Range Announces Fourth Quarter 2020 Results

Source: Nasdaq GlobeNewswire / 23 Feb 2021 16:44:01 America/New_York

FORT WORTH, Texas, Feb. 23, 2021 (GLOBE NEWSWIRE) -- RANGE RESOURCES CORPORATION (NYSE: RRC) today announced its fourth quarter 2020 financial results, proved reserves and plans for 2021.

Highlights –

All-in 2020 capital spending was $411 million, approximately $109 million less than original budget
Fourth quarter cash unit costs improved by $0.07 per mcfe compared to prior year period
Company record for lease operating expense of $0.08 per mcfe during the quarter
Reduced debt in 2020 by $86 million compared to year-end 2019
All-in 2021 capital budget of $425 million maintains production at ~2.15 Bcfe per day
2021 well costs expected to average $570 per lateral foot, or less, lowest in Appalachia
PV-10 of year-end proved reserves of $8.6 billion, or $22 per share net of debt, assuming NYMEX prices of $2.75 per Mmbtu of natural gas and $50 per barrel of oil
In January 2021, issued $600 million in 2029 notes extending the Company’s debt maturities and enhancing liquidity to $2.0 billion
Updated executive compensation framework to enhance alignment with shareholders and support the Company’s focus on financial strength, environmental leadership, cost improvements, safety and generating sustainable returns for shareholders

Commenting on the results and 2021 plans, Jeff Ventura, the Company’s CEO said, “During 2020, Range reduced debt while purchasing over eight million shares, refinanced near-term maturities, lowered well costs, improved our cost structure and delivered our operational plan safely and for less than budgeted. These results reflect the organization’s continuing focus on capital discipline and further strengthening our financial position as we develop the most prolific natural gas and NGL play in North America. Our resilience is further demonstrated by the underlying efficiency of our 2021 capital program that can maintain production at 2.15 Bcfe per day for only $425 million of all-in capital. Further, our corporate sustainability report displays our industry-leading environmental and safety efforts and aggressive emissions targets. Looking forward, I believe Range’s high-quality asset base, capital discipline, operational efficiencies and leading environmental efforts provide a sustainable business generating competitive free cash flow and returns for shareholders.”

2021 Capital Program

Range’s 2021 all-in capital budget is $425 million. The capital budget includes approximately $400 million for drilling and recompletions, and $25 million for leasehold and other investments. The Company expects to turn to sales 59 Marcellus wells in 2021 with an expected average lateral length of approximately 12,000 feet. Approximately 65% of lateral feet turned to sales in 2021 is expected to be in Range’s liquids rich acreage. Range also anticipates keeping in-progress well inventory approximately unchanged going into 2022, allowing for a repeatable and capital efficient program each year.

The table below summarizes expected 2021 activity and 2020 regarding the number of wells to sales in each area.

	Planned Wells	Wells TIL in
	TIL in 2021	2020
SW PA Super-Rich	17	3
SW PA Wet	18	31
SW PA Dry	24	33
Total Appalachia	59	67

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, non-cash 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, production and ad valorem taxes, 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.

Capital Expenditures

Fourth quarter 2020 drilling and completions expenditures were $93 million and $15 million was invested in acreage and gathering facilities. Total 2020 capital expenditures were $411 million, including $377 million on drilling and completion, and a combined $34 million on acreage, gas gathering systems and other.

Financial Position

Range reduced outstanding debt by $86 million during 2020, marking the third consecutive year of debt reduction which totals $1.0 billion since the end of 2017. As of December 31, 2020, Range had total debt outstanding of $3.1 billion, consisting of $702 million in bank debt, $2.4 billion in senior notes and $37 million in senior subordinated notes.

During the year, Range repurchased in the open market and retired approximately $161 million in principal amount of its senior and subordinated notes at a weighted average discount to par of 25%. Range also repurchased 8.2 million shares of the Company’s common stock during the year at an average price of $2.80 per share.

In January 2021, Range issued $600.0 million aggregate principal amount of 8.25% senior notes due 2029 and used net proceeds to repay borrowings under its bank credit facility. Proforma the offering, the Company has approximately $2.0 billion of borrowing capacity available under the commitment amount. Range has less than $0.3 billion in notes that mature through 2022, which are expected to be redeemed via free cash flow at strip pricing.

Fourth Quarter 2020 Results

GAAP revenues for fourth quarter 2020 totaled $599 million, GAAP net cash provided from operating activities (including changes in working capital) was $90 million, and GAAP net income was $38 million ($0.15 per diluted share). Fourth quarter earnings results include a $86 million mark-to-market derivative gain due to decreases in commodity prices.

Non-GAAP revenues for fourth quarter 2020 totaled $531 million, and cash flow from operations before changes in working capital, a non-GAAP measure, was $108 million. Adjusted net income comparable to analysts’ estimates, a non-GAAP measure, was $4 million ($0.02 per diluted share) in fourth quarter 2020.

