the reader of the details of each amount, the changes between periods and the effect on its financial results.
We believe that the presentation of PV10 value of our proved reserves is a relevant and useful metric for our investors as supplemental disclosure to the standardized measure, or after-tax amount, because it presents the discounted future net cash flows attributable to our proved reserves before taking into account future corporate income taxes and our current tax structure. While the standardized measure is dependent on the unique tax situation of each company, PV10 is based on prices and discount factors that are consistent for all companies. Because of this, PV10 can be used within the industry and by credit and security analysts to evaluate estimated net cash flows from proved reserves on a more comparable basis.
RANGE RESOURCES CORPORATION (NYSE: RRC) is a leading U.S. independent natural gas and NGL producer with operations focused in the Appalachian Basin. The Company is headquartered in Fort Worth, Texas. More information about Range can be found at .
Included within this release are certain “forward-looking statements” within the meaning of the federal securities laws, including the safe harbor provisions of the Private Securities Litigation Reform Act of 1995, that are not limited to historical facts, but reflect Range’s current beliefs, expectations or intentions regarding future events. Words such as “may,” “will,” “could,” “should,” “expect,” “plan,” “project,” “intend,” “anticipate,” “believe,” “outlook”, “estimate,” “predict,” “potential,” “pursue,” “target,” “continue,” and similar expressions are intended to identify such forward-looking statements.
All statements, except for statements of historical fact, made within regarding activities, events or developments the Company expects, believes or anticipates will or may occur in the future, such as those regarding future well costs, expected asset sales, well productivity, future liquidity and financial resilience, anticipated exports and related financial impact, NGL market supply and demand, future commodity fundamentals and pricing, future capital efficiencies, future shareholder value, emerging plays, capital spending, anticipated drilling and completion activity, acreage prospectivity, expected pipeline utilization and future guidance information, are 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. These statements are based on assumptions and estimates that management believes are reasonable based on currently available information; however, management's assumptions and Range's future performance are subject to a wide range of business risks and uncertainties and there is no assurance that these goals and projections can or will be met. Any number of factors could cause actual results to differ materially from those in the forward-looking statements. Further information on risks and uncertainties is available in Range's filings with the Securities and Exchange Commission (SEC), including its most recent Annual Report on Form 10-K. Unless required by law, Range undertakes no obligation to publicly update or revise any forward-looking statements to reflect circumstances or events after the date they are made.
The SEC permits oil and gas companies, in filings made with the SEC, to disclose proved reserves, which are estimates that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions as well as the option to disclose probable and possible reserves. Range has elected not to disclose its probable and possible reserves in its filings with the SEC. Range uses certain broader terms such as "resource potential,” “unrisked resource potential,” "unproved resource potential" or "upside" or other descriptions of volumes of resources potentially recoverable through additional drilling or recovery techniques that may include probable and possible reserves as defined by the SEC's guidelines. Range has not attempted to distinguish probable and possible reserves from these broader classifications. The SEC’s rules prohibit us from including in filings with the SEC these broader classifications of reserves. These estimates are by their nature more speculative than estimates of proved, probable and possible reserves and accordingly are subject to substantially greater risk of actually being realized. Unproved resource potential refers to Range's internal estimates of hydrocarbon quantities that may be potentially discovered through exploratory drilling or recovered with additional drilling or recovery techniques and have not been reviewed by independent engineers. Unproved resource potential does not constitute reserves within the meaning of the Society of Petroleum Engineer's Petroleum Resource Management System and does not include proved reserves. Area wide unproven resource potential has not been fully risked by Range's management. “EUR”, or estimated ultimate recovery, refers to our management’s estimates of hydrocarbon quantities that may be recovered from a well completed as a producer in the area. These quantities may not necessarily constitute or represent reserves within the meaning of the Society of Petroleum Engineer’s Petroleum Resource Management System or the SEC’s oil and natural gas disclosure rules. Actual quantities that may be recovered from Range's interests could differ substantially. Factors affecting ultimate recovery include the scope of Range's drilling program, which will be directly affected by the availability of capital, drilling and production costs, commodity prices, availability of drilling services and equipment, drilling results, lease expirations, transportation constraints, regulatory approvals, field spacing rules, recoveries of gas in place, length of horizontal laterals, actual drilling results, including geological and mechanical factors affecting recovery rates and other factors. Estimates of resource potential may change significantly as development of our resource plays provides additional data.
In addition, our production forecasts and expectations for future periods are dependent upon many assumptions, including estimates of production decline rates from existing wells and the undertaking and outcome of future drilling activity, which may be affected by significant commodity price or drilling cost changes. Investors are urged to consider closely the disclosure in our most recent Annual Report on Form 10-K, available from our website at or by written request to 100 Throckmorton Street, Suite 1200, Fort Worth, Texas 76102. You can also obtain this Form 10-K on the SEC’s website at or by calling the SEC at 1-800-SEC-0330.
