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Antero Resources Reports Fourth Quarter and Full-Year 2015 Financial and Operating Results

February 24, 2016

DENVER, Feb. 24, 2016 /PRNewswire/ -- Antero Resources Corporation (NYSE: AR) ("Antero" or the "Company") today released its fourth quarter and full-year 2015 financial and operating results.  The relevant financial statements are included in Antero's Annual Report on Form 10-K for the year ended December 31, 2015, which has been filed with the Securities and Exchange Commission ("SEC").

Antero Resources logo.

Highlights for the Fourth Quarter of 2015:

  • Net daily production averaged 1,497 MMcfe/d, an 18% increase over the prior year quarter and a 1% decrease sequentially
  • Includes net daily liquids production of 54,757 Bbl/d, an 80% increase over the prior year quarter and a 5% increase sequentially
  • Realized natural gas price before hedging averaged $2.13 per Mcf, a $0.14 per Mcf negative differential to Nymex, with 83% of production pricing at favorable indices
  • Realized natural gas price after hedging averaged $4.40 per Mcf, a $2.13 per Mcf positive differential to Nymex
  • Realized natural gas equivalent price including NGLs, oil and hedges averaged $4.28 per Mcfe, a 9% decrease from the prior year quarter
  • Liquids production contributed 22% of gas-equivalent volumes and 28% of total product revenues, as compared to 14% and 22%, respectively, in the prior year quarter
  • Cash production expense of $1.46 per Mcfe, a 5% reduction from the prior year quarter
  • Adjusted net income of $54 million or $0.20 per share, a 30% decrease from the prior year quarter
  • Adjusted EBITDAX of $308 million, a 7% decrease over the prior year quarter and a 6% increase sequentially
  • Announced $1.4 billion capital budget for 2016 with $3.5 billion of consolidated liquidity at year-end 2015

Recent Developments

Year-End 2015 Proved and 3P Reserves

On January 27, 2016, Antero announced that proved reserves at December 31, 2015 were 13.2 Tcfe, a 4% increase compared to proved reserves at December 31, 2014.  Finding and development cost for proved reserve additions was $0.80 per Mcfe.  This finding and development cost includes drilling and completion capital as well as costs incurred for well pads, roads, certain wellhead facilities, acquisitions, land additions and gives effect to performance and price revisions. Proved developed reserves increased by 54% from year-end 2014 to 5.8 Tcfe at December 31, 2015.  Additionally, the percentage of proved reserves classified as proved developed increased to 44% at December 31, 2015 as compared to 30% at year-end 2014. 

The Company's proved, probable and possible ("3P") reserves at year-end 2015 totaled 37.1 Tcfe, which represents a 9% decrease compared to the previous year.  Both proved and 3P reserves as of December 31, 2015 excluded 366 million barrels and 1,237 million barrels of ethane, respectively, that is expected to remain in the natural gas stream until such time that pricing supports full ethane recovery.  Antero's Marcellus and Utica 3P drilling inventory totaled 3,719 locations at year-end 2015, of which approximately 78% were in the Marcellus.

2016 Capital Budget and Guidance

On February 17, 2016, Antero announced that it expects to invest $1.3 billion in 2016 for drilling and completion and $100 million for core leasehold acreage acquisitions.  The $1.3 billion drilling and completion budget represents a 21% reduction from 2015 drilling and completion capital expenditures of $1.65 billion.  Net daily production for 2016 is projected to average 1.715 Bcfe/d, a 15% increase over 2015 actual net daily production of 1.493 Bcfe/d.  Antero's 2016 capital budget excludes Antero Midstream Partners LP's ("Antero Midstream") (NYSE: AM) $435 million capital budget relating to low and high pressure gathering pipelines, compressor stations and fresh water delivery and advanced wastewater treatment infrastructure.

Antero Resources Financial Results

As of December 31, 2015, Antero owned a 66% limited partner interest in Antero Midstream. Antero Midstream financial results are consolidated with Antero's results.

Fourth Quarter 2015 Financial Results

For the three months ended December 31, 2015, the Company reported net income from continuing operations attributable to common stockholders of $158 million, or $0.57 per basic and diluted share, compared to net income from continuing operations of $607 million or $2.32 per basic and diluted share in the fourth quarter for 2014.  GAAP net income for the fourth quarter of 2015 included the following items:

  • Non-cash gains on unsettled hedges of $275 million ($172 million net of tax)
  • Non-cash equity-based stock compensation expense of $19 million ($12 million net of tax)
  • Impairments of unproved properties of $61 million ($38 million net of tax)
  • Contract termination and rig stacking expense of $28 million ($17 million net of tax)

Without the effect of these items, the Company's results for the fourth quarter of 2015 were as follows:

  • Adjusted net income from continuing operations attributable to common stockholders of $54 million, or $0.20 per basic and diluted share, a 30% decrease compared to $78 million in the fourth quarter of 2014
  • Adjusted EBITDAX of $308 million, a 7% decrease compared to $332 million in the fourth quarter of 2014
  • Cash flow from operations before changes in working capital of $239 million, a 14% decrease compared to $278 million in the fourth quarter of 2014

Net production for the fourth quarter of 2015 averaged 1,497 MMcfe/d, an 18% increase as compared to the fourth quarter of 2014 and a 1% decrease compared to the third quarter of 2015.  The sequential decrease in production is primarily due to the periodic shut-in of production, averaging 45 MMcfe/d in the fourth quarter, as a result of Antero's decision not to sell gas at depressed pricing at the Dominion South and TETCO M2 indices.  Net production was comprised of 1,168 MMcf/d of natural gas (78%), 49,005 Bbl/d of natural gas liquids ("NGL"s) (20%) and 5,751 Bbl/d of crude oil (2%).  Fourth quarter 2015 net liquids production (NGLs and oil) of 54,757 Bbl/d increased 80% as compared to the fourth quarter of 2014 and 5% from the third quarter of 2015.

Average natural gas price before hedging decreased 42% from the prior year quarter to $2.13 per Mcf, a $0.14 per Mcf negative differential to Nymex, due to a 43% decline in Nymex.  Approximately 83% of Antero's fourth quarter 2015 natural gas production was priced at favorable indices, including Columbia Gas Transmission (TCO), Nymex, Chicago and Gulf Coast.  The remaining 17% of natural gas production was priced at various less favorable index pricing points including Dominion South and Tetco M2.