The following table details Range’s fourth quarter 2020 unit costs per mcfe^(a):

	4Q 2020		4Q 2019		Increase
Expenses	(per mcfe)		(per mcfe)		(Decrease)

Direct operating	$	0.08	$	0.15	(47%)
Transportation, gathering,
processing and compression		1.34		1.39	(4%)
Production and ad valorem taxes		0.02		0.04	(50%)
General and administrative^(a)		0.16		0.14	14%
Interest expense^(a)		0.24		0.19	26%
Total cash unit costs^(b)		1.84		1.92	(4%)
Depletion, depreciation and
amortization (DD&A)		0.47		0.61	(23%)
Total unit costs plus DD&A^(b)	$	2.32	$	2.53	(8%)

(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 2020:

	4Q20 Production & Realized Pricing
										Natural Gas
	Natural Gas			Oil			NGLs			Equivalent
	(Mcf)			(Bbl)			(Bbl)			(Mcfe)

Net Production per day		1,464,834			6,356			97,453			2,087,690

Average NYMEX price	$	2.67		$	42.70
Differential, including basis hedging		(0.57	)		(10.91	)
Realized prices before NYMEX hedges		2.10			31.79		$	18.02		$	2.41
Settled NYMEX hedges		(0.03	)		14.33			(0.53	)		0.00
Average realized prices after hedges	$	2.07		$	46.12		$	17.49		$	2.41

Range’s fourth quarter production was approximately 2.1 Bcfe net per day, including the impact of curtailed production during fourth quarter in response to low prices and infrastructure maintenance. The deferred production has benefited from improving prices across all products into mid-December and early 2021. By area, southwest Marcellus production averaged 2.0 Bcfe per day while the northeast Marcellus assets averaged 83 net Mmcf per day during the quarter.

Fourth quarter 2020 natural gas, NGLs and oil price realizations (including the impact of cash-settled hedges and derivative settlements which correspond to analysts’ estimates) averaged $2.41 per mcfe.

The average natural gas price, including the impact of basis hedging, was $2.10 per mcf, or a ($0.57) per mcf differential to NYMEX. The fourth quarter natural gas differential was impacted by storage levels in multiple regions as well as a late start to winter weather. Starting in December and into 2021, basis in each region has normalized, improving the Company’s first quarter 2021 natural gas differential to NYMEX within an expected range of ($0.20) to ($0.25) per mcf.
Pre-hedge NGL realizations were $18.02 per barrel, an improvement of $1.75 per barrel versus the previous quarter driven by an improving market for propane and heavier products. NGL prices have improved further in early 2021, as the Mont Belvieu weighted equivalent is currently trading above $25 per barrel in the first quarter. In addition, Range continues to see strong NGL export premiums at Marcus Hook and expects to maintain an average 2021 pre-hedge premium differential of between $0.00 - $2.00 per barrel to Mont Belvieu equivalent, as a result of access to international markets and a diversified portfolio of sales agreements.
Crude oil and condensate price realizations, before realized hedges, averaged $31.79 per barrel, or $10.91 below WTI (West Texas Intermediate). Range expects an improving condensate differential to WTI during 2021, between $7-$9 below NYMEX, as regional production continues to decline and demand for transportation fuels is expected to recover.

Transportation and Gathering

Since the end of 2018, Range has reduced transportation and gathering expenses per unit of production by $0.17 per mcfe, from $1.51 to $1.34 in the fourth quarter of 2020. The two-year improvement has been driven by full utilization of both gathering and firm transport infrastructure. In 2021, Range will have an additional 5,000 barrels per day of Mariner East capacity, which is expected to be fully utilized with existing production. Range continues to expect near-term and long-term benefits of NGL exports out of the Northeast as international demand for NGL products continues to grow. NGL export out of Marcus Hook provides a unique supply option for that demand. In 2021, Range expects to export over 80% of its propane and butane, the highest percentage of propane and butane exported by any U.S. independent, leading to strong year-over-year improvements in NGL pricing and margins. Higher realized NGL prices for Range in 2021 will lead to a slight increase in processing costs as Range’s processing costs are based on the price received, providing a natural hedge against NGL price changes as the expense follows the direction of NGL prices.

Beyond 2021, Range anticipates transportation and gathering expenses to decline in absolute terms assuming continued maintenance of existing production levels. By 2025 Range expects annual gathering expense relative to 2021 to decline by approximately $70 million, and more than $100 million per year by 2030. Importantly, the cost improvements are a result of existing gathering arrangements and do not reflect targeted amounts. Further improvements are also expected beyond 2030 in a production maintenance scenario. Range also has multiple firm transportation agreements with renewal elections during this timeframe and Range will have the option of letting capacity expire depending on market conditions. Transportation renewals relative to 2021 represent an additional $175 million in potential cost improvements by 2030.

2020 Proved Reserves

Year-end 2020 proved reserves were 17.2 Tcfe, essentially unchanged year-over-year after adjusting for asset sales and price revisions. By volume, proved reserves were 65% natural gas, 33% natural gas liquids and 2% crude oil and condensate. Proved developed reserves represent 57% of the Company’s reserves.