SOURCE: Range Resources Corporation
Range Investor Contact:
Laith Sando, Vice President – Investor Relations
817-869-4267
Range Media Contact:
Mark Windle, Director of Corporate Communications
724-873-3223
| RANGE RESOURCES CORPORATION | |||||||||||||||||||||||
| STATEMENTS OF INCOME | |||||||||||||||||||||||
| Based on GAAP reported earnings with additional | |||||||||||||||||||||||
| details of items included in each line in Form 10-K | |||||||||||||||||||||||
| (Unaudited, in thousands, except per share data) | |||||||||||||||||||||||
| Three Months Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||||||||||
| 2023 | 2022 | % | 2023 | 2022 | % | ||||||||||||||||||
| Revenues and other income: | |||||||||||||||||||||||
| Natural gas, NGLs and oil sales (a) | $ | 603,279 | $ | 1,086,697 | $ | 2,334,661 | $ | 4,911,092 | |||||||||||||||
| Derivative fair value income (loss) | 291,059 | 448,181 | 821,154 | (1,188,506 | ) | ||||||||||||||||||
| Brokered natural gas, marketing and other (b) | 44,460 | 93,335 | 206,552 | 419,776 | |||||||||||||||||||
| ARO settlement (loss) gain (b) | 2 | — | 1 | 8 | |||||||||||||||||||
| Interest income (b) | 1,921 | 381 | 5,937 | 422 | |||||||||||||||||||
| Other (b) | 636 | 1,785 | 6,113 | 4,011 | |||||||||||||||||||
| Total revenues and other income | 941,357 | 1,630,379 | -42 | % | 3,374,418 | 4,146,803 | -19 | % | |||||||||||||||
| Costs and expenses: | |||||||||||||||||||||||
| Direct operating | 22,200 | 22,282 | 94,362 | 82,827 | |||||||||||||||||||
| Direct operating – stock-based compensation (c) | 443 | 376 | 1,723 | 1,459 | |||||||||||||||||||
| Transportation, gathering, processing and compression | 283,061 | 294,228 | 1,113,941 | 1,235,441 | |||||||||||||||||||
| Transportation, gathering, processing and compression – settlements | — | — | — | 7,500 | |||||||||||||||||||
| Taxes other than income | 4,083 | 11,178 | 23,726 | 35,367 | |||||||||||||||||||
| Brokered natural gas and marketing | 44,319 | 95,960 | 200,789 | 424,609 | |||||||||||||||||||
| Brokered natural gas and marketing – stock-based compensation (c) | 491 | 571 | 2,095 | 2,439 | |||||||||||||||||||
| Exploration | 7,193 | 6,654 | 25,280 | 25,194 | |||||||||||||||||||
| Exploration – stock-based compensation (c) | 315 | 415 | 1,250 | 1,578 | |||||||||||||||||||
| Abandonment and impairment of unproved properties | 2,051 | 16,289 | 46,359 | 28,608 | |||||||||||||||||||
| General and administrative | 34,472 | 31,290 | 127,838 | 124,282 | |||||||||||||||||||
| General and administrative – stock-based compensation (c) | 9,389 | 9,778 | 35,850 | 42,023 | |||||||||||||||||||
| General and administrative – lawsuit settlements | 114 | 722 | 1,052 | 1,498 | |||||||||||||||||||
| General and administrative – rig release penalty | — | 532 | — | 532 | |||||||||||||||||||
| General and administrative – bad debt expense | — | (250 | ) | — | (250 | ) | |||||||||||||||||
| Exit costs | 28,279 | 12,088 | 99,940 | 70,337 | |||||||||||||||||||
| Deferred compensation plan (d) | (2,953 | ) | 1,963 | 26,593 | 61,880 | ||||||||||||||||||
| Interest expense | 28,734 | 35,725 | 118,620 | 156,862 | |||||||||||||||||||
| Interest expense – amortization of deferred financing costs (e) | 1,352 | 1,508 | 5,384 | 8,283 | |||||||||||||||||||
| Loss (gain) on early extinguishment of debt | 1 | 261 | (438 | ) | 69,493 | ||||||||||||||||||
| Depletion, depreciation and amortization | 90,968 | 90,847 | 350,165 | 353,420 | |||||||||||||||||||
| (Gain) loss on sale of assets | (101 | ) | 139 | (454 | ) | (409 | ) | ||||||||||||||||
| Total costs and expenses | 554,411 | 632,556 | -12 | % | 2,274,075 | 2,732,973 | -17 | % | |||||||||||||||
| Income before income taxes | 386,946 | 997,823 | -61 | % | 1,100,343 | 1,413,830 | -22 | % | |||||||||||||||
| Income tax (benefit) expense: | |||||||||||||||||||||||
| Current | (1,453 | ) | (6,044 | ) | 1,547 | 14,688 | |||||||||||||||||
| Deferred | 78,365 | 189,631 | 227,654 | 215,772 | |||||||||||||||||||
| 76,912 | 183,587 | 229,201 | 230,460 | ||||||||||||||||||||
| Net income | $ | 310,034 | $ | 814,236 | -62 | % | $ | 871,142 | $ | 1,183,370 | -26 | % | |||||||||||
| Net Income Per Common Share: | |||||||||||||||||||||||
| Basic | $ | 1.29 | $ | 3.38 | $ | 3.61 | $ | 4.79 | |||||||||||||||
| Diluted | $ | 1.27 | $ | 3.31 | $ | 3.57 | $ | 4.69 | |||||||||||||||
| Weighted average common shares outstanding, as reported: | |||||||||||||||||||||||
| Basic | 238,833 | 234,948 | 2 | % | 236,986 | 240,858 | -2 | % | |||||||||||||||
| Diluted | 241,735 | 240,222 | 1 | % | 239,837 | 246,379 | -3 | % | |||||||||||||||
(a) See separate natural gas, NGLs and oil sales information table.
