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Antero Resources Reports Second Quarter 2015 Financial Results

July 29, 2015

DENVER, July 29, 2015 /PRNewswire/ -- Antero Resources Corporation (NYSE: AR) ("Antero" or the "Company") today released its second quarter 2015 financial results. The relevant financial statements are included in Antero's Quarterly Report on Form 10-Q for the quarter ended June 30, 2015, which has been filed with the Securities and Exchange Commission ("SEC").

Antero Resources logo.

Highlights for the Second Quarter of 2015:

  • Net daily gas equivalent production averaged 1,484 MMcfe/d, a 67% increase compared to the prior year quarter and flat compared to the prior quarter
  • Net daily liquids production, included in the above, averaged 45,906 Bbl/d, a 127% increase compared to the prior year quarter and a 15% increase sequentially
  • Realized natural gas equivalent price including NGLs, oil and hedges averaged $3.85 per Mcfe
  • On a per unit basis, cash production expense declined 9%, or $0.15 per Mcfe, and G&A expense declined 28%, or $0.09 per Mcfe, compared to the prior year quarter
  • Adjusted net income of $17 million ($0.06 per share), a 77% decrease compared to the prior year quarter
  • Adjusted EBITDAX of $268 million, a 1% increase compared to the prior year quarter
  • Hedge portfolio was increased to 2.8 Tcfe of future natural gas equivalent production at an average index price of $4.08 per MMBtu

Recent Developments

2016 Production Growth Targets

As previously disclosed on July 15, 2015, Antero is preliminarily targeting 25% to 30% year-over-year net production growth in 2016, driven in part by the contribution early next year from the completion of 50 Marcellus Shale deferred completions.  While not yet board-approved and subject to change depending on the commodity price environment, this production growth target is expected to only require a modest increase in estimated 2016 drilling and completion costs, due to the operational improvements and cost savings currently being achieved.

Antero expects to continue reviewing this preliminary 2016 production target and capital budget throughout the year and anticipates finalizing the capital budget and receiving board approval in late 2015 or early 2016.

Second Quarter 2015 Financial Results

As of June 30, 2015, Antero owned a 69.7% limited partner interest in Antero Midstream Partners LP ("Antero Midstream"). Antero Midstream's results are consolidated with Antero's results.  

For the three months ended June 30, 2015, the Company reported a net loss attributable to common stockholders of $145 million, or $(0.52) per basic and diluted share, compared to a net loss of $42 million in the second quarter of 2014.  The GAAP net loss for the second quarter of 2015 included the following items:

  • Non-cash losses on unsettled hedges of $198 million ($123 million net of tax)
  • Non-cash equity-based stock compensation expense of $28 million ($22 million net of tax)
  • Impairment of unproved properties of $26 million ($16 million net of tax)
  • Contract termination and rig stacking expenses of $2 million ($1 million net of tax)

Without the effect of these non-cash or unusual items, the Company's results for the second quarter of 2015 were as follows:

  • Adjusted net income attributable to common stockholders of $17 million, or $0.06 per basic and diluted share, a 77% decrease compared to the second quarter of 2014
  • Adjusted EBITDAX of $268 million, a 1% increase compared to the second quarter of 2014
  • Cash flow from operations before changes in working capital of $208 million, a 5% decrease compared to the second quarter of 2014

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

Net daily production for the second quarter of 2015 averaged 1,484 MMcfe/d, a 67% increase as compared to the second quarter of 2014 and was approximately the same as the first quarter of 2015.  Net daily production was comprised of 1,208 MMcf/d of natural gas (82%), 40,162 Bbl/d of natural gas liquids ("NGLs") (16%) and 5,744 Bbl/d of crude oil (2%).  Second quarter 2015 net liquids (NGLs and oil) daily production of 45,906 Bbl/d increased 127% as compared to the second quarter of 2014 and 15% from the first quarter of 2015.