Summary of Changes in Proved Reserves
(in Bcfe)

Balance at December 31, 2019	18,192

Extensions, discoveries and additions	1,264
Performance revisions	420

Reclassification of PUD to unproved under SEC 5-year rule	(961	)
Price revisions	(68	)
Sales of proved reserves	(828	)
Production	(816	)

Balance at December 31, 2020	17,203

During 2020, Range added 1.3 Tcfe of proved reserves through the drill-bit, driven by the Marcellus shale development. Field level performance increased reserves by 312 Bcfe due to continued improvement in the well performance of existing Marcellus producing wells and 109 Bcfe of reserves associated with proved undeveloped locations which have re-entered the Company’s five-year drilling program. Range removed 961 Bcfe of proved undeveloped reserves that now fall outside the SEC mandated five-year development window, but the Company expects these proved undeveloped reserves to be added back in future years. The Company sold approximately 828 Bcfe of reserves during the year, associated with the North Louisiana asset. As shown in the table below the present value (PV₁₀) of reserves under SEC methodology was $3.1 billion at December 31, 2020. The valuation was impacted by lower first-of-month pricing required under SEC methodology. For comparison, the PV₁₀ using NYMEX reference prices of $2.75 per Mmbtu for natural gas and $50 per barrel of oil would have been $8.6 billion, assuming the same proven reserve volumes.

	2020 SEC	Flat Price
	Pricing^(a)	Example^(b)

Natural Gas Price ($/Mmbtu)	$1.98	$2.75
WTI Oil Price ($/Bbl)	$39.77	$50.00
NGL Price ($/Bbl)	$16.14	$20.55

Proved Reserves PV₁₀ ($ billions)	$3.0	$8.6

(a)	SEC benchmark prices adjusted for energy content, quality and basis differentials were $1.68 per mcf and $30.13 per barrel of crude oil
(b)	Example NYMEX prices adjusted for energy content, quality and basis differentials were $2.53 per mcf and $43.00 per barrel of crude oil

Year-end 2020 reserves included 7.4 Tcfe of proved undeveloped reserves from 361 wells planned to be developed within the next five years with an expected development cost of $0.32 per Mcfe. Beyond the five-year reserve calculation window, Range has approximately 2,700 additional Marcellus locations available for development in Southwest Pennsylvania. Range also has a network of over 200 existing well pads designed to accommodate an average of 20 wells per pad from any combination of Marcellus, Utica or Upper Devonian horizons. On average, existing pads currently contain six producing wells, providing Range the opportunity to develop thousands of future wells while utilizing existing roads, pads and infrastructure. In 2021, over 60% of the wells planned to turn to sales are from pad sites with existing production, similar to recent years.

The table below reflects Range’s estimate of the remaining core drilling inventory for the Marcellus.

Estimated Future Marcellus Drilling Locations - December 31, 2020
(Excludes Utica and Upper Devonian locations)

		Assumed	Producing	Undrilled
Area	Net Acres	Lateral Length	Locations⁽¹⁾	Locations⁽²⁾
SW Marcellus - Liquids areas	~350,000	10,000 ft.	480	2,600
SW Marcellus – Dry area	~110,000	10,000 ft.	220	500
Total	~460,000		700	~3,100

(1) Producing locations adjusted to 10,000 foot equivalent
(2) Includes anticipated down-spacing activity

Guidance – 2021

Capital & Production Guidance

Range’s 2021 all-in capital budget is $425 million. Production for full-year 2021 is expected to average approximately 2.15 Bcfe per day, with ~30% attributed to liquids production.

Full Year 2021 Expense Guidance

Direct operating expense:	$0.09 - $0.11 per mcfe
Transportation, gathering, processing and compression expense:	$1.35 - $1.40 per mcfe
Production tax expense:	$0.02 - $0.04 per mcfe
Exploration expense:	$24.0 - $30.0 million
G&A expense:	$0.15 - $0.16 per mcfe
Interest expense:	$0.26 - $0.28 per mcfe
DD&A expense:	$0.47 - $0.50 per mcfe
Net brokered gas marketing expense:	$10.0 - $16.0 million

Full Year 2021 Price Guidance

Based on current market indications, Range expects to average the following price differentials for its production in 2021.

Natural Gas:⁽¹⁾	NYMEX minus $0.30 to $0.40
Natural Gas Liquids (including ethane):⁽²⁾	Mont Belvieu plus $0.00 to $2.00 per barrel
Oil/Condensate:	WTI minus $7.00 to $9.00

(1) Including basis hedging
(2) Weighting based on 53% ethane, 27% propane, 7% normal butane, 4% iso-butane and 9% natural gasoline.