(b) Included in Brokered natural gas, marketing and other revenues in the 10-K.
(c) Costs associated with stock compensation and restricted stock amortization, which have been reflected in the categories associated with the direct personnel costs, which are combined with the cash costs in the 10-K.
(d) Reflects the change in market value of the vested Company stock held in the deferred compensation plan.
(e) Included in interest expense in the 10-K.
| RANGE RESOURCES CORPORATION | |||||||
| BALANCE SHEETS | |||||||
| (In thousands) | December 31, | December 31, | |||||
| 2023 | 2022 | ||||||
| (Audited) | (Audited) | ||||||
| Assets | |||||||
| Current assets | $ | 528,794 | $ | 538,662 | |||
| Derivative assets | 442,971 | 41,915 | |||||
| Natural gas and oil properties, successful efforts method | 6,117,681 | 5,890,404 | |||||
| Other property and equipment | 1,696 | 2,434 | |||||
| Operating lease right-of-use assets | 23,821 | 84,070 | |||||
| Other | 88,922 | 68,077 | |||||
| $ | 7,203,885 | $ | 6,625,562 | ||||
| Liabilities and Stockholders’ Equity | |||||||
| Current liabilities | $ | 580,469 | $ | 864,678 | |||
| Asset retirement obligations | 2,395 | 4,570 | |||||
| Derivative liabilities | 222 | 151,417 | |||||
| Bank debt | — | 9,509 | |||||
| Senior notes | 1,774,229 | 1,832,451 | |||||
| Total debt | 1,774,229 | 1,841,960 | |||||
| Deferred tax liabilities | 561,288 | 333,571 | |||||
| Derivative liabilities | 107 | 15,495 | |||||
| Deferred compensation liabilities | 72,976 | 99,907 | |||||
| Operating lease liabilities | 16,064 | 20,903 | |||||
| Asset retirement obligations and other liabilities | 119,896 | 112,981 | |||||
| Divestiture contract obligation | 310,688 | 304,074 | |||||
| Common stock and retained deficit | 4,213,585 | 3,305,198 | |||||
| Accumulated other comprehensive gain | 647 | 467 | |||||
| Common stock held in treasury stock | (448,681 | ) | (429,659 | ) | |||
| Total stockholders’ equity | 3,765,551 | 2,876,006 | |||||
| $ | 7,203,885 | $ | 6,625,562 | ||||
| RECONCILIATION OF TOTAL REVENUES AND OTHER INCOME TO TOTAL REVENUE EXCLUDING CERTAIN ITEMS, a non-GAAP measure | |||||||||||||||||||||||
| (Unaudited, in thousands) | |||||||||||||||||||||||
| Three Months Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||||||||||
| 2023 | 2022 | % | 2023 | 2022 | % | ||||||||||||||||||
| Total revenues and other income, as reported | $ | 941,357 | $ | 1,630,379 | -42 | % | $ | 3,374,418 | $ | 4,146,803 | -19 | % | |||||||||||
| Adjustment for certain special items: | |||||||||||||||||||||||
| Total change in fair value related to derivatives prior to settlement gain | (226,041 | ) | (632,813 | ) | (567,640 | ) | (1,648 | ) | |||||||||||||||
| ARO settlement gain | (2 | ) | — | (1 | ) | (8 | ) | ||||||||||||||||
| Total revenues, as adjusted, non-GAAP | $ | 715,314 | $ | 997,566 | -28 | % | $ | 2,806,777 | $ | 4,145,147 | -32 | % | |||||||||||
| RANGE RESOURCES CORPORATION | |||||||||||||||||
| CASH FLOWS FROM OPERATING ACTIVITIES | |||||||||||||||||
| (Unaudited in thousands) | |||||||||||||||||
| Three Months Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||||
| 2023 | 2022 | 2023 | 2022 | ||||||||||||||
| Net income | $ | 310,034 | $ | 814,236 | $ | 871,142 | $ | 1,183,370 | |||||||||
| Adjustments to reconcile net cash provided from operating activities: | |||||||||||||||||
| Deferred income tax expense | 78,365 | 189,631 | 227,654 | 215,772 | |||||||||||||
| Depletion, depreciation and amortization | 90,968 | 90,847 | 350,165 | 353,420 | |||||||||||||
| Abandonment and impairment of unproved properties | 2,051 | 16,289 | 46,359 | 28,608 | |||||||||||||
| Derivative fair value (income) loss | (291,059 | ) | (448,181 | ) | (821,154 | ) | 1,188,506 | ||||||||||
| Cash settlements on derivative financial instruments | 65,018 | (184,632 | ) | 253,514 | (1,190,154 | ) | |||||||||||
| Divestiture contract obligation, including accretion | 28,215 | 11,975 | 99,595 | 69,766 | |||||||||||||
| Allowance for bad debts | — | (250 | ) | — | (250 | ) | |||||||||||