Average natural gas price before hedging decreased 51% from the prior year quarter to $2.20 per Mcf, a $0.44 per Mcf negative differential to Nymex, as Nymex natural gas prices decreased 43% from the prior year quarter.  Approximately 62% of Antero's second quarter 2015 natural gas revenue was realized at favorable price indices, including Columbia Gas Transmission (TCO), Chicago and Nymex.  The remaining 38% of natural gas production was priced at various less favorable index pricing points, including Dominion South and Tetco M2.  Antero's average realized natural gas price after hedging for the second quarter of 2015 was $3.86 per Mcf, a $1.22 positive differential to the Nymex average price for the period, a 15% decrease compared to the prior year quarter.  During the quarter, Antero realized a settled natural gas hedge gain of $182 million, or $1.66 per Mcf.

Antero's average realized C3+ NGL price before hedging for the second quarter of 2015 was $16.29 per barrel, or approximately 28% of the WTI oil price average for the period.  This represents a 70% decrease for NGL prices compared to the prior year quarter as WTI oil prices decreased 44% from the prior year quarter.  The Company's average realized NGL price after hedging represented a 65% decrease from the prior year quarter NGL price to $19.51 per barrel, or 34% of the WTI oil price average for the period.  For the second quarter of 2015, Antero realized a settled NGL hedge gain of $12 million, or $3.22 per barrel. Antero's NGL barrels are comprised of propane, butane and heavier liquids, as ethane is rejected at the gas processing plant and sold in the natural gas stream. 

Antero's average realized oil price before hedging for the second quarter of 2015 was $44.06 per barrel, a $13.58 per barrel negative differential to the average WTI oil price for the period, and a 52% decrease compared to the prior year quarter.  The Company's average realized oil price after hedging decreased 46% from the prior year quarter to $47.33 per barrel, a $10.31 per barrel negative differential to the WTI price.  For the second quarter of 2015, Antero realized a settled oil hedge gain of $2 million, or $3.27 per barrel. 

Antero's liquids production and realizations for the second quarter of 2015 added an incremental $0.20 per Mcfe to the average gas equivalent price per unit, increasing the average natural gas realized price before hedging from $2.20 per Mcf to $2.40 per Mcfe on a gas equivalent basis.  Including $196 million of total settled realized hedge gains for all products, the average all-in natural gas equivalent price, including NGLs, oil and hedge settlements, was $3.85 per Mcfe for the second quarter of 2015.

Total revenues for the second quarter of 2015 were $377 million as compared to $311 million for the second quarter of 2014.  Revenue for the second quarter of 2015 included a $198 million non-cash loss on unsettled hedges while the second quarter of 2014 included a $125 million non-cash loss on unsettled hedges. Liquids production contributed 25% of combined natural gas, NGLs and oil revenue before hedging in the second quarter of 2015.  Adjusted net revenue increased 32% to $575 million compared to the second quarter of 2014 (including settled hedge gains and losses but excluding non-cash 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 second quarter of 2015 was $50 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 as well as to capture the positive spread between Tetco M2 pricing and Chicago pricing.  Marketing expense for the second quarter of 2015 was $79 million.  The largest components of marketing expense were the fixed transportation costs related to excess capacity, the cost of purchasing third-party gas and the fixed transportation costs associated with the Company's underutilized ATEX ethane pipeline capacity.  Net marketing expense was $29 million or $0.22 per Mcfe for the second quarter of 2015.

Per unit cash production expense (lease operating, gathering, compression, processing and transportation, and production tax) for the second quarter of 2015 was $1.45 per Mcfe which is a 9% decrease compared to $1.60 per Mcfe in the prior year quarter.  The decrease in cash production expense was driven by lower production taxes due to lower commodity prices.  Per unit general and administrative expense for the second quarter of 2015, excluding non-cash equity-based compensation expense, was $0.23 per Mcfe, a 28% decrease from the second quarter of 2014.  The decrease was primarily driven by the significant increase in net production which was somewhat offset by an increase in the Company's workforce.  Per unit depreciation, depletion and amortization expense increased 1% from the prior year quarter to $1.31 per Mcfe.

Adjusted EBITDAX of $268 million for the second quarter of 2015 was 1% higher than the prior year quarter due to increased production and revenue.  EBITDAX margin for the quarter was $1.99 per Mcfe, representing a 40% decrease from the prior year quarter due to lower commodity prices.  For the second quarter of 2015, cash flow from operations before changes in working capital decreased 5% from the prior year to $208 million.