Average realized y-grade C3+ NGL price for the fourth quarter of 2015 was $17.37 per barrel, or 41% of Nymex WTI oil price, a 48% decrease as compared to the prior year quarter, and average realized oil price before hedging was $28.59 per barrel, a 52% decrease as compared to the fourth quarter of 2014.  Antero's average realized ethane price (C2) for the fourth quarter of 2015 was $6.17 per barrel, or $0.15 per gallon.  The fourth quarter of 2015 represented the first period in which Antero recovered ethane at the Sherwood processing plant in West Virginia.  Average natural gas-equivalent price including C2+ NGLs and oil, but excluding hedge settlements, decreased from the prior year quarter by 42% to $2.32 per Mcfe due to a 43% decline in both Nymex WTI and Henry Hub natural gas prices.

Average realized natural gas price including hedges was $4.40 per Mcf for the fourth quarter of 2015, in line when compared to the fourth quarter of 2014.  Average realized NGL price including hedges was $21.51 per barrel, a 37% decrease as compared to the fourth quarter of 2014.  Average realized oil price including hedges was $40.85 per barrel, a 48% decrease as compared to the fourth quarter of 2014.  Average natural gas-equivalent price including NGLs, oil and hedge settlements decreased by 9% to $4.28 per Mcfe for the fourth quarter of 2015 as compared to the fourth quarter of 2014.  For the fourth quarter of 2015, Antero realized hedging gains of $270 million, or $1.96 per Mcfe.

Total operating revenues for the fourth quarter of 2015 were $905 million as compared to $1.5 billion for the fourth quarter of 2014.  Operating revenue for the fourth quarter of 2015 included a $275 million non-cash gain on unsettled hedges while the fourth quarter of 2014 included a $853 million non-cash gain on unsettled hedges. Liquids production contributed 28% of combined natural gas, NGLs and oil revenue before hedges in the fourth quarter of 2015, as compared to a 22% contribution for the prior year quarter.  Adjusted net revenue increased 8% to $630 million compared to the fourth quarter of 2014 (including cash-settled hedge gains and losses but excluding unsettled hedge gains and losses).  For a reconciliation of adjusted net revenue to operating revenue, the most comparable GAAP measure, please read "Non-GAAP Financial Measures."

Marketing revenue for the fourth quarter of 2015 was $33 million.  Antero's marketing revenue was primarily associated with the sale of third-party gas purchased to utilize the Company's excess firm transportation capacity on the Tennessee Gas Pipeline.

Marketing expense for the fourth quarter of 2015 was $85 million.  The largest components of marketing expense were the costs related to excess capacity, the cost of purchasing third-party gas and the firm transport demand costs associated with the Company's unused ATEX ethane pipeline capacity.  During the fourth quarter, Antero gained access to over 1 Bcf/d of incremental Marcellus firm transportation takeaway capacity to more favorably priced markets through the Stonewall Pipeline and Tennessee Gas Pipeline.  This takeaway capacity was only approximately 55% utilized in December as there was limited access to the Tennessee pipeline and the firm sales agreements utilizing the Stonewall capacity were not effective until January 1, 2016.  The percentage utilization increased to approximately 80% in January 2016 with the commencement of the firm sales agreements utilizing the Stonewall pipeline and additional access to the Tennessee pipeline.  Per unit net marketing expenses for the fourth quarter of 2015 were $0.38 per Mcfe.

Additionally, as previously disclosed, there was a one-time non-cash expense of $28 million during the quarter related to the buy-back and termination of a 130 BBtu/d firm sales contract with Dominion South related pricing.  The termination of this contract has been classified as contract termination and rig stacking expense in the Company's statement of operations.  Based on year-end 2015 strip pricing, the expected incremental revenue over the next two years from terminating this contract and instead selling the volumes at the TCO index is projected to be approximately $60 million, substantially exceeding the termination charge associated with this transaction.

Per unit cash production expense (lease operating, gathering, compression, processing and transportation, and production tax) for the fourth quarter of 2015 was $1.46 per Mcfe which is a 5% decrease compared to $1.54 per Mcfe in the prior year quarter.  The per unit cash production expense for the quarter included $0.08 per Mcfe for lease operating costs, $1.23 per Mcfe for gathering, compression and transportation costs and $0.15 per Mcfe for production and ad valorem taxes.  Per unit general and administrative expense for the fourth quarter of 2015, excluding non-cash equity-based compensation expense, was $0.27 per Mcfe, a 13% increase from the fourth quarter of 2014.  The increase was primarily driven by increased staffing levels, as well as increases in legal and other general corporate expenses, partly due to Antero's increased development activities and production levels.  Per unit depreciation, depletion and amortization expense decreased 13% from the prior year quarter to $1.18 per Mcfe, primarily driven by proved developed reserves increasing at a faster rate than the corresponding cost additions from wells completed during the quarter, partially offset by increased depreciation on midstream and water assets.

Adjusted EBITDAX of $308 million for the fourth quarter of 2015 was 7% lower than the prior year quarter primarily due to decreased product revenue.  EBITDAX margin for the quarter was $2.23 per Mcfe, representing a 22% decrease from the prior year quarter primarily due to lower commodity prices.  For the fourth quarter of 2015, cash flow from operations before changes in working capital decreased 14% from the prior year to $239 million.

For a description of Adjusted EBITDAX and EBITDAX margin, cash flow from operations before changes in working capital and adjusted net income from continuing operations attributable to common stockholders and reconciliations to their nearest comparable GAAP measures, please read "Non-GAAP Financial Measures."