| Amortization of deferred issuance costs and other | 1,144 | 1,438 | 4,735 | 7,959 | |||||||||||||
| Deferred and stock-based compensation | 7,683 | 12,562 | 67,849 | 107,959 | |||||||||||||
| (Gain) loss on sale of assets | (101 | ) | 139 | (454 | ) | (409 | ) | ||||||||||
| Loss (gain) on early extinguishment of debt | 1 | 261 | (438 | ) | 69,493 | ||||||||||||
| Changes in working capital: | |||||||||||||||||
| Accounts receivable | (65,334 | ) | 129,358 | 223,081 | (3,286 | ) | |||||||||||
| Other current assets | 8,235 | 1,040 | (1,285 | ) | (18,438 | ) | |||||||||||
| Accounts payable | 7,234 | (35,215 | ) | (77,057 | ) | 17,077 | |||||||||||
| Accrued liabilities and other | (16,359 | ) | 13,157 | (265,814 | ) | (164,649 | ) | ||||||||||
| Net changes in working capital | (66,224 | ) | 108,340 | (121,075 | ) | (169,296 | ) | ||||||||||
| Net cash provided from operating activities | $ | 226,095 | $ | 612,655 | $ | 977,892 | $ | 1,864,744 | |||||||||
| RECONCILIATION OF NET CASH PROVIDED FROM OPERATING ACTIVITIES, AS REPORTED, TO CASH FLOW FROM OPERATIONS BEFORE CHANGES IN WORKING CAPITAL, a non-GAAP measure | |||||||||||||||||
| Three Months Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||||
| 2023 | 2022 | 2023 | 2022 | ||||||||||||||
| Net cash provided from operating activities, as reported | $ | 226,095 | $ | 612,655 | $ | 977,892 | $ | 1,864,744 | |||||||||
| Net changes in working capital | 66,224 | (108,340 | ) | 121,075 | 169,296 | ||||||||||||
| Exploration expense | 7,193 | 6,654 | 25,280 | 25,194 | |||||||||||||
| Lawsuit settlements | 114 | 722 | 1,052 | 1,498 | |||||||||||||
| Transportation, gathering, processing and compression settlements | — | — | — | 7,500 | |||||||||||||
| Non-cash compensation adjustment and other | 272 | 1,256 | 655 | 2,839 | |||||||||||||
| Cash flow from operations before changes in working capital – non-GAAP measure | $ | 299,898 | $ | 512,947 | $ | 1,125,954 | $ | 2,071,071 | |||||||||
| ADJUSTED WEIGHTED AVERAGE SHARES OUTSTANDING | |||||||||||||||||
| (Unaudited, in thousands) | |||||||||||||||||
| Three Months Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||||
| 2023 | 2022 | 2023 | 2022 | ||||||||||||||
| Basic: | |||||||||||||||||
| Weighted average shares outstanding | 241,258 | 240,625 | 241,130 | 246,918 | |||||||||||||
| Stock held by deferred compensation plan | (2,425 | ) | (5,677 | ) | (4,144 | ) | (6,060 | ) | |||||||||
| Adjusted basic | 238,833 | 234,948 | 236,986 | 240,858 | |||||||||||||
| Dilutive: | |||||||||||||||||
| Weighted average shares outstanding | 241,258 | 240,625 | 241,130 | 246,918 | |||||||||||||
| Dilutive stock options under treasury method | 477 | (403 | ) | (1,293 | ) | (539 | ) | ||||||||||
| Adjusted dilutive | 241,735 | 240,222 | 239,837 | 246,379 | |||||||||||||
| RANGE RESOURCES CORPORATION | ||||||||||||||||||||||||
| RECONCILIATION OF NATURAL GAS, NGLs AND OIL SALES AND DERIVATIVE FAIR VALUE INCOME (LOSS) TO CALCULATED CASH REALIZED NATURAL GAS, NGLs AND OIL PRICES WITH AND WITHOUT THIRD PARTY TRANSPORTATION, GATHERING AND COMPRESSION FEES, a non-GAAP measure | ||||||||||||||||||||||||
| (Unaudited, in thousands, except per unit data) | ||||||||||||||||||||||||
| Three Months Ended December 31, | Twelve Months Ended December 31, | |||||||||||||||||||||||
| 2023 | 2022 | % | 2023 | 2022 | % | |||||||||||||||||||
| Natural gas, NGL and oil sales components: | ||||||||||||||||||||||||
| Natural gas sales | $ | 320,393 | $ | 770,571 | $ | 1,234,308 | $ | 3,364,111 | ||||||||||||||||
| NGL sales | 238,423 | 269,517 | 933,791 | 1,308,574 | ||||||||||||||||||||
| Oil sales | 44,463 | 46,609 | 166,562 | 238,407 | ||||||||||||||||||||
| Total oil and gas sales, as reported | $ | 603,279 | $ | 1,086,697 | -44 | % | $ | 2,334,661 | $ | 4,911,092 | -52 | % | ||||||||||||
| Derivative fair value income (loss), as reported: | $ | 291,059 | $ | 448,181 | $ | 821,154 | $ | (1,188,506 | ) | |||||||||||||||
| Cash settlements on derivative financial instruments – (gain) loss: | ||||||||||||||||||||||||
