Range Announces First Quarter 2016 Results
Highlights -
- Unit costs reduced by 10%, or
$0.29 per mcfe compared to prior-year quarter - Completed and contracted asset sales announced totaling approximately
$190 million of proceeds - Absolute debt levels reduced by
$631 million over the last twelve months - Existing
$3 billion bank credit facility borrowing base unanimously reaffirmed by all 29 banks - Marcellus production up 17% over prior-year quarter
- Well productivity drives production towards high-end of annual guidance
- Range becomes the first North American company to export ethane to
Europe - Peer-leading Marcellus well costs driven by operational improvements
- Recently completed
Utica dry gas well appears to be one of the best in the play based on early data
Commenting,
"The start of Mariner East during the quarter was a monumental event for Range, as the first North American company to export ethane to
Financial Discussion
Except for generally accepted accounting principles ("GAAP") reported amounts, specific expense categories exclude non-cash impairments, unrealized mark-to-market gain or loss 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 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.
Asset Sales
Range closed the sale of its
In April, Range signed a purchase and sale agreement for certain assets located in central Oklahoma for approximately
Bank Credit Facility
The Company's existing
First Quarter 2016
GAAP revenues for the first quarter of 2016 totaled
Non-GAAP revenues for first quarter 2016 totaled
Expenses | 1Q 2016 (per mcfe) |
1Q 2015 (per mcfe) |
Increase (Decrease) | ||||
Direct operating | $ 0.19 | $ 0.30 | (37%) | ||||
Transportation, gathering and compression | 1.00 | 0.75 | 33% | ||||
Production and ad valorem taxes | 0.05 | 0.08 | (38%) | ||||
General and administrative | 0.23 | 0.31 | (26%) | ||||
Interest expense | 0.30 | 0.33 | (9%) | ||||
Total cash unit costs(a) | 1.76 | 1.77 | (1%) | ||||
Depletion, depreciation and amortization | 0.96 | 1.23 | (22%) | ||||
Total unit costs(a) | $ 2.71 | $ 3.00 | (10%) | ||||
(a) Totals may not add due to rounding | |||||||
First quarter 2016 natural gas, NGLs and oil price realizations (including the impact of cash-settled hedges and derivative settlements which correspond to analysts' estimates) averaged
- Production and realized prices by each commodity for first quarter 2016 were: natural gas - 933 Mmcf per day (
$2.69 per mcf), NGLs - 65,656 barrels per day ($10.22 per barrel) and crude oil and condensate - 9,278 barrels per day ($35.49 per barrel). Total first quarter production was 1,382 Mmcfe per day ($2.54 per mcfe). - The first quarter average natural gas price, before all hedging settlements, was
$1.68 per mcf as compared to$2.84 per mcf in the prior-year quarter. NYMEX natural gas financial hedges increased realizations$0.90 per mcf in the first quarter of 2016. The average Company natural gas price differential including the impact of basis hedges for the first quarter was($0.31) per mcf compared to($0.24) per mcf in the prior-year quarter. - Total NGL pricing per barrel including ethane and processing expenses before realized cash-settled hedging improved to 25% of WTI (
$8.40 per barrel) compared to 23% of WTI ($11.16 per barrel) in the prior-year quarter. Hedging increased NGL prices by$1.82 per barrel in the first quarter. - Crude oil and condensate price realizations, before realized hedges, for the first quarter averaged
$20.00 per barrel, or$13.56 below WTI, compared to$16.19 below WTI in the prior-year quarter. Hedging added$15.49 per barrel in the first quarter.
Capital Expenditures
First quarter 2016 drilling expenditures of
Operational Discussion
Range has updated its investor presentation with first quarter financial and operational results. Please see www.rangeresources.com under the Investors tab, "Company Presentations" area, for the presentation entitled, "Company Presentation -
Production for the first quarter averaged approximately 1,330 net Mmcfe per day for the
The table below summarizes first quarter activity and the number of wells expected to be turned in line (TIL) for the remainder of 2016:
Wells TIL - First Quarter 2016 | Remaining 2016 Wells to sales | Planned Total Wells to sales in 2016 | |||||
Super-Rich area | 8 | 5 | 13 | ||||
Wet area | 9 | 29 | 38 | ||||
Dry- SW | 10 | 28 | 38 | ||||
Dry- NE | 12 | 3 | 15 | ||||
Total Marcellus/Utica | 39 | 65 | 104 | ||||
Operational efficiency gains continued in the first quarter. In the southern division, Range completed 1,324 stages during the quarter averaging over 7 stages per day per crew, which is a 9% improvement compared to the prior-year quarter. During the quarter, the Company drilled 50% more lateral feet per day per rig, on average, when compared to the prior-year quarter. This drilling improvement helped lower drilling costs per foot by 20%. These and other efficiencies have driven Range's normalized (per 1,000 feet of lateral) well costs, including surface facility costs, lower than any other Marcellus peer, as shown in the latest Company presentation.