Antero Midstream Financial Results

Antero Midstream results were released today and are available at www.anteromidstream.com

Low pressure gathering volumes for the fourth quarter of 2015 averaged 1,124 MMcf/d, a 52% increase from the fourth quarter of 2014 and an 8% increase sequentially.  High pressure gathering volumes for the fourth quarter of 2015 averaged 1,195 MMcf/d, a 32% increase from the fourth quarter of 2014 and a 2% decrease from the third quarter of 2015.  Compression volumes for the fourth quarter of 2015 averaged 478 MMcf/d, a 115% increase from the fourth quarter of 2014 and a 10% increase sequentially.  Condensate gathering volumes averaged 3,967 Bbl/d during the quarter, a 48% increase from the fourth quarter of 2015 and 39% increase from the third quarter of 2015.  Volumetric throughput growth was driven primarily by production growth from Antero. Fresh water delivery volumes averaged 119,671 Bbl/d during the fourth quarter of 2015, a 36% decrease compared to the prior year quarter and a 78% increase sequentially.

For the three months ended December 31, 2015, Antero Midstream reported revenues of $132 million, comprised of $63 million in revenues from the Gathering and Compression segment and $69 million in revenues from the Water Handling segment. Direct operating expenses for the Gathering and Compression and Water Handling segments were $6 million and $34 million, respectively, for a total of $40 million in direct operating expenses. General and administrative expenses totaled $13 million during the fourth quarter of 2015, including $5 million of non-cash equity-based compensation expense. Total cash and non-cash operating expenses were $80 million, including $23 million of depreciation.

The Board of Directors of Antero Resources Midstream Management LLC, the general partner of Antero Midstream, declared a cash distribution of $0.22 per unit ($0.88 per unit annualized) for the fourth quarter of 2015. The distribution represents a 29% increase over the minimum quarterly distribution and a 7% increase quarter-over-quarter.  The distribution represents Antero Midstream's fourth consecutive quarterly distribution increase since its initial public offering in November 2014. The distribution will be payable on February 29, 2016 to unitholders of record as of February 15, 2016.

2015 Financial Results

Net production for 2015 averaged 1,493 MMcfe/d, an increase of 48% from the prior year.  Net production was comprised of 1,203 MMcf/d of natural gas (81%), 42,604 Bbl/d of NGLs (17%) and 5,694 Bbl/d of crude oil (2%).  Net liquids production in 2015 averaged 48,298 Bbl/d, an increase of 110% over 2014 liquids production.  The net production increase was primarily driven by liquids-rich production from 69 new Marcellus wells and 62 new Utica wells brought on line in 2015, all operated by Antero.

Average natural gas price before hedges decreased 42% from the prior year to $2.37 per Mcf, a $0.29 per Mcf negative differential to Nymex, in line with 2015 guidance of $0.20 per Mcf to $0.30 per Mcf.  Approximately 69% of Antero's 2015 natural gas production was priced at favorable indices, including Columbia Gas Transmission (TCO), Nymex and Chicago.  The remaining 31% of natural gas production was priced at various other less favorable index pricing points, including Dominion South and Tetco M2.

Average realized Y-grade C3+ NGL price for 2015 was $17.15 per barrel, or 35% of the Nymex WTI oil price, a 63% decrease as compared to the prior year and in line with 2015 guidance of 33% to 37% of WTI.  Average realized oil price before hedging was $34.05 per barrel, a 58% decrease as compared to the prior year.  Average natural gas-equivalent price including C2+ NGLs and oil, but excluding hedge settlements, decreased 47% to $2.52 per Mcfe from the prior year due to a 48% decline in Nymex WTI oil prices and 40% decline in Nymex Henry Hub natural gas prices, respectively.

Average realized natural gas price including hedges was $4.15 per Mcf for 2015, an 8% decrease as compared to 2014.  Average realized NGL price including hedges was $20.57 per barrel, a 56% decrease compared to 2014.  Average realized oil price including hedges was $42.38 per barrel, a 50% decrease as compared to 2014.  Average natural gas-equivalent price including NGLs, oil and hedge settlements, decreased by 20% to $4.10 per Mcfe for 2015 as compared to 2014.  For 2015, Antero realized hedging gains of $857 million, or $1.57 per Mcfe.

Total operating revenues for 2015 were $4.0 billion as compared to $2.7 billion for the prior year.  Operating revenue for 2015 included a $1.5 billion non-cash gain on unsettled hedges while 2014 included a $732 million non-cash gain on unsettled hedges.  Liquids production contributed 24% of combined natural gas, NGLs and oil revenue before hedges in 2015 compared to 25% during 2014.  Non-GAAP adjusted net revenue increased 25% to $2.4 billion compared to 2014 (including cash-settled hedge gains and losses but excluding unsettled hedge gains and losses).  For a reconciliation of adjusted net revenue to operating revenue, the most comparable GAAP measure, please read "Non-GAAP Financial Measures."

Marketing revenue for 2015 was $176 million.  Antero's marketing revenue was primarily associated with the sale of third-party gas purchased to utilize the Company's excess firm transportation capacity on the Rockies Express Pipeline and Tennessee Gas Pipeline.

Marketing expense for 2015 was $299 million.  The largest components of marketing expense include firm transportation costs related to current excess capacity as well as the cost of third-party purchased gas and NGLs.

Net marketing expense for 2015 was $123 million, or $0.23 per Mcfe, in line with 2015 guidance of $0.20 to $0.30 per Mcfe.    

Per unit cash production expense (lease operating, gathering, compression, processing and transportation, and production tax) for 2015 was $1.42 per Mcfe which is a 10% decrease compared to $1.58 per Mcfe in the prior year and ahead of 2015 guidance of $1.50 to $1.60 per Mcfe.  The per unit cash production expense for 2015 included $0.07 per Mcfe for lease operating costs, $1.21 per Mcfe for gathering, compression and transportation costs and $0.14 per Mcfe for production and ad valorem taxes.  The decrease was primarily due to decreases in fuel costs as compared to the prior year due to lower natural gas prices.

Per unit general and administrative expense for 2015, excluding non-cash equity based compensation expense, was $0.25 per Mcfe, an 11% decrease from 2014 and in line with 2015 guidance of $0.23 per Mcfe to $0.27 per Mcfe.  The decrease was primarily driven by the significant increase in net production.  Per unit depreciation, depletion and amortization expense was consistent with the prior year at $1.31 per Mcfe.