| Natural gas | (59,846 | ) | 203,422 | (256,693 | ) | 1,119,940 | ||||||||||||||||||
| NGLs | — | (6,505 | ) | — | 12,168 | |||||||||||||||||||
| Crude Oil | 2,828 | 12,215 | 11,179 | 82,546 | ||||||||||||||||||||
| Contingent consideration - divestiture | (8,000 | ) | (24,500 | ) | (8,000 | ) | (24,500 | ) | ||||||||||||||||
| Total change in fair value related to commodity derivatives prior to settlement, a non-GAAP measure | $ | 226,041 | $ | 632,813 | $ | 567,640 | $ | 1,648 | ||||||||||||||||
| Transportation, gathering, processing and compression components: | ||||||||||||||||||||||||
| Natural gas | $ | 152,058 | $ | 163,768 | $ | 588,970 | $ | 677,316 | ||||||||||||||||
| NGLs | 130,833 | 130,460 | 524,114 | 565,614 | ||||||||||||||||||||
| Oil | 170 | — | 857 | 11 | ||||||||||||||||||||
| Total transportation, gathering, processing and compression, as reported | $ | 283,061 | $ | 294,228 | $ | 1,113,941 | $ | 1,242,941 | ||||||||||||||||
| Natural gas, NGL and oil sales, including cash-settled derivatives: (c) | ||||||||||||||||||||||||
| Natural gas sales | $ | 380,239 | $ | 567,149 | $ | 1,491,001 | $ | 2,244,171 | ||||||||||||||||
| NGL sales | 238,423 | 276,022 | 933,791 | 1,296,406 | ||||||||||||||||||||
| Oil sales | 41,635 | 34,394 | 155,383 | 155,861 | ||||||||||||||||||||
| Total | $ | 660,297 | $ | 877,565 | -25 | % | $ | 2,580,175 | $ | 3,696,438 | -30 | % | ||||||||||||
| Production of oil and gas during the periods: (a) | ||||||||||||||||||||||||
| Natural gas (mcf) | 141,716,744 | 139,608,416 | 2 | % | 538,084,671 | 539,442,624 | 0 | % | ||||||||||||||||
| NGL (bbl) | 9,571,519 | 9,918,111 | -3 | % | 37,939,700 | 36,392,033 | 4 | % | ||||||||||||||||
| Oil (bbl) | 656,533 | 616,051 | 7 | % | 2,475,306 | 2,715,681 | -9 | % | ||||||||||||||||
| Gas equivalent (mcfe) (b) | 203,085,056 | 202,813,388 | 0 | % | 780,574,707 | 774,088,908 | 1 | % | ||||||||||||||||
| Production of oil and gas – average per day: (a) | ||||||||||||||||||||||||
| Natural gas (mcf) | 1,540,399 | 1,517,483 | 2 | % | 1,474,205 | 1,477,925 | 0 | % | ||||||||||||||||
| NGL (bbl) | 104,038 | 107,806 | -3 | % | 103,944 | 99,704 | 4 | % | ||||||||||||||||
| Oil (bbl) | 7,136 | 6,696 | 7 | % | 6,782 | 7,440 | -9 | % | ||||||||||||||||
| Gas equivalent (mcfe) (b) | 2,207,446 | 2,204,493 | 0 | % | 2,138,561 | 2,120,792 | 1 | % | ||||||||||||||||
| Average prices, excluding derivative settlements and before third party transportation costs: | ||||||||||||||||||||||||
| Natural gas (mcf) | $ | 2.26 | $ | 5.52 | -59 | % | $ | 2.29 | $ | 6.24 | -63 | % | ||||||||||||
| NGL (bbl) | $ | 24.91 | $ | 27.17 | -8 | % | $ | 24.61 | $ | 35.96 | -32 | % | ||||||||||||
| Oil (bbl) | $ | 67.72 | $ | 75.66 | -10 | % | $ | 67.29 | $ | 87.79 | -23 | % | ||||||||||||
| Gas equivalent (mcfe) (b) | $ | 2.97 | $ | 5.36 | -45 | % | $ | 2.99 | $ | 6.34 | -53 | % | ||||||||||||
| Average prices, including derivative settlements before third party transportation costs: (c) | ||||||||||||||||||||||||
| Natural gas (mcf) | $ | 2.68 | $ | 4.06 | -34 | % | $ | 2.77 | $ | 4.16 | -33 | % | ||||||||||||
| NGL (bbl) | $ | 24.91 | $ | 27.83 | -10 | % | $ | 24.61 | $ | 35.62 | -31 | % | ||||||||||||
| Oil (bbl) | $ | 63.42 | $ | 55.83 | 14 | % | $ | 62.77 | $ | 57.39 | 9 | % | ||||||||||||
| Gas equivalent (mcfe) (b) | $ | 3.25 | $ | 4.33 | -25 | % | $ | 3.31 | $ | 4.78 | -31 | % | ||||||||||||
| Average prices, including derivative settlements and after third party transportation costs: (d) | ||||||||||||||||||||||||
| Natural gas (mcf) | $ | 1.61 | $ | 2.89 | -44 | % | $ | 1.68 | $ | 2.90 | -42 | % | ||||||||||||
| NGL (bbl) | $ | 11.24 | $ | 14.68 | -23 | % | $ | 10.80 | $ | 20.08 | -46 | % | ||||||||||||
| Oil (bbl) | $ | 63.16 | $ | 55.82 | 13 | % | $ | 62.43 | $ | 57.39 | 9 | % | ||||||||||||
| Gas equivalent (mcfe) (b) | $ | 1.86 | $ | 2.88 | -35 | % | $ | 1.88 | $ | 3.17 | -41 | % | ||||||||||||
| Transportation, gathering and compression expense per mcfe | $ | 1.39 | $ | 1.45 | -4 | % | $ | 1.43 | $ | 1.61 | -11 | % | ||||||||||||
(a) Represents volumes sold regardless of when produced.