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

Antero Midstream Financial Results

Antero Midstream's low pressure gathering volumes for the second quarter of 2015 averaged 965 MMcf/d, a 150% increase from the prior year quarter and 3% sequentially.  High pressure gathering and compression volumes for the second quarter of 2015 averaged 1,197 MMcf/d and 454 MMcf/d, respectively, representing 350% and 1,005% year over year growth from the second quarter of 2014 and 6% and 27% sequentially.  Condensate gathering volumes averaged 3 MBbl/d in the second quarter of 2015, representing no change from the second quarter of 2014 and 24% growth sequentially.  The high growth in throughput volumes was driven by production growth from Antero.

Antero Midstream's revenue for the second quarter of 2015 was $57 million as compared to $17 million for the prior year quarter, primarily driven by increased throughput volumes across Antero Midstream's systems.  Revenues in the second quarter of 2015 were comprised entirely of fixed fees from Antero.  Direct operating expenses totaled $11 million and general and administrative expenses totaled $10 million, including $5 million of non-cash equity-based compensation.  Total operating expenses were $36 million including $15 million of depreciation.  Operating income for the second quarter of 2015 was $21 million as compared to $0.3 million in the prior year quarter, while net income was $20 million as compared to a $0.3 million for the prior year quarter.

Antero Midstream invested $74 million in gathering and compression projects in the second quarter of 2015, including $52 million in the Marcellus and $22 million in the Utica.

On July 15, 2015, Antero Midstream declared a cash distribution of $0.19 per unit ($0.76 per unit annualized) for the second quarter of 2015. The distribution represents a 6% increase compared to the first quarter 2015 distribution and 12% increase compared to the Partnership's minimum quarterly distribution of $0.17 per unit ($0.68 per unit annualized). The distribution is payable on August 27, 2015 to unitholders of record as of August 13, 2015.

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

Balance Sheet and Liquidity

As of June 30, 2015, the Company's consolidated net debt was $4.36 billion, of which $1.1 billion were borrowings outstanding under the Company's $4.0 billion senior secured revolving credit facility, and no borrowings under the $1.0 billion senior secured credit facility for Antero Midstream.  Including the $475 million in letters of credit outstanding, the Company had $3.5 billion in available liquidity on a consolidated basis as of June 30, 2015.  For a reconciliation of consolidated net debt to consolidated total debt, the most comparable GAAP measure, please read "Non-GAAP Financial Measures."

Second Quarter 2015 Capital Spending

Antero's drilling and completion costs for the three months ended June 30, 2015 were $440 million.  In addition, the Company invested $46 million for land, $12 million for water projects in the Marcellus and Utica Shale plays and $1 million in other capital projects.

As previously disclosed, the Company also invested $34 million during the quarter on a bolt-on acquisition in the core of the Marcellus Shale liquids rich window in Tyler County, West Virginia. Given the uncertainty surrounding potential transactions, Antero does not include acquisitions in its capital budget.

Hedge Position

Antero currently has hedged 2.8 Tcfe of future natural gas equivalent production using fixed price swaps covering the period from July 1, 2015 through December 31, 2021 at an average index price of $4.08 per MMBtu and a mark-to-market value at June 30, 2015 of $2.0 billion.

The following table summarizes Antero's hedge positions held as of July 28, 2015:

Period


Natural Gas

MMBtu/d


Average

Index Price

($/MMBtu)

Liquids

Bbl/d

Average

Index Price








3Q 2015:







TCO


120,000


$4.93

Nymex HH


770,000


$3.79

Dom South


230,000


$5.48

CGTLA


40,000


$3.93

Nymex WTI ($/Bbl)



3,000

$64.84

Propane MB ($/Gallon)



23,000

$0.62

                  3Q 2015 Total


1,160,000


$4.25

26,000

4Q 2015:







TCO


120,000


$5.14

Nymex HH


770,000


$3.92

Dom South


230,000


$5.74

CGTLA


40,000


$4.09

Nymex WTI ($/Bbl)



3,000

$65.67

Propane MB ($/Gallon)



23,000

$0.64

                  4Q 2015 Total


1,160,000


$4.41

26,000

2016:







TCO


60,000


$4.91

Nymex HH


960,000


$3.56

Dom South


272,500


$5.35

CGTLA


170,000


$4.09

Propane MB ($/Gallon)



30,000

$0.59

                       2016 Total


1,462,500


$4.01

30,000

2017


1,150,000


$4.02

2,000

$0.64

2018


1,402,500


$4.25

2,000

$0.65

2019


1,537,500


$4.05

2020


1,010,000


$3.82

2021


100,000


$3.74

Approximately 66% of Antero's 2015 natural gas financial hedge portfolio is made up of Nymex Henry Hub hedges and 34% is tied to Appalachian Basin or Gulf Coast indices.  Antero has the ability to physically deliver a substantial portion of its natural gas production through direct firm transportation to the Columbia Gulf Coast Onshore index near Henry, Louisiana, the index for Nymex Henry Hub pricing, essentially eliminating basis risk on the Company's Nymex Henry Hub hedges.  Antero has 13 different counterparties to its hedge contracts, all of which are lenders in the Company's bank credit facility.

Additionally, Antero has hedged 140 Bcf of basis on future production using fixed price TCO basis swaps covering the period from July 1, 2015, through December 31, 2016, at an average basis differential of $(0.42) per MMBtu.

Conference Call

A conference call is scheduled on Thursday, July 30, 2015 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, August 7, 2015 at 9:00 am MT at 877-870-5176 (U.S.) or 858-384-5517 (International) using the passcode 10067252.

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 August 7, 2015 at 9:00 am MT.

Presentation

An updated presentation will be posted to the Company's website before the July 30, 2015 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.  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
June 30,


Six months ended

June 30,



2014


2015


2014


2015










Total operating revenue


$

311,338


$

376,714


$

479,545


$

1,606,401

Commodity derivative (gains) losses


123,766


2,227


372,695


(757,327)

Gains (losses) on  settled derivatives


953


195,880


(118)


380,720

Adjusted net revenue


$

436,057


$

574,821


$

852,122


$

1,229,794

Adjusted net income 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 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 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 attributable to common stockholders:


Three months ended


Six months ended

June 30,


June 30,


2014


2015


2014


2015











Net income (loss) from continuing operations attributable to common stockholders

$

(44,495)


$

(145,487)


$

(139,254)


$

248,944

Non-cash commodity derivative (gains) losses on unsettled derivatives, net of tax


77,345



123,238



231,056



(234,279)

Impairment of unproved properties, net of tax


1,213



16,385



2,079



21,721

     Equity-based compensation, net of tax


29,286



21,830



58,252



44,676

Loss on early extinguishment of debt, net of tax


12,642





12,642



     Contract termination and rig stacking, net of tax




1,205





6,782

Adjusted net income attributable to common stockholders

 

$

75,991


 

$

17,285


 

$

164,775


 

$

87,958

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
June 30,


Six months ended

June 30,



2014


2015


2014


2015










Net cash provided by operating activities


$

223,722


$

239,201


$

498,029


$

590,595

Net change in working capital


(3,886)


(30,894)


(40,532)


(89,831)

Cash flow from operations before changes in working capital


$

219,836


$

208,307


$

457,497


$

500,764

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





As of
June 30,





2015







Bank credit facility




$

1,118,000

6.00% senior notes due 2020





525,000

5.375% senior notes due 2021





1,000,000

5.125% senior notes due 2022





1,100,000

5.625% senior notes due 2023





750,000

Net unamortized premium





7,038

Consolidated total debt





4,500,038

Cash and cash equivalents





143,286

Consolidated net debt




$

4,356,752

Adjusted EBITDAX is a non-GAAP financial measure that Antero defines as net income (loss) including noncontrolling interest 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 (loss), 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 bank 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 (loss), 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 (loss) including noncontrolling interest to 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


Six months ended

June 30,


June 30,


2014


2015


2014


2015











Net income (loss) from continuing operations including noncontrolling interest

 

$

(44,495)


 

$

(139,483)


 

$

(139,254)


 

$

259,688

Commodity derivative fair value (gains) losses


123,766



2,227



372,695



(757,327)

Gains (losses) on settled derivative instruments


953



195,880



(118)