The Company reported net income from continuing operations attributable to common stockholders of $941 million ($3.43 per basic and diluted share) on a GAAP basis for 2015, including $1.5 billion of non-cash gains on unsettled hedges ($954 million net of tax), $98 million of non-cash equity-based compensation expense ($61 million net of tax),  $104 million of impairments of unproved properties ($65 million net of tax), and $39 million of contract termination and rig stacking expense ($24 million net of tax).  Excluding these items, adjusted net income from continuing operations attributable to common stockholders was $152 million ($0.56 per basic and diluted share) for 2015, representing a 52% decrease over the prior year. 

Adjusted EBITDAX of $1.2 billion for 2015 was 5% higher than the prior year primarily due to a 48% increase in production, which was partially offset by a 20% decrease in the average per Mcfe price received after the impact of cash settled derivatives, net of the related increases in cash operating and general and administrative expenses.  EBITDAX margin for 2015 was $2.24 per Mcfe, representing a 29% decrease from the prior year due to lower commodity prices.  For 2015, cash flow from operations before changes in working capital was in line with the prior year at $976 million.

For a description of Adjusted EBITDAX and EBITDAX margin, cash flow from operations before changes in working capital and adjusted net income from continuing operations attributable to common stockholders and reconciliations to their nearest comparable GAAP measures, please read "Non-GAAP Financial Measures."

Balance Sheet and Liquidity

As of December 31, 2015, Antero's consolidated net debt was $4.7 billion of which $1.3 billion were borrowings outstanding under the Company's $5.5 billion of lender commitments on its senior secured revolving credit facilities. Including $702 million in letters of credit outstanding, the company had $3.5 billion in available consolidated liquidity as of December 31, 2015.  For a reconciliation of consolidated net debt to total debt, the most comparable GAAP measure, please read "Non-GAAP Financial Measures."

2015 Capital Spending

Antero's drilling and completion costs for the year ended December 31, 2015, were approximately $1.65 billion.  In addition, the Company invested $199 million for additional leasehold interests, including $39 million for acquisitions and $160 million for land, and $80 million in Antero's fresh water distribution and wastewater treatment projects in the Marcellus and Utica Shale plays.  Antero's drilling and completion costs for the three months ended December 31, 2015, were $301 million.  In addition, the Company invested $28 million for additional leasehold interests during the fourth quarter of 2015. 

Conference Call

A conference call is scheduled on Thursday, February 25, 2016, at 9:00 am MT to discuss the results.  A brief Q&A session for security analysts will immediately follow the discussion of the results for the quarter.  To participate in the call, dial in at 888-347-8204 (U.S.), 855-669-9657 (Canada), or 412-902-4229 (International) and reference "Antero Resources." A telephone replay of the call will be available until Friday, March 4, 2016, at 9:00 am MT at 877-870-5176 (U.S.) or 858-384-5517 (International) using the passcode 10078393.

To access the live webcast and view the related earnings conference call presentation, visit Antero's website at www.anteroresources.com.  The webcast will be archived for replay on the Company's website until March 4, 2016, at 9:00 am MT.

Presentation

An updated presentation will be posted to the Company's website before the February 25, 2016 conference call.  The presentation can be found at www.anteroresources.com on the homepage.  Information on the Company's website does not constitute a portion of this press release.

Non-GAAP Financial Measures

Adjusted net revenue as set forth in this release represents total operating revenue adjusted for certain non-cash items, including unsettled hedge gains and losses and gains and losses on asset sales.  Antero believes that adjusted net revenue is useful to investors in evaluating operational trends of the Company and its performance relative to other oil and gas producing companies.  Adjusted net revenue is not a measure of financial performance under GAAP and should not be considered in isolation or as a substitute for total operating revenue as an indicator of financial performance.  The following table reconciles total operating revenue to adjusted net revenue:


Three months ended


Year ended

December 31,


December 31,


2014



2015


2014



2015













Total operating revenues

$

1,478,597


$

905,122


$

2,720,632


$

3,954,858

Commodity derivative fair value gains


(931,921)



(545,103)



(868,201)



(2,381,501)

Gains on settled derivatives


78,451



269,933



135,784



856,572

Gain on sale of assets


(40,000)



0



(40,000)



0

Adjusted net revenues

$

585,127


$

629,952


$

1,948,215


$

2,429,929













 

Adjusted net income from continuing operations attributable to common stockholders as set forth in this release represents net income (loss) from continuing operations attributable to common stockholders, adjusted for certain items.  Antero believes that adjusted net income from continuing operations attributable to common stockholders is useful to investors in evaluating operational trends of the Company and its performance relative to other oil and gas producing companies.  Adjusted net income from continuing operations attributable to common stockholders is not a measure of financial performance under GAAP and should not be considered in isolation or as a substitute for net income (loss) from continuing operations attributable to common stockholders as an indicator of financial performance.  The following table reconciles net income (loss) from continuing operations attributable to common stockholders to adjusted net income from continuing operations attributable to common stockholders:



Three months ended



Years ended

December 31,



December 31,



2014


2015


2014


2015












Net income from continuing operations attributable to common stockholders


$

606,722


$

158,464


$

671,377


$

941,364

Non-cash commodity derivative gains on   unsettled derivatives



(853,470)



(275,170)



(732,417)



(1,524,929)

Impairment of unproved properties



7,303



60,651



15,198



104,321

  Equity-based compensation expense



26,356



18,597



112,252



97,877

     Loss on early extinguishment of debt







20,386



 Gain on sale of assets



(40,000)





(40,000)



Contract termination and rig stacking





27,629





38,531

 Income tax effect of reconciling items



330,670



63,938



267,642



495,215

 Adjusted net income from continuing operations attributable to common stockholders


$

77,581


$

54,109


$

314,438


$

152,379

 

Cash flow from operations before changes in working capital as presented in this release represents net cash provided by operating activities before changes in working capital.  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 in isolation or as a substitute for cash flows from operating, investing, or financing activities, as an indicator of cash flows, or as a measure of liquidity.