Range also completed its third dry gas
Marcellus Shale Marketing and Transportation
The Mariner East project continued to progress in the first quarter, as the first ethane ship, the JIS INEOS Intrepid, was loaded in March. The Company is now selling ethane under a long-term contract at
Range's marketing team was able to optimize the Company's firm transportation as well as released capacity from other producers to improve cash flow during the first quarter. This is reflected in the income statement through improved Brokered natural gas, marketing and other net revenue for the quarter. This improved cash flow helped to partially offset natural gas basis differentials that were weaker than anticipated given the record warm winter. Range expects full-year natural gas differentials to range between
Guidance
Production per day Guidance
Production for the entire 2016 year has been increased to the high-end of previous guidance to average 1,410 to 1,420 Mmcfe per day after all announced asset sales. Production for the second quarter of 2016 is expected to be approximately 1,410 Mmcfe per day with 32% to 35% liquids.
Second Quarter 2016 Expense Guidance
Direct operating expense: | $0.22 - $0.23 per mcfe | |
Transportation, gathering and compression expense: | $1.03 - $1.05 per mcfe | |
Production tax expense: | $0.05 - $0.06 per mcfe | |
Exploration expense: | $5.0 - $7.0 million | |
Unproved property impairment expense: | $11.0 - $13.0 million | |
G&A expense: | $0.23 - $0.25 per mcfe | |
Interest expense: | $0.30 - $0.31 per mcfe | |
DD&A expense: | $0.96 - $0.98 per mcfe | |
Net Brokered Gas Marketing Expense | ~$3 million | |
2016 Annual Differential Guidance
Based on current market pricing indications, Range would expect to average the following pre-hedge differentials for its 2016 production.
Natural Gas: | NYMEX minus $0.40 - $0.45 | |
Natural Gas Liquids (including ethane): | 23% - 25% of WTI | |
Oil/Condensate: | WTI minus $13 - $14 | |
Hedging Status
Range hedges portions of its expected future production volumes to increase the predictability of cash flow. Range currently has approximately 80% of its expected 2016 natural gas production hedged at a weighted average floor price of
Range has hedged Marcellus and other basis differentials covering 143,452 Mmbtu per day for
Range has also hedged the premium spread between the
Conference Call Information
A conference call to review the financial results is scheduled on
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
Non-GAAP Financial Measures
Adjusted net income or loss comparable to analysts' estimates as set forth in this release represents income or loss 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 to adjusted net income (loss) 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 from operating activities 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 operating activities, investing, or financing activities as an indicator of cash flows, or as a measure of liquidity. A table is included which reconciles Net cash from operating activities 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 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 and compression expense, such information is now reported in various lines of the statement of operations. The Company believes that it is important to furnish a table reflecting the details of the various components of each statement of operations 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 and compression expense which historically were 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.