380,720

Interest expense


37,260



59,823



68,602



113,008

Loss on early extinguishment of debt


20,386





20,386



Income tax expense (benefit)


(18,454)



(84,089)



(59,116)



163,249

Depreciation, depletion, amortization, and accretion


105,463



177,454



196,971



360,154

Impairment of unproved properties


1,956



26,339



3,353



34,916

Exploration expense


6,703



628



13,700



1,999

Equity-based compensation expense


32,474



27,582



61,611



55,365

State franchise taxes


450



(106)



1,288



129

Contract termination and rig stacking




1,937





10,902

Total Adjusted EBITDAX


266,462



268,192



540,118



622,803

Interest expense


(37,260)



(59,823)



(68,602)



(113,008)

Exploration expense


(6,703)



(628)



(13,700)



(1,999)

Changes in current assets and liabilities


3,886



30,894



40,532



89,831

State franchise taxes


(450)



106



(1,288)



(129)

Other non-cash items


(2,213)



460



969



(6,903)

Net cash provided by operating activities

$

223,722


$

239,201


$

498,029


$

590,595

 


Three months ended


Six months ended


June 30,


June 30,

Adjusted EBITDAX margin ($ per Mcfe):


2014



2015


2014


2015

Realized price before cash receipts for settled hedges

$

5.30


$

2.40


$

5.54


$

2.72

Gathering, compression, and water distribution revenues


0.04



0.04



0.05



0.03

Lease operating expense


(0.06)



(0.05)



(0.07)



(0.05)

Gathering, compression, processing and transportation costs


(1.28)



(1.23)



(1.23)



(1.23)

Marketing, net


(0.15)



(0.22)



(0.14)



(0.17)

Production taxes


(0.26)



(0.17)



(0.28)



(0.17)

General and administrative(1)


(0.31)



(0.23)



(0.31)



(0.23)

Gains on settled hedges


0.01



1.45





1.42

Adjusted EBITDAX margin ($ per Mcfe):

$

3.29


$

1.99


$

3.56


$

2.32



             (1) Excludes franchise taxes and 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.

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, inflation, lack of availability of drilling and production equipment and services, environmental risks, drilling and other operating risks, regulatory changes, the uncertainty inherent in estimating natural gas 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, 2014.

ANTERO RESOURCES CORPORATION

Condensed Consolidated Balance Sheets

December 31, 2014 and June 30, 2015

(Unaudited)

(In thousands, except share amounts)









2014



2015

Assets






Current assets:






Cash and cash equivalents

$

245,979



143,286

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


116,203



79,190

Accrued revenue


191,558



125,467

Derivative instruments


692,554



664,417

Other current assets


5,866



4,819

Total current assets


1,252,160



1,017,179

Property and equipment:






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






Unproved properties


2,060,936



2,080,491

Proved properties


6,515,221



7,462,080

Fresh water distribution systems


421,012



441,692

Gathering systems and facilities


1,197,239



1,341,661

Other property and equipment


37,687



42,842



10,232,095



11,368,766

Less accumulated depletion, depreciation, and amortization


(879,643)



(1,238,989)

Property and equipment, net


9,352,452



10,129,777

Derivative instruments


899,997



1,305,392

Other assets


68,886



80,133

Total assets

$

11,573,495



12,532,481







Liabilities and Equity






Current liabilities:






Accounts payable

$

531,564



326,638

Accrued liabilities


168,614



183,319

Revenue distributions payable


182,352



190,881

Deferred income tax liability


260,373



251,097

Other current liabilities


12,202



14,248

Total current liabilities


1,155,105



966,183

Long-term liabilities:






Long-term debt


4,362,550



4,500,038

Deferred income tax liability


534,423



706,948

Derivative instruments




651

Other liabilities


47,587



49,215

Total liabilities


6,099,665



6,223,035

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 277,025,288 shares, respectively


2,621



2,770

Additional paid-in capital


3,513,725



4,099,718

Accumulated earnings


867,447



1,116,505

Total stockholders' equity


4,383,793



5,218,993

Noncontrolling interest in consolidated subsidiary


1,090,037



1,090,453

Total equity


5,473,830



6,309,446

Total liabilities and equity

$

11,573,495



12,532,481

 