Hedging Status

Range hedges portions of its expected future production volumes to increase the predictability of cash flow and to help maintain a strong, flexible financial position. As of January 31^st, Range had approximately 70% of its expected 2021 natural gas production hedged at an average ceiling price of $2.79 per Mmbtu and an average floor price of $2.60 per Mmbtu. Similarly, Range hedged approximately 50% of projected 2021 crude oil production at an average floor price of $46.84 per barrel and approximately 20% of its expected 2021 NGL revenue. Please see the detailed hedging schedule posted on the Range website under Investor Relations - Financial Information.

Range has also hedged Marcellus and other basis differentials for natural gas and NGL exports to limit volatility between benchmarks and regional prices. The combined fair value of the natural gas basis, NGL freight and spread hedges as of December 31, 2020 was a net gain of $5.6 million.

Conference Call Information

A conference call to review the financial results is scheduled on Wednesday, February 24 at 9:00 a.m. ET. To participate in the call, please dial (877) 928-8777 and provide conference code 1058978 about 10 minutes prior to the scheduled start time.

A simultaneous webcast of the call may be accessed at www.rangeresources.com. The webcast will be archived for replay on the Company's website until March 24.

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 Report on Form 10-K. 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.

Finding and development cost per unit is a non-GAAP metric used in the exploration and production industry by companies, investors and analysts. Drill-bit development cost per mcfe is based on estimated and unaudited drilling, development and exploration costs incurred divided by the total of reserve additions, performance and price revisions. These calculations do not include the future development costs required for the development of proved undeveloped reserves. This reserves metric may not be comparable to similarly titled measurements used by other companies. The U.S. Securities and Exchange Commission (the “SEC”) method of computing finding costs contains additional cost components and results in a higher number. A reconciliation of the two methods is shown on our website at www.rangeresources.com.

The reserve replacement ratio and finding and development cost per unit are statistical indicators that have limitations, including their predictive and comparative value. As an annual measure, the reserve replacement ratio can be limited because it may vary widely based on the extent and timing of new discoveries and the varying effects of changes in prices and well performance. In addition, since the reserve replacement ratio and finding and development cost per unit do not consider the cost or timing of future production of new reserves, such measures may not be an adequate measure of value creation.

We believe that the presentation of PV₁₀ is relevant and useful to 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 creditors 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 on stacked-pay projects in the Appalachian Basin. The Company is headquartered in Fort Worth, Texas. More information about Range can be found at www.rangeresources.com.

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, improving 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 declines or drilling cost increases. Investors are urged to consider closely the disclosure in our most recent Annual Report on Form 10-K, available from our website at www.rangeresources.com 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 www.sec.gov or by calling the SEC at 1-800-SEC-0330.

Range Investor Contacts:

Laith Sando, Vice President – Investor Relations
817-869-4267
lsando@rangeresources.com

Range Media Contacts:

Mark Windle, Director of Corporate Communications
724-873-3223
mwindle@rangeresources.com

RANGE RESOURCES CORPORATION

STATEMENTS OF OPERATIONS
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,
	2020			2019			%			2020			2019			%

Revenues and other income:
Natural gas, NGLs and oil sales (a)	$	444,806		$	545,438					$	1,607,713		$	2,255,425
Derivative fair value income		85,529			18,491						187,711			226,681
Brokered natural gas, marketing and other (b)		67,771			41,524						171,622			344,372
ARO settlement loss (b)		(4	)		(2	)					(22	)		(13	)
Other (b)		784			153						1,673			1,150
Total revenues and other income		598,886			605,604			-1	%		1,968,697			2,827,615			-30	%

Costs and expenses:
Direct operating		15,945			33,323						91,079			134,348
Direct operating – non-cash stock-based compensation (c)		268			469						1,078			1,928
Transportation, gathering, processing and compression		256,742			299,511						1,088,490			1,199,297
Production and ad valorem taxes		3,935			8,963						24,617			37,967
Brokered natural gas and marketing		69,053			46,199						186,900			358,036
Brokered natural gas and marketing – non-cash
stock-based compensation (c)		511			333						1,416			1,856
Exploration		9,076			9,156						31,375			35,117
Exploration – non-cash stock-based compensation (c)		388			194						1,279			1,566
Abandonment and impairment of unproved properties		2,730			1,193,711						19,334			1,235,342
General and administrative		31,307			30,269						123,859			137,694
General and administrative – non-cash stock-based
compensation (c)		8,834			7,500						32,905			35,061
General and administrative – lawsuit settlements		579			542						2,251			2,577
General and administrative – rig release penalty		—			—						—			1,436
General and administrative – bad debt expense		—			4,482						400			4,341
Exit and termination costs		13,739			4,535						545,244			7,535
Exit and termination costs – non-cash stock-based
compensation (c)		145			1,946						2,165			1,971
Deferred compensation plan (d)		2,254			960						12,541			(15,472	)
Interest expense		46,389			42,043						184,201			186,916
Interest expense – amortization of deferred financing costs (e)		2,137			1,981						8,466			7,369
Gain on early extinguishment of debt		25			(2,430	)					(14,068	)		(5,415	)
Depletion, depreciation and amortization		90,551			130,869						394,330			548,843
Impairment of proved property and other assets		—			1,095,634						78,955			1,095,634
Loss (gain) on sale of assets		1,652			(407	)					(110,791	)		30,256
Total costs and expenses		556,260			2,909,783			-81	%		2,706,026			5,044,203			-46	%

