rrc-8k_20191023.htm
false RANGE RESOURCES CORP 0000315852 0000315852 2019-10-23 2019-10-23

 

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): October 24, 2019 (October 23, 2019)

 

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. 

 

 

 


ITEM 2.02 Results of Operations and Financial Condition

On October 23, 2019 Range Resources Corporation issued a press release announcing its third quarter 2019 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 October 23, 2019

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


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:  October 24, 2019

 

 

 

 

 


 

1

rrc-ex991_24.htm

Exhibit 99.1

NEWS RELEASE

RANGE ANNOUNCES THIRD QUARTER 2019 RESULTS

FORT WORTH, TEXAS, October 23, 2019…RANGE RESOURCES CORPORATION (NYSE: RRC) today announced its third quarter 2019 financial results.  

 

Highlights –

 

 

Sold 2.5% overriding royalty in southwest Appalachia leases for gross proceeds of $750 million

 

Total asset sales of approximately $1.1 billion in the last 12 months

 

Increased credit facility commitment from $2.0 billion to $2.4 billion in October

 

Expected 2019 capital spending reduced to $736 million, $20 million below budget

 

Board of Directors approved a $100 million share repurchase program, effective October 2019

 

Third quarter production averaged 2,244 Mmcfe per day

 

Third quarter cash unit costs of $2.02 per mcfe, an improvement of 7% since year-end 2018

 

Third quarter NGL differential of $0.29 below Mont Belvieu equivalent, best in recent Company history

 

Commenting on the quarter, Jeff Ventura, the Company’s CEO and President said, “In third quarter 2019, Range delivered on several initiatives: improving our cost structure, enhancing balance sheet strength and delivering on our operational plans for less capital than originally budgeted. Our financial position has materially improved over the last year with over $1 billion in asset sales being put toward debt reduction.  Maintaining financial strength and flexibility is a core principle of Range’s strategy and the recent increase in bank commitments not only enhances liquidity but demonstrates the durability of Range’s assets and business.  While Range has made progress so far this year, we remain committed to positioning the Company for success through the commodity cycles.”

 

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.

 

Third Quarter 2019 Results

 

GAAP revenues for third quarter 2019 totaled $622 million, GAAP net cash provided from operating activities (including changes in working capital) was $104 million, and GAAP net income was a loss of $28 million ($0.11 per diluted share).  Third quarter earnings results include a $75 million derivative gain due to decreases in commodity prices and a $36 million loss related to asset sales.

 

Non-GAAP revenues for third quarter 2019 totaled $628 million, and cash flow from operations before changes in working capital, a non-GAAP measure, was $128 million.  Adjusted net income comparable to analysts’ estimates, a non-GAAP measure, was a loss of $18 million ($0.07 per diluted share) in third quarter 2019.

 

Capital Expenditures

 

Third quarter 2019 drilling and completion expenditures were $148 million.  In addition, during the quarter, $9 million was spent on acreage purchases and $1 million on gathering facilities.  Total capital expenditures year to date in 2019 were $576 million.  Range is reducing its expected 2019 capital spending by $20 million to $736 million as a result of continued efficiency gains, water savings, and service cost improvements.


Asset Sales and Bank Credit Facility

 

During the quarter, Range sold 2.5% proportionately reduced overriding royalty interests in 350,000 net surface acres in southwest Appalachia for gross proceeds totaling $750 million.  The royalty sales were effective as of March 1, 2019, and apply to existing and future Marcellus, Utica and Upper Devonian development on the subject leases.  Sale processes to monetize additional non-core assets remain underway.  

 

Separately during the third quarter, Range divested of certain legacy dry gas assets in Appalachia that were producing approximately 3 Mmcfe per day. The divestiture is modestly accretive to cash flow.  Range maintains the rights to develop deeper horizons including Marcellus, Utica and Upper Devonian.

 

In October, the Company increased its credit facility commitment from $2.0 billion to $2.4 billion.

 

Repurchase Programs

 

Range repurchased and retired approximately $94 million in principal amount of its senior notes during the quarter for a total cash spend of approximately $90 million.  

 

Range’s Board of Directors approved the initiation of a $100 million equity repurchase program, beginning October 2019. The share repurchase program will be executed at times deemed appropriate by the Company.

 

Third Quarter Unit Costs and Realized Pricing

 

The following table details Range’s unit cost trend since year-end 2018 (a):

 

 

Expenses

 

3Q 2019

($/Mcfe)

 

 

2Q 2019

($/Mcfe)

 

 

1Q 2019

($/Mcfe)

 

 

4Q 2018

($/Mcfe)

 

 

 

 

 

 

 

 

 

 

 

 

Direct operating(a)

$

0.17

 

$

0.16

 

$

0.16

 

$

0.18

Transportation, gathering, processing and compression

 

1.43

 

 

1.45

 

 

1.49

 

 

1.51

Production and ad valorem taxes

 

0.04

 

 

0.05

 

 

0.06

 

 

0.08

General and administrative(a)

 

0.16

 

 

0.18

 

 

0.18

 

 

0.16

Interest expense(a)

 

0.22

 

 

0.24

 

 

0.25

 

 

0.25

Total cash unit costs(b)

 

2.02

 

 

2.08

 

 

2.13

 

 

2.18

Depletion, depreciation and

amortization (DD&A)

 

0.67

 

 

0.68

 

 

0.68

 

 

0.75

Total cash unit costs plus DD&A(b)

$

2.68

 

$

2.76

 

$

2.82

 

$

2.93

 

 

(a)

Excludes stock-based compensation, legal settlements, rig release penalties, termination costs and amortization of deferred financing costs.

 

(b)

May not add due to rounding.

 

 

Third quarter 2019 cash unit costs totaled $2.02 per mcfe, an improvement of $0.16 per mcfe compared to fourth quarter 2018.  This improvement was primarily driven by lower transportation, gathering, processing and compression (GP&T), interest and production tax expenses per mcfe.  Range expects an additional 2% reduction in cash unit costs during fourth quarter 2019, primarily driven by additional improvements in GP&T and interest expense per mcfe.  Range anticipates further unit cost improvement in 2020 and beyond to be driven by lower GP&T, interest, and cash G&A per mcfe.