ANTERO RESOURCES CORPORATION

Condensed Consolidated Statements of Operations and Comprehensive Income (Loss)

Three Months Ended June 30, 2014 and 2015

(Unaudited)

(In thousands, except share and per share amounts)










2014


2015

Revenue:







Natural gas sales


$

314,151



242,065

Natural gas liquids sales



79,768



59,525

Oil sales



35,633



23,032

Gathering, compression, and water distribution



3,565



4,490

Marketing



1,987



49,829

Commodity derivative fair value losses



(123,766)



(2,227)

Total revenue



311,338



376,714

Operating expenses:







Lease operating



5,021



6,673

Gathering, compression, processing, and transportation



103,837



166,669

Production and ad valorem taxes



21,358



22,519

Marketing



13,946



79,053

Exploration



6,703



628

Impairment of unproved properties



1,956



26,339

Depletion, depreciation, and amortization



105,154



177,046

Accretion of asset retirement obligations



309



408

General and administrative (including equity-based compensation expense of $32,474 and $27,582 in 2014 and 2015, respectively)



58,357



59,191

Contract termination and rig stacking





1,937

Total operating expenses



316,641



540,463

Operating loss



(5,303)



(163,749)

Other expenses:







Interest



(37,260)



(59,823)

Loss on early extinguishment of debt



(20,386)



Total other expenses



(57,646)



(59,823)

Loss from continuing operations before income taxes and discontinued operations



(62,949)



(223,572)

Provision for income tax benefit



18,454



84,089

Loss from continuing operations



(44,495)



(139,483)

Discontinued operations:







Income from sale of discontinued operations, net of income tax expense of $1,354



2,210



Loss and comprehensive loss including noncontrolling interest



(42,285)



(139,483)

Net income and comprehensive income attributable to noncontrolling interest





5,890

Loss and comprehensive loss attributable to Antero Resources Corporation


$

(42,285)


$

(145,373)








Earnings (loss) per common share







Continuing operations


$

(0.17)


$

(0.52)

Discontinued operations



0.01



Total


$

(0.16)


$

(0.52)








Earnings (loss) per common share—assuming dilution







Continuing operations


$

(0.17)


$

(0.52)

Discontinued operations



0.01



Total


$

(0.16)


$

(0.52)








Weighted average number of shares outstanding:







Basic



262,049,659



277,002,786

Diluted



262,049,659



277,002,786

 

ANTERO RESOURCES CORPORATION

Condensed Consolidated Statements of Operations and Comprehensive Income (Loss)

Six Months Ended June 30, 2014 and 2015

(Unaudited)

(In thousands, except share and per share amounts)








2014


2015

Revenue:






Natural gas sales

$

626,487



557,007

Natural gas liquids sales


153,696



138,311

Oil sales


59,755



35,489

Gathering, compression, and water distribution


7,089



10,658

Marketing


5,213



107,609

Commodity derivative fair value gains (losses)


(372,695)



757,327

Total revenue


479,545



1,606,401

Operating expenses:






Lease operating


9,890



14,775

Gathering, compression, processing, and transportation


187,347



330,331

Production and ad valorem taxes


42,397



46,737

Marketing


25,927



152,402

Exploration


13,700



1,999

Impairment of unproved properties


3,353



34,916

Depletion, depreciation, and amortization


196,360



359,346

Accretion of asset retirement obligations


611



808

General and administrative (including equity-based compensation expense of $61,611 and $55,365 in 2014 and 2015, respectively)


109,342



118,240

Contract termination and rig stacking




10,902

Total operating expenses


588,927



1,070,456

Operating income (loss)


(109,382)



535,945

Other expenses:






Interest


(68,602)



(113,008)

Loss on early extinguishment of debt


(20,386)



Total other expenses


(88,988)



(113,008)

Income (loss) from continuing operations before income taxes and discontinued operations


(198,370)



422,937

Provision for income tax (expense) benefit


59,116



(163,249)

Income (loss) from continuing operations


(139,254)



259,688

Discontinued operations:






Income from sale of discontinued operations, net of income tax expense of $1,354


2,210



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


(137,044)



259,688

Net income and comprehensive income attributable to noncontrolling interest




10,630

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

$

(137,044)