Income (loss) before income taxes		42,626			(2,304,179	)		102	%		(737,329	)		(2,216,588	)		67	%

Income tax (benefit) expense:
Current		(157	)		2,068						(523	)		6,147
Deferred		4,382			(500,927	)					(25,029	)		(506,438	)
		4,225			(498,859	)					(25,552	)		(500,291	)

Net income (loss)	$	38,401		$	(1,805,320	)		102	%	$	(711,777	)	$	(1,716,297	)		59	%

Net Income (Loss) Per Common Share:
Basic	$	0.16		$	(7.27	)				$	(2.95	)	$	(6.92	)
Diluted	$	0.15		$	(7.27	)				$	(2.95	)	$	(6.92	)

Weighted average common shares outstanding, as reported:
Basic		240,174			248,277			-3	%		241,373			247,970			-3	%
Diluted		246,286			248,277			-1	%		241,373			247,970			-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,
	2020			2019
	(Audited)			(Audited)
Assets
Current assets	$	266,508		$	290,954
Derivative assets		40,012			137,554
Natural gas and oil properties, successful efforts method		5,686,809			6,041,035
Transportation and field assets		4,161			5,375
Operating lease right-of-use assets		63,581			62,053
Other		75,865			75,432
	$	6,136,936		$	6,612,403

Liabilities and Stockholders’ Equity
Current liabilities	$	673,445		$	551,032
Asset retirement obligations		6,689			2,393
Derivative liabilities		26,707			13,119

Bank debt		693,123			464,319
Senior notes		2,329,745			2,659,844
Senior subordinated notes		17,384			48,774
Total debt		3,040,252			3,172,937

Deferred tax liability		135,267			160,196
Derivative liabilities		9,746			949
Deferred compensation liability		81,481			64,070
Operating lease liabilities		43,155			41,068
Asset retirement obligations and other liabilities		91,157			259,151
Divestiture contract obligation		391,502			—

Common stock and retained deficit		1,668,146			2,355,512
Other comprehensive loss		(479	)		(788	)
Common stock held in treasury stock		(30,132	)		(7,236	)
Total stockholders’ equity		1,637,535			2,347,488
	$	6,136,936		$	6,612,403

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,
	2020			2019		%			2020		2019			%

Total revenues and other income, as reported	$	598,886		$	605,604		-1	%	$	1,968,697	$	2,827,615			-30	%
Adjustment for certain special items:
Total change in fair value related to derivatives
prior to settlement (gain) loss		(68,143	)		31,544					134,918		(38,297	)
ARO settlement (gain) loss		4			2					22		13
Total revenues, as adjusted, non-GAAP	$	530,747		$	637,150		-17	%	$	2,103,637	$	2,789,331			-25	%

RANGE RESOURCES CORPORATION

CASH FLOWS FROM OPERATING ACTIVITIES
(Unaudited in thousands)

	Three Months Ended December 31,						Twelve Months Ended December 31,
	2020			2019			2020			2019

Net income (loss)	$	38,401		$	(1,805,320	)	$	(711,777	)	$	(1,716,297	)
Adjustments to reconcile net cash provided from continuing operations:
Deferred income tax benefit		4,382			(500,927	)		(25,029	)		(506,438	)
Depletion, depreciation, amortization and impairment		90,551			1,226,503			473,285			1,644,477
Exploration dry hole and impairment costs		888			(11	)		888			(11	)
Abandonment and impairment of unproved properties		2,730			1,193,711			19,334			1,235,342
Derivative fair value loss (income)		(85,529	)		(18,491	)		(187,711	)		(226,681	)
Cash settlements on derivative financial instruments		17,386			50,035			322,629			188,384
Divestiture contract obligation		13,245			—			499,934			—
Allowance for bad debts		—			4,482			400			4,341
Amortization of deferred issuance costs and other		1,896			1,593			6,919			6,455
Deferred and stock-based compensation		10,172			10,481			48,552			24,891
Loss (gain) on sale of assets and other		1,652			(407	)		(110,791	)		30,256
Loss (gain) on early extinguishment of debt		25			(2,430	)		(14,068	)		(5,415	)

Changes in working capital:
Accounts receivable		(66,804	)		(27,318	)		24,539			214,196
Inventory and other		6,796			8,544			1,010			4,520
Accounts payable		20,134			(7,729	)		(32,686	)		(60,374	)
Accrued liabilities and other		33,781			(304	)		(46,748	)		(155,803	)
Net changes in working capital		(6,093	)		(26,807	)		(53,885	)		2,539
Net cash provided from operating activities	$	89,706		$	132,412		$	268,680		$	681,843