 

 

 

 

 

2


The following table details Range’s average production and realized pricing for third quarter 2019:

 

 

Net Production

 

Natural Gas

(Mmcf/d)

 

Oil (Bbl/d)

 

NGLs

(Bbl/d)

 

Natural Gas

Equivalent (Mmcfe/d)

 

 

 

 

 

 

 

 

 

 

 

 

 

1,562

 

10,212

 

103,383

 

2,244

 

 

 

Realized Pricing (a)

 

 

Natural Gas

($/Mcf)

 

Oil ($/Bbl)

 

NGLs

($/Bbl)

 

Natural Gas

Equivalent ($/Mcfe)

 

 

 

 

 

 

 

 

 

 

 

 

 

Average NYMEX price

 

$2.23

 

$56.42

 

 

 

 

Differential, including basis hedging

 

(0.26)

 

(6.84)

 

 

 

 

Realized prices before NYMEX hedges

 

1.97

 

49.58

 

$15.06

 

$2.30

Settled NYMEX hedges

 

0.51

 

  0.15

 

    0.74

 

  0.38

Average realized prices after hedges

 

$2.48

 

$49.73

 

$15.80

 

$2.69

 

 

 

 

 

 

 

 

 

(a)May not add due to rounding

 

 

 

 

 

 

 

 

 

 

Third quarter 2019 natural gas, NGLs and oil price realizations (including the impact of derivative settlements which correspond to analysts’ estimates) averaged $2.68 per mcfe.  Additional detail on commodity price realizations can be found in the Supplemental Tables provided on the Company’s website.  

 

 

The average natural gas price, including the impact of basis hedging, was $1.97 per mcf, or $0.26 per mcf below NYMEX.  Based on recent pricing, Range expects a fourth quarter 2019 differential of approximately $0.30 below NYMEX.

 

 

Pre-hedge NGL realizations were $15.06 per barrel, or $0.29 per barrel below to a Mont Belvieu weighted barrel, as shown on Supplemental Table 9 on the Company’s website.  The third quarter NGL differential to Mont Belvieu was the best in recent Company history.  Range expects to maintain a strong differential during fourth quarter 2019 as a result of access to international markets and its diversified portfolio of ethane contracts.

 

 

Crude oil and condensate price realizations, before realized hedges, averaged $49.58 per barrel, or $6.84 below West Texas Intermediate (WTI).  Range expects a fourth quarter 2019 oil and condensate pricing differential of approximately $7 below WTI.

 

 

Operational Discussion

 

NGL Marketing

 

During September and October, Sunoco performed optimization work at the Marcus Hook export terminal which is expected to result in more efficient transportation to end markets.  The upgrade required the Mariner East pipeline to experience downtime, and as a result of the outage, Range sold ethane volumes in its residue natural gas stream that would typically be transported via the Mariner East system. 

 

The value of exported barrels from the East Coast increased during the quarter, particularly in September after a Middle East oil disruption.  Range capitalized on the opportunity during the third quarter by utilizing both pipeline and rail access to export terminals.  Propane export values at the dock remain elevated and are currently estimated

3


at $0.10 per gallon above the Mont Belvieu index.  The combination of ethane rejection and access to international markets for propane and butane led to the best quarterly NGL differential to Mont Belvieu that Range has realized in recent history.  Range resumed use of Mariner East ethane capacity in mid-October and expects another strong differential to Mont Belvieu in the fourth quarter of 2019.

 

Appalachia Division

 

Production for third quarter 2019 averaged approximately 2,042 net Mmcfe per day from the Appalachia division, a 3% increase over the prior-year third quarter.  Despite the third-party optimization work mentioned above, which impacted ethane recovery, the southwest area of the division averaged 1,945 net Mmcfe per day during third quarter 2019.  The northeast Marcellus properties averaged 97 net Mmcf per day inclusive of approximately 15 net Mmcf per day of legacy acreage production during third quarter 2019.

 

North Louisiana

 

Production for third quarter 2019 averaged approximately 202 net Mmcfe per day.  The division brought on line two wells during the quarter and expects to bring on line an additional well during the fourth quarter.

 

The table below summarizes estimated activity for 2019 regarding the number of wells to sales for each area.  

 

 

 

 

Wells TIL

3Q 2019

 

Wells TIL

1H 2019

 

Calendar 2019

Planned TIL

 

Remaining

4Q 2019

SW PA Super-Rich

 

 

8

 

11

 

19

 

0

SW PA Wet

 

 

8

 

8

 

36

 

20

SW PA Dry

 

 

6

 

20

 

33

 

7

Total Appalachia

 

 

22

 

39

 

88

 

27

 

 

 

 

 

 

 

 

 

 

Total N. LA.

 

 

2

 

5

 

8

 

1

Total

 

 

24

 

44

 

96

 

28

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

4


 

Guidance – 2019  

 

Production per day Guidance

 

Production for fourth quarter 2019 is expected to be ~2.33 to 2.35 Bcfe per day, which incorporates approximately 25 Mmcfe per day impact of recent asset sales and ethane recovery.  

 

4Q 2019 Expense Guidance  

 

Direct operating expense:

 

 $0.16 − $0.17 per mcfe

Transportation, gathering, processing and compression expense:

 

 $1.40 − $1.42 per mcfe

Production tax expense:

 

 $0.04 − $0.05 per mcfe

Exploration expense:

 

 $7.0 − $9.0 million

Unproved property impairment expense:

 

 $15.0 − $18.0 million

G&A expense:

 

 $0.15 − $0.17 per mcfe

Interest expense:

 

 $0.19 − $0.21 per mcfe

DD&A expense:

 

 $0.67 − $0.70 per mcfe

Net brokered gas marketing expense:

 

  ~$6.0 million

 

 

Price Guidance

 

Based on current market indications, Range expects to average the following pre-hedge differentials for fourth quarter 2019 production.  

 

 

4Q 2019 Pricing Guidance

Natural Gas: (1)

NYMEX minus $0.30

Natural Gas Liquids: (2)

Mont Belvieu minus $0.60 to $0.80 per barrel

Oil/Condensate:

WTI minus $6.00 to $8.00

 

 

 

(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 more flexible financial position. Range currently has over 80% of its expected fourth quarter 2019 natural gas production hedged at a weighted average floor price of $2.81 per Mmbtu.  Similarly, Range has hedged over 80% of its fourth quarter 2019 projected crude oil production at an average floor price of $56.78.  Please see Range’s detailed hedging schedule posted at the end of the financial tables below and on its website at www.rangeresources.com.  

 

Range has also hedged Marcellus and other basis differentials to limit volatility between NYMEX and regional prices.  The fair value of the basis hedges was a gain of $4.6 million as of September 30, 2019.  The Company also has propane basis swap contracts which lock in the differential between Mont Belvieu and international propane indices.  The fair value of these contracts was a loss of $3.3 million on September 30, 2019.  

 

Conference Call Information

A conference call to review the financial results is scheduled on Thursday, October 24 at 9:00 a.m. ET.  To participate in the call, please dial 866-900-7525 and provide conference code 9092535 about 10 minutes prior to the scheduled start time.

5


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 November 24, 2019.

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).  The Company provides additional comparative information on prior periods along with non-GAAP revenue disclosures on its website.  