(b) Oil and NGLs are converted at the rate of one barrel equals six mcfe based upon the approximate relative energy content of oil to natural gas, which is not necessarily indicative of the relationship of oil and natural gas prices.
(c) Excluding third party transportation, gathering and compression costs.
(d) Net of transportation, gathering, processing and compression costs.
| RANGE RESOURCES CORPORATION | |||||||||||||||||||||||
| RECONCILIATION OF INCOME BEFORE INCOME TAXES AS REPORTED TO INCOME BEFORE INCOME TAXES EXCLUDING CERTAIN ITEMS, a non-GAAP measure | |||||||||||||||||||||||
| (Unaudited, in thousands, except per share data) | |||||||||||||||||||||||
| Three Months Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||||||||||
| 2023 | 2022 | % | 2023 | 2022 | % | ||||||||||||||||||
| Income from operations before income taxes, as reported | $ | 386,946 | $ | 997,823 | -61 | % | $ | 1,100,343 | $ | 1,413,830 | -22 | % | |||||||||||
| Adjustment for certain special items: | |||||||||||||||||||||||
| (Gain) loss on sale of assets | (101 | ) | 139 | (454 | ) | (409 | ) | ||||||||||||||||
| Gain on ARO settlements | (2 | ) | — | (1 | ) | (8 | ) | ||||||||||||||||
| Change in fair value related to derivatives prior to settlement | (226,041 | ) | (632,813 | ) | (567,640 | ) | (1,648 | ) | |||||||||||||||
| Abandonment and impairment of unproved properties | 2,051 | 16,289 | 46,359 | 28,608 | |||||||||||||||||||
| Loss (gain) on early extinguishment of debt | 1 | 261 | (438 | ) | 69,493 | ||||||||||||||||||
| Transportation, gathering, processing and compression settlements | — | — | — | 7,500 | |||||||||||||||||||
| Lawsuit settlements | 114 | 722 | 1,052 | 1,498 | |||||||||||||||||||
| Exit costs | 28,279 | 12,088 | 99,940 | 70,337 | |||||||||||||||||||
| Brokered natural gas and marketing – stock-based compensation | 491 | 571 | 2,095 | 2,439 | |||||||||||||||||||
| Direct operating – stock-based compensation | 443 | 376 | 1,723 | 1,459 | |||||||||||||||||||
| Exploration expenses – stock-based compensation | 315 | 415 | 1,250 | 1,578 | |||||||||||||||||||
| General & administrative – stock-based compensation | 9,389 | 9,778 | 35,850 | 42,023 | |||||||||||||||||||
| Deferred compensation plan – non-cash adjustment | (2,953 | ) | 1,963 | 26,593 | 61,880 | ||||||||||||||||||
| Income before income taxes, as adjusted | 198,932 | 407,612 | -51 | % | 746,672 | 1,698,580 | -56 | % | |||||||||||||||
| Income tax (benefit) expense, as adjusted | |||||||||||||||||||||||
| Current | (1,453 | ) | (6,044 | ) | 1,547 | 14,688 | |||||||||||||||||
| Deferred (a) | 47,208 | 101,903 | 170,189 | 424,645 | |||||||||||||||||||
| Net income excluding certain items, a non-GAAP measure | $ | 153,177 | $ | 311,753 | -51 | % | $ | 574,936 | $ | 1,259,247 | -54 | % | |||||||||||
| Non-GAAP income per common share | |||||||||||||||||||||||
| Basic | $ | 0.64 | $ | 1.33 | -52 | % | $ | 2.43 | $ | 5.23 | -54 | % | |||||||||||
| Diluted | $ | 0.63 | $ | 1.30 | -52 | % | $ | 2.40 | $ | 5.11 | -53 | % | |||||||||||
| Non-GAAP diluted shares outstanding, if dilutive | 241,735 | 240,222 | 239,837 | 246,379 | |||||||||||||||||||
(a) Taxes are estimated to be approximately 23% for 2023 and deferred taxes were estimated to be 25% for 2022.