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, expected production, 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, expected NGL ship loading and associated costs 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, including, but not limited to, the volatility of oil and gas prices, the results of our hedging transactions, the costs and results of actual drilling and operations, the timing of production, mechanical and other inherent risks associated with oil and gas production, weather, the availability of drilling equipment, changes in interest rates, litigation, uncertainties about reserve estimates, environmental risks and regulatory changes. Range undertakes no obligation to publicly update or revise any forward-looking statements. Further information on risks and uncertainties is available in Range's filings with the
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
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 March 31, | |||||||||||||
2016 | 2015 | % | |||||||||||
Revenues and other income: | |||||||||||||
Natural gas, NGLs and oil sales (a) | $ | 209,487 | $ | 325,483 | |||||||||
Derivative fair value (loss)/income | 86,908 | 122,839 | |||||||||||
Brokered natural gas, marketing and other (b) | 34,858 | 14,433 | |||||||||||
ARO settlement gain (loss) (b) | (2 | ) | (2 | ) | |||||||||
Other (b) | 162 | 54 | |||||||||||
Total revenues and other income | 331,413 | 462,807 | -28 | % | |||||||||
Costs and expenses: | |||||||||||||
Direct operating | 23,466 | 36,251 | |||||||||||
Direct operating - non-cash stock-based compensation (c) | 588 | 886 | |||||||||||
Transportation, gathering and compression | 125,263 | 89,426 | |||||||||||
Production and ad valorem taxes | 5,887 | 9,928 | |||||||||||
Brokered natural gas and marketing | 36,042 | 21,056 | |||||||||||
Brokered natural gas and marketing - non-cash stock-based compensation (c) | 516 | 506 | |||||||||||
Exploration | 4,223 | 7,154 | |||||||||||
Exploration - non-cash stock-based compensation (c) | 690 | 732 | |||||||||||
Abandonment and impairment of unproved properties | 10,628 | 11,491 | |||||||||||
General and administrative | 28,423 | 36,663 | |||||||||||
General and administrative - non-cash stock-based compensation (c) | 11,113 | 11,080 | |||||||||||
General and administrative - lawsuit settlements | 921 | 336 | |||||||||||
General and administrative - bad debt expense | 200 | 250 | |||||||||||
Termination costs | 162 | 4,663 | |||||||||||
Termination costs - non-cash stock-based compensation (c) | - | 1,287 | |||||||||||
Deferred compensation plan (d) | 16,056 | (5,624 | ) | ||||||||||
Interest expense | 37,739 | 39,207 | |||||||||||
Depletion, depreciation and amortization | 120,561 | 147,290 | |||||||||||
Impairment of proved properties and other assets | 43,040 | - | |||||||||||
Loss on sale of assets | 1,643 | 175 | |||||||||||
Total costs and expenses | 467,161 | 412,757 | 13 | % | |||||||||
(Loss) income before income taxes | (135,748 | ) | 50,050 | -371 | % | ||||||||
Income tax (benefit) expense: | |||||||||||||
Current | - | - | |||||||||||
Deferred | (44,038 | ) | 22,366 | ||||||||||
(44,038 | ) | 22,366 | |||||||||||
Net (loss) income | $ | (91,710 | ) | $ | 27,684 | -431 | % | ||||||
Net (Loss) Income Per Common Share: | |||||||||||||
Basic | $ | (0.55 | ) | $ | 0.16 | ||||||||
Diluted | $ | (0.55 | ) | $ | 0.16 | ||||||||
Weighted average common shares outstanding, as reported: | |||||||||||||
Basic | 166,803 | 166,039 | 0 | % | |||||||||
Diluted | 166,803 | 166,066 | 0 | % | |||||||||
(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. |
RANGE RESOURCES CORPORATION | ||||||||||
BALANCE SHEETS | ||||||||||
(In thousands) | March 31, | December 31, | ||||||||