 

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 line in the statement of operations 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 quarterly report on Form 10-Q.  The Company believes that it is important to furnish this detail of the various components comprising each line of the Statements of Operations to better inform the reader of the details of each amount, the changes between periods and the effect on its financial results.

  

RANGE RESOURCES CORPORATION (NYSE: RRC) is a leading U.S. independent oil and natural gas producer with operations focused in stacked-pay projects in the Appalachian Basin and North Louisiana. The Company pursues an organic development strategy targeting high return, low-cost projects within its large inventory of low risk development drilling opportunities.  The Company is headquartered in Fort Worth, Texas.  More information about Range can be found at www.rangeresources.com.

 

6


Included within this news 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 in this release 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,

7


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.

 

 

2019-19

SOURCE:   Range Resources Corporation

 

 

Investor Contacts:

 

Laith Sando, Vice President – Investor Relations

817-869-4267

lsando@rangeresources.com

 

 

Media Contact:

 

Mark Windle, Manager of Corporate Communications

724-873-3223

mwindle@rangeresources.com

 

www.rangeresources.com

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

8


 

RANGE RESOURCES CORPORATION

 

STATEMENTS OF OPERATIONS

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Based on GAAP reported earnings with additional

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

details of items included in each line in Form 10-Q

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(Unaudited, in thousands, except per share data)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended September 30,

 

 

Nine Months Ended September 30,

 

 

 

2019

 

 

 

2018

 

 

 

%

 

 

 

2019

 

 

 

2018

 

 

 

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenues and other income:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas, NGLs and oil sales (a)

$

474,754

 

 

$

736,431

 

 

 

 

 

 

$

1,709,987

 

 

$

2,094,450

 

 

 

 

 

Derivative fair value income/(loss)

 

74,676

 

 

 

(34,591

)

 

 

 

 

 

 

208,190

 

 

 

(151,890

)

 

 

 

 

Brokered natural gas, marketing and other (b)

 

72,765

 

 

 

109,111

 

 

 

 

 

 

 

302,848

 

 

 

266,774

 

 

 

 

 

ARO settlement (loss) gain (b)

 

(11

)

 

 

 

 

 

 

 

 

 

(11

)

 

 

(12

)

 

 

 

 

Other (b)

 

261

 

 

 

274

 

 

 

 

 

 

 

997

 

 

 

686

 

 

 

 

 

Total revenues and other income

 

622,445

 

 

 

811,225

 

 

 

-23

%

 

 

2,222,011

 

 

 

2,210,008

 

 

 

1

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Costs and expenses:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Direct operating

 

34,957

 

 

 

30,389

 

 

 

 

 

 

 

101,025

 

 

 

102,469

 

 

 

 

 

Direct operating – non-cash stock-based compensation (c)

 

319

 

 

 

537

 

 

 

 

 

 

 

1,459

 

 

 

1,667

 

 

 

 

 

Transportation, gathering, processing and compression  

 

295,912

 

 

 

304,562

 

 

 

 

 

 

 

899,786

 

 

 

819,100

 

 

 

 

 

Production and ad valorem taxes  

 

7,805

 

 

 

9,427

 

 

 

 

 

 

 

29,004

 

 

 

29,493

 

 

 

 

 

Brokered natural gas and marketing

 

79,416

 

 

 

115,677

 

 

 

 

 

 

 

311,837

 

 

 

273,420

 

 

 

 

 

Brokered natural gas and marketing – non-cash
stock-based compensation (c)

 

522

 

 

 

403

 

 

 

 

 

 

 

1,523

 

 

 

1,001

 

 

 

 

 

Exploration

 

10,517

 

 

 

7,894

 

 

 

 

 

 

 

25,961

 

 

 

21,990

 

 

 

 

 

Exploration – non-cash stock-based compensation (c)  

 

496

 

 

 

405

 

 

 

 

 

 

 

1,372

 

 

 

1,527

 

 

 

 

 

Abandonment and impairment of unproved properties  

 

16,202

 

 

 

6,549

 

 

 

 

 

 

 

41,631

 

 

 

73,244

 

 

 

 

 

General and administrative  

 

32,626

 

 

 

37,812

 

 

 

 

 

 

 

107,425

 

 

 

121,255

 

 

 

 

 

General and administrative – non-cash stock-based
compensation (c)

 

8,423

 

 

 

5,607

 

 

 

 

 

 

 

27,561

 

 

 

38,332

 

 

 

 

 

General and administrative – lawsuit settlements

 

139

 

 

 

53

 

 

 

 

 

 

 

2,035

 

 

 

1,385

 

 

 

 

 

General and administrative – rig release penalty

 

 

 

 

 

 

 

 

 

 

 

1,436

 

 

 

 

 

 

 

 

General and administrative – bad debt expense  

 

(141

)

 

 

250

 

 

 

 

 

 

 

(141

)

 

 

(1,250

)

 

 

 

 

Termination costs

 

820

 

 

 

(336

)

 

 

 

 

 

 

3,000

 

 

 

(373

)

 

 

 

 

Termination costs – non-cash stock-based compensation (c)

 

(1

)

 

 

 

 

 

 

 

 

 

25

 

 

 

 

 

 

 

 

Deferred compensation plan (d)

 

(8,871

)

 

 

223

 

 

 

 

 

 

 

(16,432

)

 

 

(559

)

 

 

 

 

Interest expense

 

45,202

 

 

 

53,063

 

 

 

 

 

 

 

144,873

 

 

 

155,733

 

 

 

 

 

Interest expense – amortization of deferred financing costs (e)

 

1,795

 

 

 

1,738

 

 

 

 

 

 

 

5,388

 

 

 

5,315

 

 

 

 

 

Gain on early extinguishment of debt  

 

(2,985

)

 

 

 

 

 

 

 

 

 

(2,985

)

 

 

 

 

 

 

 

Depletion, depreciation and amortization  

 

137,751

 

 

 

164,266

 

 

 

 

 

 

 

417,974

 

 

 

487,558

 

 

 

 

 

Impairment of proved property

 

 

 

 

 

 

 

 

 

 

 

 

 

 

22,614

 

 

 

 

 

Loss/(gain) on sale of assets

 

36,341

 

 

 

30

 

 

 

 

 

 

 

30,663

 

 

 

(149

)

 

 

 

 

Total costs and expenses

 

697,245

 

 

 

738,549

 

 

 

-6

%

 

 

2,134,420

 

 

 

2,153,772

 

 

 

-1

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(Loss) income before income taxes

 

(74,800

)

 

 

72,676

 

 

 

-203

%

 

 

87,591

 

 

 

56,236

 

 

 

56

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income tax (benefit) expense:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Current

 

4,079

 

 

 

 