The following table reconciles net cash provided by operating activities to cash flow from operations before changes in working capital as used in this release:



Three months ended
December 31,



Years ended
December 31,



2014


2015


2014


2015












Net cash provided by operating activities


$

199,375


$

169,781


$

998,121


$

1,006,381

Net change in working capital


78,348


68,842



(17,805)



(30,067)

Cash flow from operations before changes in working capital


$

277,723


$

238,623


$

980,316


$

976,314

 

The following table reconciles consolidated net debt to total debt as used in this release:




Years ended
December 31,



2014


2015








Bank credit facilities


$

1,730,000


$

1,327,000

6.00% senior notes due 2020



525,000



525,000

5.375% senior notes due 2021



1,000,000



1,000,000

5.125% senior notes due 2022



1,100,000



1,100,000

5.625% senior notes due 2023





750,000

Net unamortized premium



7,550



6,513

Total debt


$

4,362,550


$

4,708,513

Cash and cash equivalents



245,979



23,473

Consolidated net debt


$

4,116,571


$

4,685,040

 

Adjusted EBITDAX is a non-GAAP financial measure that Antero defines as net income from continuing operations after adjusting for those items shown in the table below.  Adjusted EBITDAX, as used and defined by the Company, may not be comparable to similarly titled measures employed by other companies and is not a measure of performance calculated in accordance with GAAP.  Adjusted EBITDAX should not be considered in isolation or as a substitute for operating income, net income, cash flows from operating, investing and financing activities, or other income or cash flow statement data prepared in accordance with GAAP.  Adjusted EBITDAX provides no information regarding a company's capital structure, borrowings, interest costs, capital expenditures, and working capital movement or tax position.  Adjusted EBITDAX does not represent funds available for discretionary use because those funds may be required for debt service, capital expenditures, working capital, income taxes, franchise taxes, exploration expenses, and other commitments and obligations.  However, Antero's management team believes Adjusted EBITDAX is useful to an investor in evaluating the Company's financial performance because this measure:

  • is widely used by investors in the oil and gas industry to measure a company's operating performance without regard to items excluded from the calculation of such term, which can vary substantially from company to company depending upon accounting methods and book value of assets, capital structure and the method by which assets were acquired, among other factors;
  • helps investors to more meaningfully evaluate and compare the results of Antero's operations from period to period by removing the effect of its capital structure from its operating structure; and
  • is used by the Company's management team for various purposes, including as a measure of operating performance, in presentations to its board of directors, as a basis for strategic planning and forecasting and by its lenders pursuant to covenants under its credit facility and the indentures governing the Company's senior notes.

There are significant limitations to using Adjusted EBITDAX as a measure of performance, including the inability to analyze the effect of certain recurring and non-recurring items that materially affect Antero's net income, the lack of comparability of results of operations of different companies and the different methods of calculating Adjusted EBITDAX reported by different companies.  The following table represents a reconciliation of the Company's net income from continuing operations to total Adjusted EBITDAX, a reconciliation of total Adjusted EBITDAX to net cash provided by operating activities and a reconciliation of realized price before cash receipts for settled hedges to Adjusted EBITDAX margin:



Three months ended December 31,


Years ended December 31,

(in thousands)


2014


2015


2014


2015














Net income from continuing operations including noncontrolling interest


$

608,970


$

175,574


$

673,625


$

979,996

Commodity derivative fair value gains



(931,921)



(545,103)



(868,201)



(2,381,501)

Gains on settled derivatives



78,451



269,933



135,784



856,572

Gain on sale of assets



(40,000)





(40,000)



Interest expense



48,994



60,471



160,051



234,400

Loss on early extinguishment of debt







20,386



Income tax expense



369,753



77,181



445,672



575,890

Depletion, depreciation, amortization, and accretion



157,252



162,178



479,167



711,418

Impairment of unproved properties



7,303



60,651



15,198



104,321

Exploration expense



6,717



760



27,893



3,846

Equity-based compensation expense



26,356



18,597



112,252



97,877

State franchise taxes



450



(59)



2,188



72

Contract termination and rig stacking





27,629





38,531

Consolidated Adjusted EBITDAX



332,325



307,812



1,164,015



1,221,422

Net income from discontinued operations



2,210





2,210



Gain on sale of assets



(3,564)





(3,564)



Income tax expense



1,354





1,354



Adjusted EBITDAX from discontinued operations









Total Adjusted EBITDAX



332,325



307,812



1,164,015



1,221,422

Interest expense



(48,994)



(60,471)



(160,051)



(234,400)

Exploration expense



(6,717)



(760)



(27,893)



(3,846)

Changes in current assets and liabilities



(78,348)



(68,842)



17,805



30,067

State franchise taxes



(450)



59



(2,188)



(72)

Other noncash items



1,559



(8,017)



6,433



(6,790)

Net cash provided by operating activities


$

199,375


$

169,781


$

998,121


$

1,006,381

 



Three months ended


Years ended



December 31,


December 31,

Adjusted EBITDAX margin ($ per Mcfe):


2014


2015


2014


2015

Realized price before gains on settled derivatives


$

4.00


$

2.32


$

4.73


$

2.52

Gathering, compression, and water handling and treatment revenues



0.09



0.05



0.06



0.04

Lease operating expense



(0.09)



(0.08)



(0.08)



(0.07)

Gathering, compression, processing and transportation costs



(1.25)



(1.23)



(1.26)



(1.21)

Marketing, net



(0.13)



(0.38)



(0.14)



(0.23)

Production and ad valorem taxes



(0.20)



(0.15)



(0.24)



(0.14)

General and administrative(1)



(0.24)



(0.26)



(0.28)



(0.24)

Gains on settled derivatives



0.68



1.96



0.37



1.57

Adjusted EBITDAX margin ($ per Mcfe):


$

2.86


$

2.23


$

3.16


$

2.24

(1)       – excludes equity-based stock compensation that is included in G&A













Antero Resources is an independent natural gas and oil company engaged in the acquisition, development and production of unconventional liquids-rich natural gas properties located in the Appalachian Basin in West Virginia, Ohio and Pennsylvania. The Company's website is located at www.anteroresources.com.

Cautionary Statements

This release includes "forward-looking statements".  Such forward-looking statements are subject to a number of risks and uncertainties, many of which are beyond Antero's control. All statements, other than historical facts included in this release, are forward-looking statements.  All forward-looking statements speak only as of the date of this release. Although Antero believes that the plans, intentions and expectations reflected in or suggested by the forward-looking statements are reasonable, there is no assurance that these plans, intentions or expectations will be achieved. Therefore, actual outcomes and results could materially differ from what is expressed, implied or forecast in such statements.  Nothing in this press release is intended to constitute guidance with respect to Antero Midstream.

