rrc-8k_20210223.htm
false 0000315852 0000315852 2021-02-23 2021-02-23

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 

FORM 8-K

 

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Date of Report (Date of earliest event reported): February 24, 2021 (February 23, 2021)

 

RANGE RESOURCES CORPORATION

(Exact name of Registrant as Specified in Its Charter)

 

 

Delaware

001-12209

34-1312571

(State or Other Jurisdiction

of Incorporation)

(Commission File Number)

(IRS Employer

Identification No.)

 

 

 

100 Throckmorton Street, Suite 1200

Fort Worth, Texas

 

76102

(Address of Principal Executive Offices)

 

(Zip Code)

Registrant’s Telephone Number, Including Area Code: (817) 870-2601

Not Applicable

(Former Name or Former Address, if Changed Since Last Report)

 

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instructions A.2. below):

 

Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Securities registered pursuant to Section 12(b) of the Act:

 

Title of each class

 

Trading

Symbol(s)

 

Name of each exchange on which registered

Common Stock, $0.01 par value

      

RRC

 

New York Stock Exchange

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§ 230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§ 240.12b-2 of this chapter).

Emerging growth company 

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. 

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ITEM 2.02 Results of Operations and Financial Condition

On February 23, 2021 Range Resources Corporation issued a press release announcing its 2020 results. A copy of this press release is being furnished as an exhibit to this report on Form 8-K.

ITEM 9.01 Financial Statements and Exhibits

(d) Exhibits:

99.1 Press Release dated February 23, 2021

104  Cover Page Interactive Data File (embedded within the Inline XBRL document)

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

 

 

RANGE RESOURCES CORPORATION

 

By:   

/s/ Mark S. Scucchi

 

Mark S. Scucchi

 

Chief Financial Officer

Date:  February 24, 2021

 

 

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rrc-ex991_24.htm

EXHIBIT 99.1

NEWS RELEASE

Range Announces Fourth Quarter 2020 Results

FORT WORTH, TEXAS, FEBRUARY 23, 2021…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 TIL in 2021

 

Wells TIL in 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.

 

 

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

 

 

Expenses

 

4Q 2020

(per mcfe)

 

4Q 2019

(per mcfe)

 

 

Increase (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

(Mcf)

 

Oil (Bbl)

 

NGLs

(Bbl)

 

Natural Gas

Equivalent (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

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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

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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

Pricing(a)

Flat Price 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)

 

 

Area

 

Net Acres

Assumed Lateral Length

Producing

Locations(1)

Undrilled

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.

 

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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 31st, 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.

 

 

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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.

 

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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

8


 

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.

 

 

 

2021-04

SOURCE:   Range Resources Corporation

 

 

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

 


9


 

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.


10


 

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

%

 


11


 

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

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 


12


 

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)