 

 

 

 

 

 

4,079

 

 

 

 

 

 

 

 

Deferred

 

(51,298

)

 

 

24,137

 

 

 

 

 

 

 

(5,511

)

 

 

38,295

 

 

 

 

 

 

 

(47,219

)

 

 

24,137

 

 

 

 

 

 

 

(1,432

)

 

 

38,295

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net (loss) income

$

(27,581

)

 

$

48,539

 

 

 

-157

%

 

$

89,023

 

 

$

17,941

 

 

 

396

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net (Loss) Income Per Common Share:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

$

(0.11

)

 

$

0.19

 

 

 

 

 

 

$

0.35

 

 

$

0.07

 

 

 

 

 

Diluted

$

(0.11

)

 

$

0.19

 

 

 

 

 

 

$

0.35

 

 

$

0.07

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Weighted average common shares outstanding, as reported:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

 

248,082

 

 

 

246,451

 

 

 

1

%

 

 

247,878

 

 

 

246,016

 

 

 

1

%

Diluted

 

248,082

 

 

 

247,166

 

 

 

0

%

 

 

248,823

 

 

 

246,879

 

 

 

1

%

(a) See separate natural gas, NGLs and oil sales information table.

(b) Included in Brokered natural gas, marketing and other revenues in the 10-Q.

(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-Q.

(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-Q.

9


 

RANGE RESOURCES CORPORATION

 

BALANCE SHEETS

 

 

 

 

 

 

 

(In thousands)

 

September 30,

 

 

 

December 31,

 

 

 

2019

 

 

 

2018

 

 

 

(Unaudited)

 

 

 

(Audited)

 

Assets

 

 

 

 

 

 

 

Current assets

$

275,439

 

 

$

514,232

 

Derivative assets

 

156,847

 

 

 

92,795

 

Natural gas and oil properties, successful efforts method

 

8,295,570

 

 

 

9,023,185

 

Transportation and field assets

 

6,311

 

 

 

9,776

 

Operating lease right-of-use assets

 

47,214

 

 

 

 

Other

 

72,818

 

 

 

68,166

 

 

$

8,854,199

 

 

$

9,708,154

 

 

 

 

 

 

 

 

 

Liabilities and Stockholders’ Equity

 

 

 

 

 

 

 

Current liabilities

$

550,424

 

 

$

745,182

 

Asset retirement obligations

 

5,485

 

 

 

5,485

 

Derivative liabilities

 

1,521

 

 

 

4,144

 

 

 

 

 

 

 

 

 

Bank debt

 

318,919

 

 

 

932,018

 

Senior notes

 

2,766,322

 

 

 

2,856,166

 

Senior subordinated notes

 

48,749

 

 

 

48,677

 

Total debt

 

3,133,990

 

 

 

3,836,861

 

 

 

 

 

 

 

 

 

Deferred tax liability

 

661,216

 

 

 

666,668

 

Derivative liabilities

 

296

 

 

 

3,462

 

Deferred compensation liability

 

58,329

 

 

 

67,542

 

Asset retirement obligations and other liabilities

 

284,746

 

 

 

319,379

 

 

 

 

 

 

 

 

 

Common stock and retained earnings

 

4,158,998

 

 

 

4,060,480

 

Other comprehensive loss

 

(478

)

 

 

(658

)

Common stock held in treasury stock

 

(328

)

 

 

(391

)

Total stockholders’ equity

 

4,158,192

 

 

 

4,059,431

 

 

$

8,854,199

 

 

$

9,708,154

 

 

RECONCILIATION OF TOTAL REVENUES AND OTHER INCOME TO TOTAL REVENUE EXCLUDING CERTAIN ITEMS, a non-GAAP measure

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(Unaudited, in thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

September 30,

 

 

Nine Months Ended

September 30,

 

 

 

2019

 

 

 

2018

 

 

 

%

 

 

 

2019

 

 

 

2018

 

 

 

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total revenues and other income, as reported

$

622,445

 

 

$

811,225

 

 

 

-23

%

 

$

2,222,011

 

 

$

2,210,008

 

 

 

1

%

Adjustment for certain special items:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total change in fair value related to derivatives
prior to settlement loss (gain)

 

5,332

 

 

 

(331

)

 

 

 

 

 

 

(69,841

)

 

 

111,618

 

 

 

 

 

ARO settlement loss

 

11

 

 

 

 

 

 

 

 

 

 

11

 

 

 

12

 

 

 

 

 

Total revenues, as adjusted, non-GAAP

$

627,788

 

 

$

810,894

 

 

 

-23

%

 

$

2,152,181

 

 

$

2,321,638

 

 

 

-7

%

 

10


 

RANGE RESOURCES CORPORATION

CASH FLOWS FROM OPERATING ACTIVITIES

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(Unaudited in thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended September 30,

 

 

Nine Months Ended September 30,

 

 

 

2019

 

 

 

2018

 

 

 

2019

 

 

 

2018

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net (loss) income

$

(27,581

)

 

$

48,539

 

 

$

89,023

 

 

$

17,941

 

Adjustments to reconcile net cash provided from continuing operations:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Deferred income tax (benefit) expense

 

(51,298

)

 

 

24,137

 

 

 

(5,511

)

 

 

38,295

 

Depletion, depreciation, amortization and impairment

 

137,751

 

 

 

164,266

 

 

 

417,974

 

 

 

510,172

 

Exploration dry hole costs

 

 

 

 

2

 

 

 

 

 

 

4

 

Abandonment and impairment of unproved properties

 

16,202

 

 

 

6,549

 

 

 

41,631

 

 

 

73,244

 

Derivative fair value (income) loss

 

(74,676

)

 

 

34,591

 

 

 

(208,190

)

 

 

151,890

 

Cash settlements on derivative financial instruments that do not qualify for hedge accounting

 

80,008

 

 

 

(34,922

)

 

 

138,349

 

 

 

(40,272

)

Allowance for bad debts

 

(141

)

 

 

250

 

 

 

(141

)

 

 

(1,250

)

Amortization of deferred issuance costs, loss on extinguishment of debt, and other

 

1,619

 

 

 

1,787

 

 

 

4,862

 

 

 

4,163

 

Deferred and stock-based compensation

 

683

 

 

 

7,085

 

 

 

14,410

 

 

 

41,252

 

Loss (gain) on sale of assets and other

 

36,341

 

 

 

30

 

 

 

30,663

 

 

 

(149

)

Gain on early extinguishment of debt

 

(2,985

)

 

 

 

 

 

(2,985

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Changes in working capital:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Accounts receivable

 

40,086

 

 

 

(35,288

)

 

 

241,514

 

 

 

(49,713

)

Inventory and other

 

1,011

 

 

 

(1,618

)