2016 | 2015 | |||||||||
(Unaudited) | (Audited) | |||||||||
Assets | ||||||||||
Current assets | $ | 130,647 | $ | 157,530 | ||||||
Derivative assets | 266,509 | 288,762 | ||||||||
Natural gas and oil properties, successful efforts method | 6,216,744 | 6,361,305 | ||||||||
Transportation and field assets | 17,872 | 19,455 | ||||||||
Other | 73,378 | 72,979 | ||||||||
$ | 6,705,150 | $ | 6,900,031 | |||||||
Liabilities and Stockholders' Equity | ||||||||||
Current liabilities | $ | 322,971 | $ | 335,513 | ||||||
Asset retirement obligations | 15,071 | 15,071 | ||||||||
Derivative liabilities | 192 | 1,136 | ||||||||
Bank debt | 23,149 | 86,427 | ||||||||
Senior notes | 738,362 | 738,101 | ||||||||
Senior subordinated notes | 1,827,554 | 1,826,775 | ||||||||
Total debt | 2,589,065 | 2,651,303 | ||||||||
Deferred tax liability | 735,971 | 777,947 | ||||||||
Derivative liabilities | 1,270 | 21 | ||||||||
Deferred compensation liability | 115,152 | 104,792 | ||||||||
Asset retirement obligations and other liabilities | 254,114 | 254,590 | ||||||||
Common stock and retained earnings | 2,673,215 | 2,761,903 | ||||||||
Common stock held in treasury stock | (1,871 | ) | (2,245 | ) | ||||||
Total stockholders' equity | 2,671,344 | 2,759,658 | ||||||||
$ | 6,705,150 | $ | 6,900,031 | |||||||
RECONCILIATION OF TOTAL REVENUES AND OTHER INCOME TO TOTAL REVENUE EXCLUDING CERTAIN ITEMS, a non-GAAP measure | |||||||||||
(Unaudited, in thousands) | Three Months Ended March 31, | ||||||||||
2016 | 2015 | % | |||||||||
Total revenues and other income, as reported | $ | 331,413 | $ | 462,807 | -28 | % | |||||
Adjustment for certain special items: | |||||||||||
Total change in fair value related to derivatives prior to settlement (gain) loss | 22,558 | (25,349 | ) | ||||||||
ARO settlement (gain) loss | 2 | 2 | |||||||||
Total revenues, as adjusted, non-GAAP | $ | 353,973 | $ | 437,460 | -19 | % | |||||
RANGE RESOURCES CORPORATION |
|||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||||||||
(Unaudited, in thousands) | Three Months Ended March 31, | ||||||||||
2016 | 2015 | ||||||||||
Net (loss) income | $ | (91,710 | ) | $ | 27,684 | ||||||
Adjustments to reconcile net cash provided from continuing operations: | |||||||||||
Deferred income tax (benefit) expense | (44,038 | ) | 22,366 | ||||||||
Depletion, depreciation, amortization and impairment | 163,601 | 147,290 | |||||||||
Exploration dry hole costs | - | 103 | |||||||||
Abandonment and impairment of unproved properties | 10,628 | 11,491 | |||||||||
Derivative fair value income | (86,908 | ) | (122,839 | ) | |||||||
Cash settlements on derivative financial instruments that do not qualify for hedge accounting | 109,466 | 97,490 | |||||||||
Allowance for bad debts | 200 | 250 | |||||||||
Amortization of deferred issuance costs, loss on extinguishment of debt, and other | 1,707 | 1,358 | |||||||||
Deferred and stock-based compensation | 29,128 | 9,218 | |||||||||
Loss on sale of assets and other | 1,643 | 175 | |||||||||
Changes in working capital: | |||||||||||
Accounts receivable | 18,752 | 54,435 | |||||||||
Inventory and other | 5,333 | (1,072 | ) | ||||||||
Accounts payable | 11,922 | 7,098 | |||||||||
Accrued liabilities and other | (42,300 | ) | (44,409 | ) | |||||||
Net changes in working capital | (6,293 | ) | 16,052 | ||||||||
Net cash provided from operating activities | $ | 87,424 | $ | 210,638 | |||||||
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 March 31, | ||||||||||
2016 | 2015 | ||||||||||
Net cash provided from operating activities, as reported | $ | 87,424 | $ | 210,638 | |||||||
Net changes in working capital | 6,293 | (16,052 | ) | ||||||||
Exploration expense | 4,223 | 7,051 | |||||||||
Lawsuit settlements | 921 | 336 | |||||||||