| RANGE RESOURCES CORPORATION | ||||||||||||||||
| RECONCILIATION OF NET INCOME, EXCLUDING CERTAIN ITEMS AND ADJUSTED EARNINGS PER SHARE, non-GAAP measures | ||||||||||||||||
| (In thousands, except per share data) | ||||||||||||||||
| Three Months Ended December 31, | Twelve Months Ended December 31, | |||||||||||||||
| 2023 | 2022 | 2023 | 2022 | |||||||||||||
| Net income, as reported | $ | 310,034 | $ | 814,236 | $ | 871,142 | $ | 1,183,370 | ||||||||
| Adjustment for certain special items: | ||||||||||||||||
| (Gain) loss on sale of assets | (101 | ) | 139 | (454 | ) | (409 | ) | |||||||||
| Gain on ARO settlements | (2 | ) | — | (1 | ) | (8 | ) | |||||||||
| Loss (gain) on early extinguishment of debt | 1 | 261 | (438 | ) | 69,493 | |||||||||||
| Change in fair value related to derivatives prior to settlement | (226,041 | ) | (632,813 | ) | (567,640 | ) | (1,648 | ) | ||||||||
| Transportation, gathering, processing and compression settlements | — | — | — | 7,500 | ||||||||||||
| Abandonment and impairment of unproved properties | 2,051 | 16,289 | 46,359 | 28,608 | ||||||||||||
| Lawsuit settlements | 114 | 722 | 1,052 | 1,498 | ||||||||||||
| Exit costs | 28,279 | 12,088 | 99,940 | 70,337 | ||||||||||||
| Stock-based compensation | 10,638 | 11,140 | 40,918 | 47,499 | ||||||||||||
| Deferred compensation plan | (2,953 | ) | 1,963 | 26,593 | 61,880 | |||||||||||
| Tax impact | 31,157 | 87,728 | 57,465 | (208,873 | ) | |||||||||||
| Net income excluding certain items, a non-GAAP measure | $ | 153,177 | $ | 311,753 | $ | 574,936 | $ | 1,259,247 | ||||||||
| Net income per diluted share, as reported | $ | 1.27 | $ | 3.31 | $ | 3.57 | $ | 4.69 | ||||||||
| Adjustment for certain special items per diluted share: | ||||||||||||||||
| (Gain) loss on sale of assets | (0.00 | ) | 0.00 | (0.00 | ) | (0.00 | ) | |||||||||
| Gain on ARO settlements | (0.00 | ) | — | (0.00 | ) | (0.00 | ) | |||||||||
| Loss (gain) on early extinguishment of debt | 0.00 | 0.00 | (0.00 | ) | 0.28 | |||||||||||
| Change in fair value related to derivatives prior to settlement | (0.94 | ) | (2.63 | ) | (2.37 | ) | (0.01 | ) | ||||||||
| Transportation, gathering, processing and compression settlements | — | — | — | 0.03 | ||||||||||||
| Abandonment and impairment of unproved properties | 0.01 | 0.07 | 0.19 | 0.12 | ||||||||||||
| Lawsuit settlements | 0.00 | 0.00 | 0.00 | 0.01 | ||||||||||||
| Exit costs | 0.12 | 0.05 | 0.42 | 0.29 | ||||||||||||
| Stock-based compensation | 0.04 | 0.05 | 0.17 | 0.19 | ||||||||||||
| Deferred compensation plan | (0.01 | ) | 0.01 | 0.11 | 0.25 | |||||||||||
| Adjustment for rounding differences | — | (0.01 | ) | 0.01 | — | |||||||||||
| Tax impact | 0.13 | 0.37 | 0.24 | (0.85 | ) | |||||||||||
| Dilutive share impact (rabbi trust and other) | 0.01 | 0.08 | 0.06 | 0.11 | ||||||||||||
| Net income per diluted share, excluding certain items, a non-GAAP measure | $ | 0.63 | $ | 1.30 | $ | 2.40 | $ | 5.11 | ||||||||
| Adjusted earnings per share, a non-GAAP measure: | ||||||||||||||||
| Basic | $ | 0.64 | $ | 1.33 | $ | 2.43 | $ | 5.23 | ||||||||
| Diluted | $ | 0.63 | $ | 1.30 | $ | 2.40 | $ | 5.11 | ||||||||
| RANGE RESOURCES CORPORATION | ||||||||||||||||
| RECONCILIATION OF CASH MARGIN PER MCFE, a non-GAAP measure | ||||||||||||||||
| (Unaudited, in thousands, except per unit data) | ||||||||||||||||
| Three Months Ended December 31, | Twelve Months Ended December 31, | |||||||||||||||
| 2023 | 2022 | 2023 | 2022 | |||||||||||||
| Revenues | ||||||||||||||||
| Natural gas, NGL and oil sales, as reported | $ | 603,279 | $ | 1,086,697 | $ | 2,334,661 | $ | 4,911,092 | ||||||||
| Derivative fair value income (loss), as reported | 291,059 | 448,181 | 821,154 | (1,188,506 | ) | |||||||||||