 

 

(4,024

)

 

 

(822

)

Accounts payable

 

(23,513

)

 

 

(21,144

)

 

 

(52,645

)

 

 

(6,529

)

Accrued liabilities and other

 

(29,592

)

 

 

35,168

 

 

 

(155,499

)

 

 

36,721

 

Net changes in working capital

 

(12,008

)

 

 

(22,882

)

 

 

29,346

 

 

 

(20,343

)

Net cash provided from operating activities

$

103,915

 

 

$

229,432

 

 

$

549,431

 

 

$

774,947

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

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 September 30,

 

 

Nine Months Ended September 30,

 

 

 

2019

 

 

 

2018

 

 

 

2019

 

 

 

2018

 

Net cash provided from operating activities, as reported

$

103,915

 

 

$

229,432

 

 

$

549,431

 

 

$

774,947

 

Net changes in working capital

 

12,008

 

 

 

22,882

 

 

 

(29,346

)

 

 

20,343

 

Exploration expense

 

10,517

 

 

 

7,892

 

 

 

25,961

 

 

 

21,986

 

Lawsuit settlements

 

139

 

 

 

53

 

 

 

2,035

 

 

 

1,385

 

Termination costs

 

820

 

 

 

(336

)

 

 

3,000

 

 

 

(373

)

Rig release penalty

 

 

 

 

 

 

 

1,436

 

 

 

 

Non-cash compensation adjustment

 

392

 

 

 

41

 

 

 

1,635

 

 

 

1,880

 

Cash flow from operations before changes in working capital – non-GAAP measure

$

127,791

 

 

$

259,964

 

 

$

554,152

 

 

$

820,168

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

ADJUSTED WEIGHTED AVERAGE SHARES OUTSTANDING

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(Unaudited, in thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended September 30,

 

 

Nine Months Ended September 30,

 

 

 

2019

 

 

 

2018

 

 

 

2019

 

 

 

2018

 

Basic:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Weighted average shares outstanding

 

251,408

 

 

 

249,482

 

 

 

250,995

 

 

 

249,131

 

Stock held by deferred compensation plan

 

(3,326

)

 

 

(3,031

)

 

 

(3,117

)

 

 

(3,115

)

Adjusted basic

 

248,082

 

 

 

246,451

 

 

 

247,878

 

 

 

246,016

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Dilutive:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Weighted average shares outstanding

 

251,408

 

 

 

249,482

 

 

 

250,995

 

 

 

249,131

 

Dilutive stock options under treasury method

 

(3,326

)

 

 

(2,316

)

 

 

(2,172

)

 

 

(2,252

)

Adjusted dilutive

 

248,082

 

 

 

247,166

 

 

 

248,823

 

 

 

246,879

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

11


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 September 30,

 

 

Nine Months Ended September 30,

 

 

 

2019

 

 

 

2018

 

 

 

%

 

 

 

2019

 

 

 

2018

 

 

 

%

 

Natural gas, NGL and oil sales components:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas sales

$

284,980

 

 

$

390,656

 

 

 

 

 

 

$

1,063,323

 

 

$

1,182,580

 

 

 

 

 

NGL sales

 

143,195

 

 

 

278,563

 

 

 

 

 

 

 

508,035

 

 

 

705,793

 

 

 

 

 

Oil sales

 

46,579

 

 

 

67,212

 

 

 

 

 

 

 

138,629

 

 

 

206,077

 

 

 

 

 

Total oil and gas sales, as reported

$

474,754

 

 

$

736,431

 

 

 

-36

%

 

$

1,709,987

 

 

$

2,094,450

 

 

 

-18

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Derivative fair value income (loss), as reported:

$

74,676

 

 

$

(34,591

)

 

 

 

 

 

$

208,190

 

 

$

(151,890

)

 

 

 

 

Cash settlements on derivative financial instruments – (gain) loss:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas

 

(72,809

)

 

 

(5,845

)

 

 

 

 

 

 

(92,333

)

 

 

(56,466

)

 

 

 

 

NGLs

 

(7,053

)

 

 

28,023

 

 

 

 

 

 

 

(47,835

)

 

 

63,435

 

 

 

 

 

Crude Oil

 

(146

)

 

 

12,744

 

 

 

 

 

 

 

1,819

 

 

 

33,303

 

 

 

 

 

Total change in fair value related to derivatives prior to settlement, a
non-GAAP measure

$

(5,332

)

 

$

331

 

 

 

 

 

 

$

69,841

 

 

$

(111,618

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Transportation, gathering, processing and compression components:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas

$

180,353

 

 

$

176,271

 

 

 

 

 

 

$

554,788

 

 

$

497,569

 

 

 

 

 

NGLs

 

115,559

 

 

 

128,291

 

 

 

 

 

 

 

344,998

 

 

 

321,531

 

 

 

 

 

Total transportation, gathering, processing and compression, as reported

$

295,912

 

 

$

304,562

 

 

 

 

 

 

$

899,786

 

 

$

819,100

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas, NGL and oil sales, including cash-settled derivatives: (c)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas sales

$

357,789

 

 

$

396,501

 

 

 

 

 

 

$

1,155,656

 

 

$

1,239,046

 

 

 

 

 

NGL sales

 

150,248

 

 

 

250,540

 

 

 

 

 

 

 

555,870

 

 

 

642,358

 

 

 

 

 

Oil sales

 

46,725

 

 

 

54,468

 

 

 

 

 

 

 

136,810

 

 

 

172,774

 

 

 

 

 

Total

$

554,762

 

 

$

701,509

 

 

 

-21

%

 

 

1,848,336

 

 

 

2,054,178

 

 

 

-10

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Production of oil and gas during the periods (a):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas (mcf)

 

143,721,265

 

 

 

140,757,676

 

 

 

2

%

 

 

427,405,931

 

 

 

411,769,576

 

 

 

4

%

NGL (bbl)

 

9,511,234

 

 

 

10,255,159

 

 

 

-7

%

 

 

28,971,049

 

 

 

29,009,100

 

 

 

0

%

Oil (bbl)

 

939,541

 

 

 

1,040,891

 

 

 

-10

%

 

 

2,727,415

 

 

 

3,314,704

 

 

 

-18

%

Gas equivalent (mcfe) (b)

 

206,425,915

 

 

 

208,533,976

 

 

 

-1

%

 

 

617,596,715

 

 

 

605,712,400

 

 

 

2

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Production of oil and gas – average per day (a):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas (mcf)

 

1,562,188

 

 

 

1,529,975

 

 

 

0

%

 

 

1,565,589

 

 

 

1,508,313

 

 

 

4

%

NGL (bbl)

 

103,383

 

 

 

111,469

 

 

 

(0)

%

 

 