Termination costs | 162 | 4,663 | |||||||||
Non-cash compensation adjustment | (84 | ) | (103 | ) | |||||||
Cash flow from operations before changes in working capital - a non-GAAP measure | $ | 98,939 | $ | 206,533 | |||||||
ADJUSTED WEIGHTED AVERAGE SHARES OUTSTANDING | |||||||||||
(Unaudited, in thousands) | Three Months Ended March 31, | ||||||||||
2016 | 2015 | ||||||||||
Basic: | |||||||||||
Weighted average shares outstanding | 169,584 | 168,861 | |||||||||
Stock held by deferred compensation plan | (2,781 | ) | (2,822 | ) | |||||||
Adjusted basic | 166,803 | 166,039 | |||||||||
Dilutive: | |||||||||||
Weighted average shares outstanding | 169,584 | 168,861 | |||||||||
Dilutive stock options under treasury method | (2,781 | ) | (2,795 | ) | |||||||
Adjusted dilutive | 166,803 | 166,066 | |||||||||
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 March 31, | |||||||||||
2016 | 2015 | % | ||||||||||
Natural gas, NGL and oil sales components: | ||||||||||||
Natural gas sales | $ | 142,435 | $ | 228,740 | ||||||||
NGL sales | 50,162 | 59,811 | ||||||||||
Oil sales | 16,890 | 36,932 | ||||||||||
Total oil and gas sales, as reported | $ | 209,487 | $ | 325,483 | -36 | % | ||||||
Derivative fair value income (loss), as reported: | $ | 86,908 | $ | 122,839 | ||||||||
Cash settlements on derivative financial instruments - (gain) loss: | ||||||||||||
Natural gas | (85,515 | ) | (55,869 | ) | ||||||||
NGLs | (10,878 | ) | (5,595 | ) | ||||||||
Crude Oil | (13,073 | ) | (36,026 | ) | ||||||||
Total change in fair value related to derivatives prior to settlement, a non-GAAP measure | $ | (22,558 | ) | $ | 25,349 | |||||||
Transportation, gathering and compression components: | ||||||||||||
Natural gas | $ | 92,592 | $ | 76,527 | ||||||||
NGLs | 32,671 | 12,899 | ||||||||||
Total transportation, gathering and compression, as reported | $ | 125,263 | $ | 89,426 | ||||||||
Natural gas, NGL and oil sales, including cash-settled derivatives: (c) | ||||||||||||
Natural gas sales | $ | 227,950 | $ | 284,609 | ||||||||
NGL sales | 61,040 | 65,406 | ||||||||||
Oil sales | 29,963 | 72,958 | ||||||||||
Total | $ | 318,953 | $ | 422,973 | -25 | % | ||||||
Production of oil and gas during the periods (a): | ||||||||||||
Natural gas (mcf) | 84,867,370 | 80,500,036 | 5 | % | ||||||||
NGL (bbl) | 5,974,734 | 5,359,276 | 11 | % | ||||||||
Oil (bbl) | 844,341 | 1,138,960 | -26 | % | ||||||||
Gas equivalent (mcfe) (b) | 125,781,820 | 119,489,452 | 5 | % | ||||||||
Production of oil and gas - average per day (a): | ||||||||||||
Natural gas (mcf) | 932,608 | 894,445 | 4 | % | ||||||||
NGL (bbl) | 65,656 | 59,548 | 10 | % | ||||||||
Oil (bbl) | 9,278 | 12,655 | -27 | % | ||||||||
Gas equivalent (mcfe) (b) | 1,382,218 | 1,327,661 | 4 | % | ||||||||
Average prices, including cash-settled hedges that qualify for hedge accounting before third party transportation costs: | ||||||||||||
Natural gas (mcf) | $ | 1.68 | $ | 2.84 | -41 | % | ||||||
NGL (bbl) | $ | 8.40 | $ | 11.16 | -25 | % | ||||||
Oil (bbl) | $ | 20.00 | $ | 32.43 | -38 | % | ||||||
Gas equivalent (mcfe) (b) | $ | 1.67 | $ | 2.72 | -39 | % | ||||||
Average prices, including cash-settled hedges and derivatives before third party transportation costs: (c) | ||||||||||||
Natural gas (mcf) | $ | 2.69 | $ | 3.54 | -24 | % | ||||||
NGL (bbl) | $ | 10.22 | $ | 12.20 | -16 | % | ||||||
Oil (bbl) | $ | 35.49 | $ | 64.06 | -45 | % | ||||||
Gas equivalent (mcfe) (b) | $ | 2.54 | $ | 3.54 | -28 | % | ||||||
Average prices, including cash-settled hedges and derivatives: (d) | ||||||||||||
Natural gas (mcf) | $ | 1.59 | $ | 2.58 | -38 | % | ||||||
NGL (bbl) | $ | 4.75 | $ | 9.80 | -52 | % | ||||||
Oil (bbl) | $ | 35.49 | $ | 64.06 | -45 | % | ||||||