249,058







Earnings (loss) per common share:






Continuing operations

$

(0.53)



0.92

Discontinued operations


0.01



Total

$

(0.52)



0.92







Earnings (loss) per common share—assuming dilution






Continuing operations

$

(0.53)



0.92

Discontinued operations


0.01



Total

$

(0.52)



0.92







Weighted average number of shares outstanding:






Basic


262,049,659



271,181,132

Diluted


262,049,659



271,192,089

 

ANTERO RESOURCES CORPORATION

Condensed Consolidated Statements of Cash Flows

Six Months Ended June 30, 2014 and 2015

(Unaudited)

(In thousands)








2014


2015

Cash flows from operating activities:






Net income (loss) including noncontrolling interest

$

(137,044)



259,688

Adjustment to reconcile net income (loss) to net cash provided by operating activities:






Depletion, depreciation, amortization, and accretion


196,971



360,154

Impairment of unproved properties


3,353



34,916

Derivative fair value (gains) losses


372,695



(757,327)

Gains (losses) on settled derivatives


(118)



380,720

Deferred income tax expense (benefit)


(59,116)



163,249

Equity-based compensation expense


61,611



55,365

Loss on early extinguishment of debt


20,386



Gain on sale of discontinued operations


(3,564)



Deferred income tax expense—discontinued operations


1,354



Other


969



3,999

Changes in current assets and liabilities:






Accounts receivable


(15,922)



(2,987)

Accrued revenue


(42,728)



66,091

Other current assets


(942)



1,047

Accounts payable


3,477



4,579

Accrued liabilities


42,475



10,904

Revenue distributions payable


57,503



8,529

Other current liabilities


(3,331)



1,668

Net cash provided by operating activities


498,029



590,595

Cash flows used in investing activities:






Additions to unproved properties


(239,152)



(131,683)

Drilling and completion costs


(1,103,017)



(1,009,421)

Additions to fresh water distribution systems


(99,927)



(34,076)

Additions to gathering systems and facilities


(261,667)



(200,045)

Additions to other property and equipment


(11,041)



(2,794)

Change in other assets


(39,067)



(759)

Proceeds from asset sales




40,000

Net cash used in investing activities


(1,753,871)



(1,338,778)

Cash flows from financing activities:






Issuance of common stock




537,693

Issuance of senior notes


600,000



750,000

Repayment of senior notes


(260,000)



Borrowings (repayments) on bank credit facility, net


952,000



(612,000)

Make-whole premium on debt extinguished


(17,383)



Payments of deferred financing costs


(16,989)



(15,254)

Distributions to noncontrolling interest in consolidated subsidiary




(12,617)

Other




(2,332)

Net cash provided by financing activities


1,257,628



645,490

Net increase (decrease) in cash and cash equivalents


1,786



(102,693)

Cash and cash equivalents, beginning of period


17,487



245,979

Cash and cash equivalents, end of period

$

19,273



143,286







Supplemental disclosure of cash flow information:






Cash paid during the period for interest

$

60,031



103,133

Supplemental disclosure of noncash investing activities:






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

$

126,657



(210,217)

 

The following tables set forth selected operating data for the three months ended June 30, 2014 compared to the three months ended June 30, 2015:















Three Months Ended June 30,


Amount of
Increase


Percent

(in thousands)


2014


2015


(Decrease)


Change

Operating revenues:












Natural gas sales


$

314,151


$

242,065


$

(72,086)


(23)%

NGLs sales



79,768



59,525



(20,243)


(25)%

Oil sales



35,633



23,032



(12,601)


(35)%

Gathering, compression, and water distribution



3,565



4,490



925


26%

Marketing



1,987



49,829



47,842


2,408%

Commodity derivative fair value losses



(123,766)



(2,227)



121,539


(98)%

Total operating revenues



311,338



376,714



65,376


21%

Operating expenses:












Lease operating



5,021



6,673



1,652


33%

Gathering, compression, processing, and transportation



103,837



166,669



62,832


61%

Production and ad valorem taxes



21,358



22,519



1,161


5%

Marketing



13,946



79,053



65,107


467%

Exploration



6,703



628



(6,075)