106,121

 

 

 

106,260

 

 

 

0

%

Oil (bbl)

 

10,212

 

 

 

11,314

 

 

 

(0)

%

 

 

9,991

 

 

 

12,142

 

 

 

-18

%

Gas equivalent (mcfe) (b)  

 

2,243,760

 

 

 

2,266,674

 

 

 

(0)

%

 

 

2,262,259

 

 

 

2,218,727

 

 

 

2

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average prices, excluding derivative settlements and before third party transportation costs:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas (mcf)

$

1.98

 

 

$

2.78

 

 

 

-29

%

 

$

2.49

 

 

$

2.87

 

 

 

-13

%

NGL (bbl)

$

15.06

 

 

$

27.16

 

 

 

-45

%

 

$

17.54

 

 

$

24.33

 

 

 

-28

%

Oil (bbl)

$

49.58

 

 

$

64.57

 

 

 

-23

%

 

$

50.83

 

 

$

62.17

 

 

 

-18

%

Gas equivalent (mcfe) (b)

$

2.30

 

 

$

3.53

 

 

 

-35

%

 

$

2.77

 

 

$

3.46

 

 

 

-20

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average prices, including derivative settlements before third party transportation costs: (c)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas (mcf)

$

2.49

 

 

$

2.82

 

 

 

-12

%

 

$

2.70

 

 

$

3.01

 

 

 

-10

%

NGL (bbl)

$

15.80

 

 

$

24.43

 

 

 

-35

%

 

$

19.19

 

 

$

22.14

 

 

 

-13

%

Oil (bbl)

$

49.73

 

 

$

52.33

 

 

 

-5

%

 

$

50.16

 

 

$

52.12

 

 

 

-4

%

Gas equivalent (mcfe) (b)

$

2.69

 

 

$

3.36

 

 

 

-20

%

 

$

2.99

 

 

$

3.39

 

 

 

-12

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average prices, including derivative settlements and after third party

       transportation costs: (d)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas (mcf)

$

1.23

 

 

$

1.56

 

 

 

-21

%

 

$

1.41

 

 

$

1.80

 

 

 

-22

%

NGL (bbl)

$

3.65

 

 

$

11.92

 

 

 

-69

%

 

$

7.28

 

 

$

11.06

 

 

 

-34

%

Oil (bbl)

$

49.73

 

 

$

52.33

 

 

 

-5

%

 

$

50.16

 

 

$

52.12

 

 

 

-4

%

Gas equivalent (mcfe) (b)

$

1.25

 

 

$

1.90

 

 

 

-34

%

 

$

1.54

 

 

$

2.04

 

 

 

-25

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Transportation, gathering and compression expense per mcfe

$

1.43

 

 

$

1.46

 

 

 

-2

%

 

$

1.46

 

 

$

1.35

 

 

 

8

%

(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 and compression costs.

 

12


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 September 30,

 

 

Nine Months Ended September 30,

 

 

 

2019

 

 

 

2018

 

 

 

%

 

 

 

2019

 

 

 

2018

 

 

 

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(Loss) income from operations before income taxes, as reported

$

(74,800

)

 

$

72,676

 

 

 

203

%

 

$

87,591

 

 

$

56,236

 

 

 

-56

%

Adjustment for certain special items:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss (gain) on sale of assets

 

36,341

 

 

 

30

 

 

 

 

 

 

 

30,663

 

 

 

(149

)

 

 

 

 

Loss on ARO settlements

 

11

 

 

 

 

 

 

 

 

 

 

11

 

 

 

12

 

 

 

 

 

Change in fair value related to derivatives prior to settlement

 

5,332

 

 

 

(331

)

 

 

 

 

 

 

(69,841

)

 

 

111,618

 

 

 

 

 

Rig release penalty

 

 

 

 

 

 

 

 

 

 

 

1,436

 

 

 

 

 

 

 

 

Abandonment and impairment of unproved properties

 

16,202

 

 

 

6,549

 

 

 

 

 

 

 

41,631

 

 

 

73,244

 

 

 

 

 

Gain on early extinguishment of debt

 

(2,985

)

 

 

 

 

 

 

 

 

 

(2,985

)

 

 

 

 

 

 

 

Impairment of proved property

 

 

 

 

 

 

 

 

 

 

 

 

 

 

22,614

 

 

 

 

 

Lawsuit settlements

 

139

 

 

 

53

 

 

 

 

 

 

 

2,035

 

 

 

1,385

 

 

 

 

 

Termination costs

 

820

 

 

 

(336

)

 

 

 

 

 

 

3,000

 

 

 

(373

)

 

 

 

 

Termination costs – non-cash stock-based compensation

 

(1

)

 

 

 

 

 

 

 

 

 

25

 

 

 

 

 

 

 

 

Brokered natural gas and marketing – non-cash stock-based
compensation

 

522

 

 

 

403

 

 

 

 

 

 

 

1,523

 

 

 

1,001

 

 

 

 

 

Direct operating – non-cash stock-based compensation

 

319

 

 

 

537

 

 

 

 

 

 

 

1,459

 

 

 

1,667

 

 

 

 

 

Exploration expenses – non-cash stock-based compensation

 

496

 

 

 

405

 

 

 

 

 

 

 

1,372

 

 

 

1,527

 

 

 

 

 

General & administrative – non-cash stock-based compensation

 

8,423

 

 

 

5,607

 

 

 

 

 

 

 

27,561

 

 

 

38,332

 

 

 

 

 

Deferred compensation plan – non-cash adjustment

 

(8,871

)

 

 

223

 

 

 

 

 

 

 

(16,432

)

 

 

(559

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(Loss) income before income taxes, as adjusted

 

(18,052

)

 

 

85,816

 

 

 

-121

%

 

 

109,049

 

 

 

306,555

 

 

 

-64

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Income tax (benefit) expense, as adjusted

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Current

 

4,079

 

 

 

 

 

 

 

 

 

 

4,079

 

 

 

 

 

 

 

 

Deferred (a)

 

(4,513

)

 

 

21,869

 

 

 

 

 

 

 

27,279

 

 

 

79,617

 

 

 

 

 

Net (loss) income excluding certain items, a non-GAAP measure

$

(17,618

)

 

$

63,947

 

 

 

-128

%

 

$

77,691

 

 

$

226,938

 

 

 

-66

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Non-GAAP (loss) income per common share

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

$

(0.07

)

 

$

0.26

 

 

 

-127

%

 

$

0.31

 

 

$

0.92

 

 

 

-66

%

Diluted

$

(0.07

)

 

$

0.26

 

 

 

-127

%

 

$

0.31

 

 

$

0.92

 

 

 

-66

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Non-GAAP diluted shares outstanding, if dilutive

 

248,082

 

 

 

247,166

 

 

 

 

 

 

 

248,823

 

 

 

246,879

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(a)  Deferred taxes are estimated to be approximately 25% for 2019 and 26% for 2018.