| Less non-cash fair value gain | (226,041 | ) | (632,813 | ) | (567,640 | ) | (1,648 | ) | ||||||||
| Brokered natural gas and marketing and other, as reported | 47,019 | 95,501 | 218,603 | 424,217 | ||||||||||||
| Less ARO settlement | (2 | ) | — | (1 | ) | (8 | ) | |||||||||
| Cash revenues | 715,314 | 997,566 | 2,806,777 | 4,145,147 | ||||||||||||
| Expenses | ||||||||||||||||
| Direct operating, as reported | 22,643 | 22,658 | 96,085 | 84,286 | ||||||||||||
| Less direct operating stock-based compensation | (443 | ) | (376 | ) | (1,723 | ) | (1,459 | ) | ||||||||
| Transportation, gathering and compression, as reported | 283,061 | 294,228 | 1,113,941 | 1,242,941 | ||||||||||||
| Less transportation, gathering and compression settlements | — | — | — | (7,500 | ) | |||||||||||
| Taxes other than income, as reported | 4,083 | 11,178 | 23,726 | 35,367 | ||||||||||||
| Brokered natural gas and marketing, as reported | 44,810 | 96,531 | 202,884 | 427,048 | ||||||||||||
| Less brokered natural gas and marketing stock-based compensation | (491 | ) | (571 | ) | (2,095 | ) | (2,439 | ) | ||||||||
| General and administrative, as reported | 43,975 | 42,072 | 164,740 | 168,085 | ||||||||||||
| Less G&A stock-based compensation | (9,389 | ) | (9,778 | ) | (35,850 | ) | (42,023 | ) | ||||||||
| Less lawsuit settlements | (114 | ) | (722 | ) | (1,052 | ) | (1,498 | ) | ||||||||
| Interest expense, as reported | 30,086 | 37,233 | 124,004 | 165,145 | ||||||||||||
| Less amortization of deferred financing costs | (1,352 | ) | (1,508 | ) | (5,384 | ) | (8,283 | ) | ||||||||
| Cash expenses | 416,869 | 490,945 | 1,679,276 | 2,059,670 | ||||||||||||
| Cash margin, a non-GAAP measure | $ | 298,445 | $ | 506,621 | $ | 1,127,501 | $ | 2,085,477 | ||||||||
| Mmcfe produced during period | 203,085 | 202,813 | 780,575 | 774,089 | ||||||||||||
| Cash margin per mcfe | $ | 1.47 | $ | 2.50 | $ | 1.44 | $ | 2.69 | ||||||||
| RECONCILIATION OF INCOME BEFORE INCOME TAXES TO CASH MARGIN | ||||||||||||||||
| (Unaudited, in thousands, except per unit data) | ||||||||||||||||
| Three Months Ended December 31, | Twelve Months Ended December 31, | |||||||||||||||
| 2023 | 2022 | 2023 | 2022 | |||||||||||||
| Income before income taxes, as reported | $ | 386,946 | $ | 997,823 | $ | 1,100,343 | $ | 1,413,830 | ||||||||
| Adjustments to reconcile income before income taxes to cash margin: | ||||||||||||||||
| ARO settlements | (2 | ) | — | (1 | ) | (8 | ) | |||||||||
| Derivative fair value (income) loss | (291,059 | ) | (448,181 | ) | (821,154 | ) | 1,188,506 | |||||||||
| Net cash receipts (payments) on derivative settlements | 65,018 | (184,632 | ) | 253,514 | (1,190,154 | ) | ||||||||||
| Transportation, gathering and compression settlements | — | — | — | 7,500 | ||||||||||||
| Exploration expense | 7,193 | 6,654 | 25,280 | 25,194 | ||||||||||||
| Lawsuit settlements | 114 | 722 | 1,052 | 1,498 | ||||||||||||
| Exit costs | 28,279 | 12,088 | 99,940 | 70,337 | ||||||||||||
| Deferred compensation plan | (2,953 | ) | 1,963 | 26,593 | 61,880 | |||||||||||
| Stock-based compensation (direct operating, brokered natural gas and marketing, general and administrative and termination costs) | 10,638 | 11,140 | 40,918 | 47,499 | ||||||||||||
| Interest – amortization of deferred financing costs | 1,352 | 1,508 | 5,384 | 8,283 | ||||||||||||
| Depletion, depreciation and amortization | 90,968 | 90,847 | 350,165 | 353,420 | ||||||||||||
| (Gain) loss on sale of assets | (101 | ) | 139 | (454 | ) | (409 | ) | |||||||||
| Loss (gain) on early extinguishment of debt | 1 | 261 | (438 | ) | 69,493 | |||||||||||
| Abandonment and impairment of unproved properties | 2,051 | 16,289 | 46,359 | 28,608 | ||||||||||||
| Cash margin, a non-GAAP measure | $ | 298,445 | $ | 506,621 | $ | 1,127,501 | $ | 2,085,477 | ||||||||