RECONCILIATION OF NET CASH PROVIDED FROM OPERATING ACTIVITIES, AS REPORTED, TO CASH FLOW FROM OPERATIONS BEFORE CHANGES IN WORKING CAPITAL, a non-GAAP measure
(Unaudited, in thousands)

	Three Months Ended December 31,						Twelve Months Ended December 31,
	2020			2019			2020			2019
Net cash provided from operating activities, as reported	$	89,706		$	132,412		$	268,680		$	681,843
Net changes in working capital		6,093			26,807			53,885			(2,539	)
Exploration expense		8,188			9,167			30,487			35,128
Lawsuit settlements		579			542			2,251			2,577
Exit and termination costs – severance costs only		271			4,535			5,908			7,535
Accrued transportation contract release including accretion		222			—			10,900			—
One-time midstream termination payment		—			—			28,500			—
Rig release penalty		—			—			—			1,436
Non-cash compensation adjustment		2,474			1,311			4,403			2,946
Cash flow from operations before changes in working capital – non-GAAP measure	$	107,533		$	174,774		$	405,014		$	728,926



ADJUSTED WEIGHTED AVERAGE SHARES OUTSTANDING
(Unaudited, in thousands)

	Three Months Ended December 31,						Twelve Months Ended December 31,
	2020			2019			2020			2019
Basic:
Weighted average shares outstanding		246,320			251,430			247,050			251,105
Stock held by deferred compensation plan		(6,146	)		(3,153	)		(5,677	)		(3,135	)
Adjusted basic		240,174			248,277			241,373			247,970

Dilutive:
Weighted average shares outstanding		246,320			251,430			247,050			251,105
Dilutive stock options under treasury method		(34	)		(3,153	)		(5,677	)		(3,135	)
Adjusted dilutive		246,286			248,277			241,373			247,970

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,
	2020			2019			%			2020			2019			%
Natural gas, NGL and oil sales components:
Natural gas sales	$	264,646		$	325,515					$	943,740		$	1,388,838
NGL sales		161,569			173,099						578,454			681,134
Oil sales		18,591			46,824						85,519			185,453
Total oil and gas sales, as reported	$	444,806		$	545,438			-18	%	$	1,607,713		$	2,255,425			-29	%

Derivative fair value income (loss), as reported:	$	85,529		$	18,491					$	187,711		$	226,681
Cash settlements on derivative financial instruments – (gain) loss:
Natural gas		(13,753	)		(46,920	)					(258,797	)		(139,253	)
NGLs		4,745			(3,233	)					(11,288	)		(51,068	)
Crude Oil		(8,378	)		118						(52,544	)		1,937
Total change in fair value related to derivatives prior to settlement, a non-GAAP measure	$	68,143		$	(31,544	)				$	(134,918	)	$	38,297

Transportation, gathering, processing and compression components:
Natural gas	$	155,766		$	185,273					$	650,071		$	740,061
NGLs		100,983			114,238						437,474			459,236
Oil		(7	)		—						945			—
Total transportation, gathering, processing and compression, as reported	$	256,742		$	299,511					$	1,088,490		$	1,199,297

Natural gas, NGL and oil sales, including cash-settled derivatives: (c)
Natural gas sales	$	278,399		$	372,435					$	1,202,537		$	1,528,091
NGL sales		156,824			176,332						589,742			732,202
Oil sales		26,969			46,706						138,063			183,516
Total	$	462,192		$	595,473			-22	%	$	1,930,342		$	2,443,809			-21	%

Production of oil and gas during the periods (a):
Natural gas (mcf)		134,764,765			150,708,420			-11	%		574,529,290			578,114,351			-1	%
NGL (bbl)		8,965,697			9,879,081			-9	%		37,491,546			38,850,130			-3	%
Oil (bbl)		584,754			962,390			-39	%		2,829,495			3,689,805			-23	%
Gas equivalent (mcfe) (b)		192,067,471			215,757,246			-11	%		816,455,536			833,353,961			-2	%

Production of oil and gas – average per day (a):
Natural gas (mcf)		1,464,834			1,638,135			-11	%		1,569,752			1,583,875			-1	%
NGL (bbl)		97,453			107,381			-9	%		102,436			106,439			-4	%
Oil (bbl)		6,356			10,461			-39	%		7,731			10,109			-24	%
Gas equivalent (mcfe) (b)		2,087,690			2,345,187			-11	%		2,230,753			2,283,162			-2	%

Average prices, excluding derivative settlements and before third party transportation costs:
Natural gas (mcf)	$	1.96		$	2.16			-9	%	$	1.64		$	2.40			-32	%
NGL (bbl)	$	18.02		$	17.52			3	%	$	15.43		$	17.53			-12	%
Oil (bbl)	$	31.79		$	48.65			-35	%	$	30.22		$	50.26			-40	%
Gas equivalent (mcfe) (b)	$	2.32		$	2.53			-8	%	$	1.97		$	2.71			-27	%