Antero cautions you that these forward-looking statements are subject to all of the risks and uncertainties, most of which are difficult to predict and many of which are beyond the Company's control, incident to the exploration for and development, production, gathering and sale of natural gas, NGLs and oil. These risks include, but are not limited to, commodity price volatility and continued low commodity prices, Antero's ability to meet development and drilling plans, the Company's ability to implement its hedge strategy and results, risk regarding the timing and amount of future production of natural gas, NGLs and oil, inflation, lack of availability of drilling and production equipment and services, environmental risks, drilling and other operating risks, marketing and transportation risks, the ability to satisfy applicable minimum volume requirements, regulatory changes, the uncertainty inherent in estimating natural gas, NGL and oil reserves and in projecting future rates of production, cash flow and access to capital, the timing of development expenditures, and the other risks described under the heading "Item 1A. Risk Factors" in Antero's Annual Report on Form 10-K for the year ended December 31, 2015.

For more information, contact Michael Kennedy – SVP – Finance at (303) 357-6782 or mkennedy@anteroresources.com.

ANTERO RESOURCES CORPORATION

Consolidated Balance Sheets

December 31, 2014 and 2015

(In thousands, except share amounts)




2014


2015


Assets





Current assets:








Cash and cash equivalents


$

245,979



23,473


Accounts receivable, net of allowance for doubtful accounts of $1,251 in 2014 and $1,195 in 2015



116,203



79,404


Accrued revenue



191,558



128,242


Derivative instruments



692,554



1,009,030


Other current assets



5,866



8,087


Total current assets



1,252,160



1,248,236


Property and equipment:








Natural gas properties, at cost (successful efforts method):








Unproved properties



2,060,936



1,996,081


Proved properties



6,515,221



8,211,106


Water handling and treatment systems



421,012



565,616


Gathering systems and facilities



1,197,239



1,502,396


Other property and equipment



37,687



46,415





10,232,095



12,321,614


Less accumulated depletion, depreciation, and amortization



(879,643)



(1,589,372)


Property and equipment, net



9,352,452



10,732,242


Derivative instruments



899,997



2,108,450


Other assets



68,886



66,296


Total assets


$

11,573,495



14,155,224










Liabilities and Equity





Current liabilities:








Accounts payable


$

531,564



364,160


Accrued liabilities



168,614



194,076


Revenue distributions payable



182,352



129,949


Other current liabilities



12,202



19,085


Total current liabilities



894,732



707,270


Long-term liabilities:








Long-term debt



4,362,550



4,708,513


Deferred income tax liability



794,796



1,370,686


Other liabilities



47,587



82,077


Total liabilities



6,099,665



6,868,546


Commitments and contingencies








Equity:








Stockholders' equity:








Preferred stock, $0.01 par value; authorized - 50,000,000 shares; none issued






Common stock, $0.01 par value; authorized - 1,000,000,000 shares; issued and outstanding 262,071,642 shares and 277,035,558 shares, respectively



2,621



2,770


Additional paid-in capital



3,513,725



4,122,811


Accumulated earnings



867,447



1,808,811


Total stockholders' equity



4,383,793



5,934,392


Noncontrolling interest in consolidated subsidiary



1,090,037



1,352,286


Total equity



5,473,830



7,286,678


Total liabilities and equity


$

11,573,495



14,155,224


 

ANTERO RESOURCES CORPORATION

Consolidated Statements of Operations and Comprehensive Income (Loss)

Years Ended December 31, 2013, 2014 and 2015

(In thousands, except share and per share amounts)




2013


2014


2015


Revenue:











Natural gas sales


$

689,198



1,301,349



1,039,892


Natural gas liquids sales



111,663



328,323



264,483


Oil sales



20,584



107,080



70,753


Gathering, compression, and water handling and treatment





22,075



22,000


Marketing





53,604



176,229


Commodity derivative fair value gains



491,689



868,201



2,381,501


Gain on sale of gathering system





40,000




Total revenue



1,313,134



2,720,632



3,954,858


Operating expenses:











Lease operating



9,439



29,341



36,011


Gathering, compression, processing, and transportation



218,428



461,413



659,361


Production and ad valorem taxes



50,481



87,918



78,325


Marketing





103,435



299,062


Exploration



22,272



27,893



3,846


Impairment of unproved properties



10,928



15,198



104,321


Depletion, depreciation, and amortization



233,876



477,896



709,763


Accretion of asset retirement obligations



1,065



1,271



1,655


General and administrative (including equity-based compensation expense of $365,280, $112,252, and $97,877 in 2013, 2014, and 2015, respectively)



425,438



216,533



233,697


Contract termination and rig stacking







38,531


Total operating expenses



971,927



1,420,898



2,164,572


Operating income



341,207



1,299,734



1,790,286


Other expenses:











Interest



(136,617)



(160,051)



(234,400)


Loss on early extinguishment of debt



(42,567)



(20,386)




Total other expenses



(179,184)



(180,437)



(234,400)


Income from continuing operations before income taxes and discontinued operations



162,023



1,119,297



1,555,886


Provision for income tax expense



(186,210)



(445,672)



(575,890)


Income (loss) from continuing operations



(24,187)



673,625



979,996


Discontinued operations:











Income from sale of discontinued operations, net of income tax expense of $3,249 and $1,354 in 2013 and 2014, respectively



5,257



2,210




Net income (loss) and comprehensive income (loss) including noncontrolling interest



(18,930)



675,835



979,996


Net income and comprehensive income attributable to noncontrolling interest





2,248



38,632


Net income (loss) and comprehensive income (loss) attributable to Antero Resources Corporation


$

(18,930)



673,587



941,364













Earnings (loss) per common share:











Continuing operations


$

(0.09)



2.56



3.43


Discontinued operations



0.02



0.01




Total


$

(0.07)



2.57



3.43













Earnings (loss) per common share—assuming dilution:











Continuing operations


$

(0.09)