Gas equivalent (mcfe) (b) | $ | 1.54 | $ | 2.79 | -45 | % | ||||||
Transportation, gathering and compression expense per mcfe | $ | 1.00 | $ | 0.75 | 33 | % | ||||||
(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. |
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 March 31, | |||||||||||
2016 | 2015 | % | ||||||||||
(Loss) income before income taxes, as reported | $ | (135,748 | ) | $ | 50,050 | -371 | % | |||||
Adjustment for certain special items: | ||||||||||||
Loss on sale of assets | 1,643 | 175 | ||||||||||
Loss on ARO settlements | 2 | 2 | ||||||||||
Change in fair value related to derivatives prior to settlement | 22,558 | (25,349 | ) | |||||||||
Abandonment and impairment of unproved properties | 10,628 | 11,491 | ||||||||||
Impairment of proved property and other assets | 43,040 | - | ||||||||||
Lawsuit settlements | 921 | 336 | ||||||||||
Termination costs | 162 | 4,663 | ||||||||||
Termination costs - non-cash stock-based compensation | - | 1,287 | ||||||||||
Brokered natural gas and marketing - non-cash stock-based compensation | 516 | 506 | ||||||||||
Direct operating - non-cash stock-based compensation | 588 | 886 | ||||||||||
Exploration expenses - non-cash stock-based compensation | 690 | 732 | ||||||||||
General & administrative - non-cash stock-based compensation | 11,113 | 11,080 | ||||||||||
Deferred compensation plan - non-cash adjustment | 16,056 | (5,624 | ) | |||||||||
(Loss) income before income taxes, as adjusted | (27,831 | ) | 50,235 | -155 | % | |||||||
Income tax (benefit) expense, as adjusted | ||||||||||||
Current | - | - | ||||||||||
Deferred (a) | (10,697 | ) | 19,299 | |||||||||
Net (loss) income excluding certain items, a non-GAAP measure | $ | (17,134 | ) | $ | 30,936 | -155 | % | |||||
Non-GAAP (loss) income per common share | ||||||||||||
Basic | $ | (0.10 | ) | $ | 0.19 | -153 | % | |||||
Diluted | $ | (0.10 | ) | $ | 0.19 | -153 | % | |||||
Non-GAAP diluted shares outstanding, if dilutive | 166,803 | 166,066 | ||||||||||
(a) | Deferred taxes are estimated to be approximately 38%. |
RANGE RESOURCES CORPORATION | ||||
HEDGING POSITION AS OF APRIL 25, 2016 | ||||
(Unaudited) | ||||
Daily Volume | Hedge Price | |||
Gas | ||||
2Q 2016 Swaps | 760,000 Mmbtu | $3.21 | ||
3Q 2016 Swaps | 760,000 Mmbtu | $3.22 | ||
4Q 2016 Swaps | 760,000 Mmbtu | $3.24 | ||
2017 Swaps | 205,000 Mmbtu | $2.83 | ||
2018 Swaps | 50,000 Mmbtu | $2.88 | ||
Oil | ||||
2Q 2016 Swaps | 6,000 bbls | $59.21 | ||
3Q 2016 Swaps | 5,750 bbls | $58.73 | ||
4Q 2016 Swaps | 5,750 bbls | $58.73 | ||
2017 Swaps | 1,000 bbls | $50.13 | ||
C2 Ethane | ||||
3Q 2016 Swaps | 500 bbls | $0.22/gallon | ||
4Q 2016 Swaps | 500 bbls | $0.22/gallon | ||
2017 Swaps | 1,000 bbls | $0.25/gallon | ||
C3 Propane | ||||
2Q 2016 Swaps | 5,500 bbls | $0.60/gallon | ||
3Q 2016 Swaps | 5,500 bbls | $0.60/gallon | ||
4Q 2016 Swaps | 5,500 bbls | $0.60/gallon | ||
C4 Normal Butane | ||||
2Q 2016 Swaps | 3,918 bbls | $0.66/gallon | ||
3Q 2016 Swaps | 4,000 bbls | $0.66/gallon | ||
4Q 2016 Swaps | 4,000 bbls | $0.66/gallon | ||
C5 Natural Gasoline | ||||
2Q 2016 Swaps | 3,250 bbls | $1.14/gallon | ||
3Q 2016 Swaps | 3,500 bbls | $1.11/gallon | ||
4Q 2016 Swaps | 3,500 bbls | $1.11/gallon | ||
2017 Swaps | 1,000 bbls | $0.92/gallon | ||
NOTE: SEE WEBSITE FOR OTHER SUPPLEMENTAL INFORMATION FOR THE PERIODS
Investor Contacts:
Vice President - Investor Relations
817-869-4267
lsando@rangeresources.com
Investor Relations Manager
817-869-4266
damend@rangeresources.com
Senior Financial Analyst
817-869-4264
mfreeman@rangeresources.com
Media Contact:
Director of Corporate Communications
724-873-3224
mpitzarella@rangeresources.com
www.rangeresources.com
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