Average prices, including derivative settlements before third party transportation costs: (c)
Natural gas (mcf)	$	2.07		$	2.47			-16	%	$	2.09		$	2.64			-21	%
NGL (bbl)	$	17.49		$	17.85			-2	%	$	15.73		$	18.85			-17	%
Oil (bbl)	$	46.12		$	48.53			-5	%	$	48.79		$	49.74			-2	%
Gas equivalent (mcfe) (b)	$	2.41		$	2.76			-13	%	$	2.36		$	2.93			-19	%

Average prices, including derivative settlements and after third party transportation costs: (d)
Natural gas (mcf)	$	0.91		$	1.24			-27	%	$	0.96		$	1.36			-29	%
NGL (bbl)	$	6.23		$	6.29			-1	%	$	4.06		$	7.03			-42	%
Oil (bbl)	$	46.13		$	48.53			-5	%	$	48.46		$	49.74			-3	%
Gas equivalent (mcfe) (b)	$	1.07		$	1.37			-22	%	$	1.03		$	1.49			-31	%

Transportation, gathering and compression expense per mcfe	$	1.34		$	1.39			-4	%	$	1.33		$	1.44			-7	%

	(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,
	2020			2019			%			2020			2019			%

Income (loss) from operations before income taxes, as reported	$	42,626		$	(2,304,179	)		102	%	$	(737,329	)	$	(2,216,588	)		67	%
Adjustment for certain special items:
Loss (gain) on sale of assets		1,652			(407	)					(110,791	)		30,256
Loss on ARO settlements		4			2						22			13
Change in fair value related to derivatives prior to settlement		(68,143	)		31,544						134,918			(38,297	)
Abandonment and impairment of unproved properties		2,730			1,193,711						19,334			1,235,342
Rig release penalty		—			—						—			1,436
Loss (gain) on early extinguishment of debt		25			(2,430	)					(14,068	)		(5,415	)
Impairment of proved property and other assets		—			1,095,634						78,955			1,095,634
Lawsuit settlements		579			542						2,251			2,577
Exit and termination costs		13,739			4,535						545,244			7,535
Exit and termination costs – non-cash stock-based compensation		145			1,946						2,165			1,971
Brokered natural gas and marketing – non-cash stock-based compensation		511			333						1,416			1,856
Direct operating – non-cash stock-based compensation		268			469						1,078			1,928
Exploration expenses – non-cash stock-based compensation		388			194						1,279			1,566
General & administrative – non-cash stock-based compensation		8,834			7,500						32,905			35,061
Deferred compensation plan – non-cash adjustment		2,254			960						12,541			(15,472	)

Income (loss) before income taxes, as adjusted		5,612			30,354			-82	%		(30,080	)		139,403			-122	%

Income tax expense (benefit), as adjusted
Current		(157	)		2,068						(523	)		6,147
Deferred (a)		1,403			7,588						(7,520	)		34,867
Net income (loss) excluding certain items, a non-GAAP measure	$	4,366		$	20,698			-79	%	$	(22,037	)	$	98,389			-122	%

Non-GAAP income (loss) per common share
Basic	$	0.02		$	0.08			-75	%	$	(0.09	)	$	0.40			-123	%
Diluted	$	0.02		$	0.08			-75	%	$	(0.09	)	$	0.40			-123	%

Non-GAAP diluted shares outstanding, if dilutive		246,286			248,889						241,373			249,054

	(a)	Deferred taxes are estimated to be approximately 25% for 2020 and 2019.

RANGE RESOURCES CORPORATION

RECONCILIATION OF NET INCOME (LOSS), 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,
	2020			2019			2020			2019

Net income (loss), as reported	$	38,401		$	(1,805,320	)	$	(711,777	)	$	(1,716,297	)
Adjustment for certain special items:
Loss (gain) on sale of assets		1,652			(407	)		(110,791	)		30,256
Loss (gain) on ARO settlements		4			2			22			13
Gain on early extinguishment of debt		25			(2,430	)		(14,068	)		(5,415	)
Change in fair value related to derivatives prior to settlement		(68,143	)		31,544			134,918			(38,297	)
Impairment of proved property		—			1,095,634			78,955			1,095,634
Abandonment and impairment of unproved properties		2,730			1,193,711			19,334			1,235,342
Lawsuit settlements		579			542			2,251			2,577
Rig release penalty		—			—			—			1,436
Exit and termination costs		13,739			4,535			545,244			7,535
Non-cash stock-based compensation		10,146			10,442			38,843			42,382
Deferred compensation plan		2,254			960			12,541			(15,472	)
Tax impact		2,979			(508,515	)		(17,509	)		(541,305	)

Net income (loss) excluding certain items, a non-GAAP measure	$	4,366		$	20,698		$	(22,037	)	$	98,389