2.56



3.43


Discontinued operations



0.02



0.01




Total


$

(0.07)



2.57



3.43













Weighted average number of shares outstanding:











Basic



262,049,659



262,053,868



274,122,567


Diluted



262,049,659



262,068,106



274,143,341


 

ANTERO RESOURCES CORPORATION

Consolidated Statements of Cash Flows

Years ended December 31, 2013, 2014, and 2015

(In thousands)




2013


2014


2015


Cash flows from operating activities:











Net income (loss) including noncontrolling interest


$

(18,930)



675,835



979,996


Adjustment to reconcile net income to net cash provided by operating activities:











Depletion, depreciation, amortization, and accretion



234,941



479,167



711,418


Impairment of unproved properties



10,928



15,198



104,321


Derivative fair value gains



(491,689)



(868,201)



(2,381,501)


Gains on settled derivatives



163,570



135,784



856,572


Deferred income tax expense



190,210



445,672



575,890


Gain on sale of assets





(40,000)




Equity-based compensation expense



365,280



112,252



97,877


Loss on early extinguishment of debt



42,567



20,386




Gain on sale of discontinued operations



(8,506)



(3,564)




Deferred income tax expense—discontinued operations



3,249



1,354




Other



1,173



6,433



31,741


Changes in current assets and liabilities:











Accounts receivable



(9,314)



(45,593)



(3,201)


Accrued revenue



(50,156)



(94,733)



63,316


Other current assets



19,543



(2,891)



(2,221)


Accounts payable



1,039



(11,710)



5,200


Accrued liabilities



26,803



85,953



13,210


Revenue distributions payable



50,552



85,763



(52,403)


Other current liabilities



3,447



1,016



6,166


Net cash provided by operating activities



534,707



998,121



1,006,381


Cash flows used in investing activities:











Additions to proved properties



(15,300)



(64,066)




Additions to unproved properties



(440,825)



(777,422)



(198,694)


Drilling and completion costs



(1,615,965)



(2,477,150)



(1,651,282)


Additions to water handling and treatment systems



(203,790)



(196,675)



(131,051)


Additions to gathering systems and facilities



(389,453)



(558,037)



(360,287)


Additions to other property and equipment



(6,240)



(13,218)



(6,595)


Change in other assets



(2,019)



(3,082)



9,750


Proceeds from asset sales







40,000


Net cash used in investing activities



(2,673,592)



(4,089,650)



(2,298,159)


Cash flows from financing activities:











Issuance of common stock



1,578,573





537,832


Issuance of common units in Antero Midstream Partners LP





1,087,224



240,703


Issuance of senior notes



1,231,750



1,102,500



750,000


Repayment of senior notes



(690,000)



(260,000)




Borrowings (repayments) on bank credit facilities, net



71,000



1,442,000



(403,000)


Make-whole premium on debt extinguished



(33,041)



(17,383)




Payments of deferred financing costs



(20,899)



(31,543)



(17,293)


Distributions to noncontrolling interest in consolidated subsidiary







(34,129)


Other





(2,777)



(4,841)


Net cash provided by financing activities



2,137,383



3,320,021



1,069,272


Net increase (decrease) in cash and cash equivalents



(1,502)



228,492



(222,506)


Cash and cash equivalents, beginning of period



18,989



17,487



245,979


Cash and cash equivalents, end of period


$

17,487



245,979



23,473













Supplemental disclosure of cash flow information:











Cash paid during the period for interest


$

117,832



163,055



219,945


Supplemental disclosure of noncash investing activities:











Increase (decrease) in accounts payable and accrued liabilities for additions to property and equipment


$

188,123



181,591



(169,783)


 

ANTERO RESOURCES CORPORATION

The following tables set forth selected operating data for the three months ended December 31, 2014 compared to the three months ended December 31, 2015:



Three months ended December 31,


Amount of
Increase


Percent


(in thousands)


2014


2015


(Decrease)


Change


Operating revenues:













Natural gas sales


$

364,472


$

228,910


$

(135,562)


(37)

%

NGLs sales



83,516



76,080



(7,436)


(9)

%

Oil sales



18,021



15,126



(2,895)


(16)

%

Gathering, compression, and water handling and treatment



10,111



6,916



(3,195)


(32)

%

Marketing



30,556



32,987



2,431


8

%

Commodity derivative fair value gains



931,921



545,103



(386,818)


(42)

%

Gain on sale of assets



40,000





(40,000)


*


Total operating revenues



1,478,597



905,122



(573,475)


(39)

%

Operating expenses:













Lease operating



10,771



10,450



(321)


(3)

%

Gathering, compression, processing, and transportation



145,535



168,728



23,193


16

%

Production and ad valorem taxes



23,795



20,867



(2,928)


(12)

%

Marketing



45,316



84,861



39,545


87

%

Exploration



6,717



760



(5,957)


(89)

%

Impairment of unproved properties



7,303



60,651



53,348


730

%

Depletion, depreciation, and amortization



156,912



161,750



4,838


3

%

Accretion of asset retirement obligations



340



428



88


26

%

General and administrative (before equity-based compensation)



27,835



37,175



9,340


34

%

Equity-based compensation



26,356



18,597



(7,759)


(29)

%

Contract termination and rig stacking





27,629



27,629


*


Total operating expenses



450,880



591,896



141,016


31

%

Operating income



1,027,717



313,226



(714,491)


(70)

%














Other Expenses:













Interest expense



(48,994)



(60,471)



(11,477)


23

%

Income from continuing operations before income taxes and discontinued operations



978,723



252,755



(725,968)


(74)

%

Income tax expense



(369,753)



(77,181)



292,572


(79)

%

Net income and comprehensive income including noncontrolling interest



608,970



175,574



(433,396)


(71)

%

Net income and comprehensive income attributable to noncontrolling interest



2,248



17,110



14,862


661

%

Net income and comprehensive income attributable to Antero Resources Corporation


$

606,722


$

158,464


$

(448,258)


(74)

%














Adjusted EBITDAX


$

332,325


$

307,812


$

(24,513)


(7)

%














Production data:













Natural gas (Bcf)



100



107



7


7

%

NGLs (MBbl)



2,500



4,509



2,009


80

%

Oil (MBbl)