 

 

 

 

 

 

 

 

 

 

 

13


 

RANGE RESOURCES CORPORATION

 

RECONCILIATION OF NET (LOSS) INCOME, EXCLUDING

CERTAIN ITEMS AND ADJUSTMENT EARNINGS PER SHARE, non-GAAP measures

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(In thousands, except per share data)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

September 30,

 

 

 

Nine Months Ended

September 30,

 

 

 

 

2019

 

 

 

2018

 

 

 

 

2019

 

 

 

2018

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net (loss) income, as reported

$

(27,581

)

 

$

48,539

 

 

 

$

89,023

 

 

$

17,941

 

 

Adjustment for certain special items:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss (gain) on sale of assets

 

36,341

 

 

 

30

 

 

 

 

30,663

 

 

 

(149

)

 

Loss on ARO settlements

 

11

 

 

 

 

 

 

 

11

 

 

 

12

 

 

Gain on early extinguishment of debt

 

(2,985

)

 

 

 

 

 

 

(2,985

)

 

 

 

 

Change in fair value related to derivatives prior to settlement

 

5,332

 

 

 

(331

)

 

 

 

(69,841

)

 

 

111,618

 

 

Impairment of proved property

 

 

 

 

 

 

 

 

 

 

 

22,614

 

 

Abandonment and impairment of unproved properties

 

16,202

 

 

 

6,549

 

 

 

 

41,631

 

 

 

73,244

 

 

Lawsuit settlements

 

139

 

 

 

53

 

 

 

 

2,035

 

 

 

1,385

 

 

Rig release penalty

 

 

 

 

 

 

 

 

1,436

 

 

 

 

 

Termination costs

 

820

 

 

 

(336

)

 

 

 

3,000

 

 

 

(373

)

 

Non-cash stock-based compensation

 

9,759

 

 

 

6,952

 

 

 

 

31,940

 

 

 

42,527

 

 

Deferred compensation plan

 

(8,871

)

 

 

223

 

 

 

 

(16,432

)

 

 

(559

)

 

Tax impact

 

(46,785

)

 

 

2,268

 

 

 

 

(32,790

)

 

 

(41,322

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net (loss) income excluding certain items, a non-GAAP measure

$

(17,618

)

 

$

63,947

 

 

 

$

77,691

 

 

$

226,938

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net (loss) income per diluted share, as reported

$

(0.11

)

 

$

0.19

 

 

 

$

0.35

 

 

$

0.07

 

 

Adjustment for certain special items per diluted share:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss (gain) on sale of assets

 

0.15

 

 

 

0.00

 

 

 

 

0.12

 

 

 

(0.00

)

 

Loss on ARO settlements

 

0.00

 

 

 

 

 

 

 

0.00

 

 

 

0.00

 

 

Gain on early extinguishment of debt

 

(0.01

)

 

 

 

 

 

 

(0.01

)

 

 

 

 

Change in fair value related to derivatives prior to settlement

 

0.02

 

 

 

(0.00

)

 

 

 

(0.28

)

 

 

0.45

 

 

Impairment of proved property

 

 

 

 

 

 

 

 

 

 

 

0.09

 

 

Abandonment and impairment of unproved properties

 

0.07

 

 

 

0.03

 

 

 

 

0.17

 

 

 

0.30

 

 

Lawsuit settlements

 

0.00

 

 

 

0.00

 

 

 

 

0.01

 

 

 

0.01

 

 

Termination costs

 

0.00

 

 

 

(0.00

)

 

 

 

0.01

 

 

 

(0.00

)

 

Non-cash stock-based compensation

 

0.04

 

 

 

0.03

 

 

 

 

0.13

 

 

 

0.17

 

 

Deferred compensation plan

 

(0.04

)

 

 

0.00

 

 

 

 

(0.07

)

 

 

(0.00

)

 

Adjustment for rounding differences

 

 

 

 

 

 

 

 

0.01

 

 

 

 

 

Tax impact

 

(0.19

)

 

 

0.01

 

 

 

 

(0.13

)

 

 

(0.17

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net (loss) income per diluted share, excluding certain items, a

     non-GAAP measure

$

(0.07

)

 

$

0.26

 

 

 

$

0.31

 

 

$

0.92

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Adjusted earnings per share, a non-GAAP measure:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

$

(0.07

)

 

$

0.26

 

 

 

$

0.31

 

 

$

0.92

 

 

Diluted

$

(0.07

)

 

$

0.26

 

 

 

$

0.31

 

 

$

0.92

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

14


 

RANGE RESOURCES CORPORATION

RECONCILIATION OF CASH MARGIN PER MCFE, a non-GAAP measure

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(Unaudited, in thousands, except per unit data)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

September 30,

 

 

 

Nine Months Ended

September 30,

 

 

 

 

2019

 

 

 

2018

 

 

 

 

2019

 

 

 

2018

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenues

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural gas, NGL and oil sales, as reported

$

474,754

 

 

$

736,431

 

 

 

$

1,709,987

 

 

$

2,094,450

 

 

Derivative fair value income (loss), as reported

 

74,676

 

 

 

(34,591

)

 

 

 

208,190

 

 

 

(151,890

)

 

       Less non-cash fair value loss (gain)

 

5,332

 

 

 

(331

)

 

 

 

(69,841

)

 

 

111,618

 

 

Brokered natural gas and marketing and other, as reported

 

73,015

 

 

 

109,385

 

 

 

 

303,834

 

 

 

267,448

 

 

       Less ARO settlement and other (gains)

 

(250

)

 

 

(274

)

 

 

 

(986

)

 

 

(674

)

 

               Cash revenue applicable to production

 

627,527

 

 

 

810,620

 

 

 

 

2,151,184

 

 

 

2,320,952

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Expenses

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Direct operating, as reported

 

35,276

 

 

 

30,926

 

 

 

 

102,484

 

 

 

104,136

 

 

       Less direct operating stock-based compensation

 

(319

)

 

 

(537

)

 

 

 

(1,459

)

 

 

(1,667

)

 

Transportation, gathering and compression, as reported

 

295,912

 

 

 

304,562

 

 

 

 

899,786

 

 

 

819,100

 

 

Production and ad valorem taxes, as reported

 

7,805

 

 

 

9,427

 

 

 

 

29,004

 

 

 

29,493

 

 

Brokered natural gas and marketing, as reported

 

79,938

 

 

 

116,080

 

 

 

 

313,360

 

 

 

274,421

 

 

       Less brokered natural gas and marketing stock-based

       compensation

 

(522

)