Net income (loss) per diluted share, as reported	$	0.15		$	(7.27	)	$	(2.95	)	$	(6.92	)
Adjustment for certain special items per diluted share:
Loss (gain) on sale of assets		0.01			(0.00	)		(0.46	)		0.12
Loss (gain) on ARO settlements		0.00			0.00			0.00			0.00
Loss (gain) on early extinguishment of debt		0.00			(0.01	)		(0.06	)		(0.02	)
Change in fair value related to derivatives prior to settlement		(0.28	)		0.13			0.56			(0.15	)
Impairment of proved property and other assets		—			4.41			0.33			4.42
Abandonment and impairment of unproved properties		0.01			4.81			0.08			4.98
Lawsuit settlements		0.00			0.00			0.01			0.01
Rig release penalty		—			—			—			0.01
Exit and termination costs		0.06			0.02			2.26			0.03
Non-cash stock-based compensation		0.04			0.04			0.16			0.17
Deferred compensation plan		0.01			0.00			0.05			(0.06	)
Adjustment for rounding differences		0.01			—			—			(0.01	)
Tax impact		0.01			(2.05	)		(0.07	)		(2.18	)

Net income (loss) per diluted share, excluding certain items, a non-
GAAP measure	$	0.02		$	0.08		$	(0.09	)	$	0.40

Adjusted earnings per share, a non-GAAP measure:
Basic	$	0.02		$	0.08		$	(0.09	)	$	0.40
Diluted	$	0.02		$	0.08		$	(0.09	)	$	0.40

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,
	2020			2019			2020			2019

Revenues
Natural gas, NGL and oil sales, as reported	$	444,806		$	545,438		$	1,607,713		$	2,255,425
Derivative fair value income, as reported		85,529			18,491			187,711			226,681
Less non-cash fair value (gain) loss		(68,143	)		31,544			134,918			(38,297	)
Brokered natural gas and marketing and other, as reported		68,551			41,675			173,273			345,509
Less ARO settlement and other (gains) losses		(780	)		(151	)		(1,651	)		(1,137	)
Cash revenue applicable to production		529,963			636,997			2,101,964			2,788,181

Expenses
Direct operating, as reported		16,213			33,792			92,157			136,276
Less direct operating stock-based compensation		(268	)		(469	)		(1,078	)		(1,928	)
Transportation, gathering and compression, as reported		256,742			299,511			1,088,490			1,199,297
Production and ad valorem taxes, as reported		3,935			8,963			24,617			37,967
Brokered natural gas and marketing, as reported		69,564			46,532			188,316			359,892
Less brokered natural gas and marketing stock-based
compensation		(511	)		(333	)		(1,416	)		(1,856	)
General and administrative, as reported		40,720			42,793			159,415			181,109
Less G&A stock-based compensation		(8,834	)		(7,500	)		(32,905	)		(35,061	)
Less lawsuit settlements		(579	)		(542	)		(2,251	)		(2,577	)
Less rig release penalty		—			—			—			(1,436	)
Interest expense, as reported		48,526			44,024			192,667			194,285
Less amortization of deferred financing costs		(2,137	)		(1,981	)		(8,466	)		(7,369	)
Cash expenses		423,371			464,790			1,699,546			2,058,599

Cash margin, a non-GAAP measure	$	106,592		$	172,207		$	402,418		$	729,582

Mmcfe produced during period		192,067			215,757			816,456			833,354

Cash margin per mcfe	$	0.55		$	0.80		$	0.49		$	0.88


RECONCILIATION OF INCOME (LOSS) BEFORE INCOME TAXES TO CASH MARGIN
(Unaudited, in thousands, except per unit data)
	Three Months Ended December 31,						Twelve Months Ended December 31,
	2020			2019			2020			2019

Income (loss) before income taxes, as reported	$	42,626		$	(2,304,179	)	$	(737,329	)	$	(2,216,588	)
Adjustments to reconcile income (loss) before income taxes to cash margin:
ARO settlements and other gains		(780	)		(151	)		(1,651	)		(1,137	)
Derivative fair value (income)		(85,529	)		(18,491	)		(187,711	)		(226,681	)
Net cash receipts on derivative settlements		17,386			50,035			322,629			188,384
Exploration expense		9,076			9,156			31,375			35,117
Lawsuit settlements		579			542			2,251			2,577
Rig release penalty		—			—			—			1,436
Exit and termination costs		13,739			4,535			545,244			7,535
Deferred compensation plan		2,254			960			12,541			(15,472	)
Stock-based compensation (direct operating, brokered natural gas and marketing, general and administrative and termination costs)		10,146			10,442			38,843			42,382
Interest – amortization of deferred financing costs		2,137			1,981			8,466			7,369
Depletion, depreciation and amortization		90,551			130,869			394,330			548,843
Loss (gain) loss on sale of assets		1,652			(407	)		(110,791	)		30,256
Loss (gain) on early extinguishment of debt		25			(2,430	)		(14,068	)		(5,415	)
Impairment of proved property and other assets		—			1,095,634			78,955			1,095,634
Abandonment and impairment of unproved properties		2,730			1,193,711			19,334			1,235,342
Cash margin, a non-GAAP measure	$	106,592		$	172,207		$	402,418		$	729,582

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Range Announces Fourth Quarter 2020 Results

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