301



529



228


76

%

Combined (Bcfe)



116



138



22


18

%

Daily combined production (MMcfe/d)



1,265



1,497



232


18

%

Average prices before effects of derivative settlements:













Natural gas (per Mcf)


$

3.66


$

2.13


$

(1.53)


(42)

%

NGLs (per Bbl)


$

33.41


$

16.87


$

(16.54)


(50)

%

Oil (per Bbl)


$

59.85


$

28.59


$

(31.26)


(52)

%

Combined (per Mcfe)


$

4.00


$

2.32


$

(1.68)


(42)

%

Average realized prices after effects of derivative settlements:













Natural gas (per Mcf)


$

4.39


$

4.40


$

0.01


%

NGLs (per Bbl)


$

33.41


$

21.15


$

(12.26)


(37)

%

Oil (per Bbl)


$

78.24


$

40.85


$

(37.39)


(48)

%

Combined (per Mcfe)


$

4.68


$

4.28


$

(0.40)


(9)

%

Average Costs (per Mcfe):













Lease operating


$

0.09


$

0.08


$

(0.01)


(11)

%

Gathering, compression, processing, and transportation


$

1.25


$

1.23


$

(0.02)


(2)

%

Production and ad valorem taxes


$

0.20


$

0.15


$

(0.05)


(25)

%

Marketing, net


$

0.13


$

0.38


$

0.25


192

%

Depletion, depreciation, amortization, and accretion


$

1.35


$

1.18


$

(0.17)


(13)

%

General and administrative (before equity-based compensation)


$

0.24


$

0.27


$

0.03


13

%



*

Not meaningful or applicable

 

ANTERO RESOURCES CORPORATION

The following tables set forth selected operating data for the year ended December 31, 2014 compared to the year ended December 31, 2015:
















Year ended December 31,


Amount of
Increase


Percent


(in thousands)


2014


2015


(Decrease)


Change


Operating revenues:













Natural gas sales


$

1,301,349


$

1,039,892


$

(261,457)


(20)

%

NGLs sales



328,323



264,483



(63,840)


(19)

%

Oil sales



107,080



70,753



(36,327)


(34)

%

Gathering, compression, and water handling and treatment



22,075



22,000



(75)


%

Marketing



53,604



176,229



122,625


229

%

Commodity derivative fair value gains



868,201



2,381,501



1,513,300


174

%

Gain on sale of gathering system



40,000





(40,000)


*


Total operating revenues



2,720,632



3,954,858



1,234,226


45

%

Operating expenses:













Lease operating



29,341



36,011



6,670


23

%

Gathering, compression, processing, and transportation



461,413



659,361



197,948


43

%

Production and ad valorem taxes



87,918



78,325



(9,593)


(11)

%

Marketing



103,435



299,062



195,627


189

%

Exploration



27,893



3,846



(24,047)


(86)

%

Impairment of unproved properties



15,198



104,321



89,123


586

%

Depletion, depreciation, and amortization



477,896



709,763



231,867


49

%

Accretion of asset retirement obligations



1,271



1,655



384


30

%

General and administrative (before equity-based compensation)



104,281



135,820



31,539


30

%

Equity-based compensation



112,252



97,877



(14,375)


(13)

%

Contract termination and rig stacking





38,531



38,531


*


Total operating expenses



1,420,898



2,164,572



743,674


52

%

Operating income



1,299,734



1,790,286



490,552


38

%














Other Expenses:













Interest expense



(160,051)



(234,400)



(74,349)


46

%

Loss on early extinguishment of debt



(20,386)





20,386


*


Total other expenses



(180,437)



(234,400)



(53,963)


30

%

Income from continuing operations before income taxes and discontinued operations



1,119,297



1,555,886



436,589


39

%

Income tax expense



(445,672)



(575,890)



(130,218)


29

%

Income from continuing operations



673,625



979,996



306,371


45

%

Income from discontinued operations



2,210





(2,210)


*


Net income and comprehensive income including noncontrolling interest



675,835



979,996



304,161


45

%

Net income and comprehensive income attributable to noncontrolling interest



2,248



38,632



36,384


1,619

%

Net income and comprehensive income attributable to Antero Resources Corporation


$

673,587


$

941,364


$

267,777


40

%














Adjusted EBITDAX


$

1,164,015


$

1,221,422


$

57,407


5

%

Production data:













Natural gas (Bcf)



317



439



122


39

%

NGLs (MBbl)



7,102



15,550



8,448


119

%

Oil (MBbl)



1,311



2,078



767


58

%

Combined (Bcfe)



368



545



177


48

%

Daily combined production (MMcfe/d)



1,007



1,493



486


48

%

Average prices before effects of derivative settlements:













Natural gas (per Mcf)


$

4.10


$


2.37

$

(1.73)


(42)

%

NGLs (per Bbl)


$

46.23


$


17.01

$

(29.22)


(63)

%

Oil (per Bbl)


$

81.65


$


34.05

$

(47.60)


(58)

%

Combined (per Mcfe)


$

4.73


$


2.52

$

(2.21)


(47)

%

Average realized prices after effects of derivative settlements:













Natural gas (per Mcf)


$

4.52


$


4.15

$

(0.37)


(8)

%

NGLs (per Bbl)


$

46.23


$


20.57

$

(25.66)


(56)

%

Oil (per Bbl)


$

84.66


$


42.38

$

(42.28)


(50)

%

Combined (per Mcfe)


$

5.10


$


4.10

$

(1.00)


(20)

%

Average Costs (per Mcfe):













Lease operating


$

0.08


$


0.07

$

(0.01)


(13)

%

Gathering, compression, processing, and transportation


$

1.26


$


1.21

$

(0.05)


(4)

%

Production and ad valorem taxes


$

0.24


$


0.14

$

(0.10)


(42)

%

Marketing, net


$

0.14


$


0.23

$

0.09


64

%

Depletion, depreciation, amortization, and accretion


$

1.30


$


1.31

$

0.01


1

%

General and administrative (before equity-based compensation)


$

0.28


$


0.25

$

(0.03)


(11)

%



























*

Not meaningful or applicable

 

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SOURCE Antero Resources Corporation