 

 

(403

)

 

 

 

(1,523

)

 

 

(1,001

)

 

General and administrative, as reported

 

41,047

 

 

 

43,722

 

 

 

 

138,316

 

 

 

159,722

 

 

       Less G&A stock-based compensation

 

(8,423

)

 

 

(5,607

)

 

 

 

(27,561

)

 

 

(38,332

)

 

       Less lawsuit settlements

 

(139

)

 

 

(53

)

 

 

 

(2,035

)

 

 

(1,385

)

 

       Less rig release penalty

 

 

 

 

 

 

 

 

(1,436

)

 

 

 

 

Interest expense, as reported

 

46,997

 

 

 

54,801

 

 

 

 

150,261

 

 

 

161,048

 

 

            Less amortization of deferred financing costs

 

(1,795

)

 

 

(1,738

)

 

 

 

(5,388

)

 

 

(5,315

)

 

               Cash expenses

 

495,777

 

 

 

551,180

 

 

 

 

1,593,809

 

 

 

1,500,220

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cash margin, a non-GAAP measure

$

131,750

 

 

$

259,440

 

 

 

$

557,375

 

 

$

820,732

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Mmcfe produced during period

 

206,426

 

 

 

208,534

 

 

 

 

617,597

 

 

 

605,712

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cash margin per mcfe

$

0.64

 

 

$

1.24

 

 

 

$

0.90

 

 

$

1.35

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

RECONCILIATION OF (LOSS) INCOME BEFORE INCOME TAXES TO CASH MARGIN

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(Unaudited, in thousands, except per unit data)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

September 30,

 

 

 

Nine Months Ended

September 30,

 

 

 

 

2019

 

 

 

2018

 

 

 

 

2019

 

 

 

2018

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(Loss) income before income taxes, as reported

$

(74,800

)

 

$

72,676

 

 

 

$

87,591

 

 

$

56,236

 

 

Adjustments to reconcile (loss) income before income taxes to cash

     margin:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

ARO settlements and other (gains)

 

(250

)

 

 

(274

)

 

 

 

(986

)

 

 

(674

)

 

Derivative fair value (income) loss

 

(74,676

)

 

 

34,591

 

 

 

 

(208,190

)

 

 

151,890

 

 

Net cash receipts on derivative settlements

 

80,008

 

 

 

(34,922

)

 

 

 

138,349

 

 

 

(40,272

)

 

Exploration expense

 

10,517

 

 

 

7,894

 

 

 

 

25,961

 

 

 

21,990

 

 

Lawsuit settlements

 

139

 

 

 

53

 

 

 

 

2,035

 

 

 

1,385

 

 

Rig release penalty

 

 

 

 

 

 

 

 

1,436

 

 

 

 

 

Termination costs

 

820

 

 

 

(336

)

 

 

 

3,000

 

 

 

(373

)

 

Deferred compensation plan

 

(8,871

)

 

 

223

 

 

 

 

(16,432

)

 

 

(559

)

 

Stock-based compensation (direct operating, brokered natural gas

   and marketing, general and administrative and termination costs)

 

9,759

 

 

 

6,952

 

 

 

 

31,940

 

 

 

42,527

 

 

Interest – amortization of deferred financing costs

 

1,795

 

 

 

1,738

 

 

 

 

5,388

 

 

 

5,315

 

 

Depletion, depreciation and amortization

 

137,751

 

 

 

164,266

 

 

 

 

417,974

 

 

 

487,558

 

 

Loss (gain) on sale of assets

 

36,341

 

 

 

30

 

 

 

 

30,663

 

 

 

(149

)

 

Gain on early extinguishment of debt

 

(2,985

)

 

 

 

 

 

 

(2,985

)

 

 

 

 

Impairment of proved property and other assets

 

 

 

 

 

 

 

 

 

 

 

22,614

 

 

Abandonment and impairment of unproved properties

 

16,202

 

 

 

6,549

 

 

 

 

41,631

 

 

 

73,244

 

 

Cash margin, a non-GAAP measure

$

131,750

 

 

$

259,440

 

 

 

$

557,375

 

 

$

820,732

 

 

15


 

RANGE RESOURCES CORPORATION

 

 

HEDGING POSITION AS OF September 30, 2019 – (Unaudited)

 

 

 

 

 

 

 

Daily Volume

 

 

 

Hedge Price

 

 

Gas 1

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

4Q 2019 Swaps

 

 

 

1,421,739 Mmbtu

 

 

 

$2.82

 

 

 

 

 

 

 

 

 

 

 

 

 

2020 Swaps

 

 

 

821,776 Mmbtu

 

 

 

$2.66

 

 

 

 

 

 

 

 

 

 

 

 

 

2021 Swaps

 

 

 

30,000 Mmbtu

 

 

 

$2.70

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil 2

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

4Q 2019 Collars

 

 

 

1,000 bbls

 

 

 

$63 x 73

 

 

 

 

 

 

 

 

 

 

 

 

 

4Q 2019 Swaps

 

 

 

9,168 bbls

 

 

 

$56.11

 

 

 

 

 

 

 

 

 

 

 

 

 

2020 Swaps

 

 

 

7,240 bbls

 

 

 

$58.42

 

 

 

 

 

 

 

 

 

 

 

 

 

2021 Swaps

 

 

 

1,000 bbls

 

 

 

$55.00

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Natural Gas Liquids

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

4Q 2019 C3 Swaps

 

 

 

500 bbls

 

 

 

$0.525 /gallon

 

 

 

 

 

 

 

 

 

 

 

 

 

4Q 2019 NC4 Swaps

 

 

 

1,000 bbls

 

 

 

$0.60 /gallon

 

 

 

 

 

 

 

 

 

 

 

 

 

4Q 2019 iC4 Swaps

 

 

 

168 bbls

 

 

 

$0.75 /gallon

 

 

 

 

 

 

 

 

 

 

 

 

 

4Q 2019 C5 Swaps

 

 

 

5,500 bbls

 

 

 

$1.296/gallon

 

 

 

 

 

 

 

 

 

 

 

 

 

(1)

Range also sold natural gas call swaptions of 250,000 Mmbtu/d for calendar 2020, and 80,000 Mmbtu/d for calendar 2021 at average strike prices of $2.80 and $2.73 per Mmbtu, respectively.

 

(2)

Range also sold WTI calls of 500 Bbls/d for 2Q-3Q 2020 at a strike price of $59 per Bbl and WTI call swaptions of 2,000 Bbls/d for calendar 2021 at an average strike price of $56 per Bbl.

 

 

SEE WEBSITE FOR OTHER SUPPLEMENTAL INFORMATION FOR THE PERIODS AND ADDITIONAL HEDGING DETAILS

 

 

16