(91)%

Impairment of unproved properties



1,956



26,339



24,383


1,247%

Depletion, depreciation, and amortization



105,154



177,046



71,892


68%

Accretion of asset retirement obligations



309



408



99


32%

General and administrative (before equity-based compensation)



25,883



31,609



5,726


22%

Equity-based compensation



32,474



27,582



(4,892)


(15)%

Contract termination and rig stacking





1,937



1,937


*

   Total operating expenses



316,641



540,463



223,822


71%

Operating loss



(5,303)



(163,749)



(158,446)


*













Other Expenses:












Interest expense



(37,260)



(59,823)



(22,563)


61%

Loss on early extinguishment of debt



(20,386)





20,386


*

Total other expenses



(57,646)



(59,823)



(2,177)


4%

Loss before income taxes



(62,949)



(223,572)



(160,623)


255%

Income tax benefit



18,454



84,089



65,635


356%

Loss from continuing operations



(44,495)



(139,483)



(94,988)


213%

Income from discontinued operations



2,210





(2,210)


*

Net loss and comprehensive loss including noncontrolling interest



(42,285)



(139,483)



(97,198)


230%

Net income and comprehensive income attributable to noncontrolling interest





5,890



5,890


*

Net loss


$

(42,285)


$

(145,373)


$

(103,088)


244%













Adjusted EBITDAX


$

266,462


$

268,192


$

1,730


1%













Production data:












Natural gas (Bcf)



70



110



40


57%

NGLs (MBbl)



1,451



3,655



2,204


152%

Oil (MBbl)



391



523



132


34%

Combined (Bcfe)



81



135



54


67%

Daily combined production (MMcfe/d)



891



1,484



593


67%

Average prices before effects of derivative settlements:












Natural gas (per Mcf)


$

4.49


$

2.20


$

(2.29)


(51)%

NGLs (per Bbl)


$

54.98


$

16.29


$

(38.69)


(70)%

Oil (per Bbl)


$

91.20


$

44.06


$

(47.14)


(52)%

Combined (per Mcfe)


$

5.30


$

2.40


$

(2.90)


(55)%

Average realized prices after effects of derivative settlements:












Natural gas (per Mcf)


$

4.52


$

3.86


$

(0.66)


(15)%

NGLs (per Bbl)


$

54.98


$

19.51


$

(35.47)


(65)%

Oil (per Bbl)


$

87.31


$

47.33


$

(39.98)


(46)%

Combined (per Mcfe)


$

5.31


$

3.85


$

(1.46)


(27)%

Average Costs (per Mcfe):












Lease operating


$

0.06


$

0.05


$

(0.01)


(17)%

Gathering, compression, processing, and transportation


$

1.28


$

1.23


$

(0.05)


(4)%

Production and ad valorem taxes


$

0.26


$

0.17


$

(0.09)


(35)%

Marketing, net


$

0.15


$

0.22


$

0.07


47%

Depletion, depreciation, amortization, and accretion


$

1.30


$

1.31


$

0.01


1%

General and administrative (before equity-based compensation)


$

0.32


$

0.23


$

(0.09)


(28)%

__________________________________

*      Not meaningful or applicable

 

The following tables set forth selected operating data for the six months ended June 30, 2014 compared to the six months ended June 30, 2015:















Six Months Ended June 30,


Amount of
Increase


Percent

(in thousands)


2014


2015


(Decrease)


Change

Operating revenues:












Natural gas sales


$

626,487


$

557,007


$

(69,480)


(11)%

NGLs sales



153,696



138,311



(15,385)


(10)%

Oil sales



59,755



35,489



(24,266)


(41)%

Gathering, compression, and water distribution



7,089



10,658



3,569


50%

Marketing



5,213



107,609



102,396


1,964%

Commodity derivative fair value gains (losses)



(372,695)



757,327



1,130,022


*

Total operating revenues



479,545



1,606,401



1,126,856


235%

Operating expenses:












Lease operating



9,890



14,775



4,885


49%

Gathering, compression, processing, and transportation



187,347



330,331



142,984


76%

Production and ad valorem taxes



42,397



46,737



4,340


10%

Marketing



25,927



152,402



126,475


488%

Exploration



13,700



1,999



(11,701)


(85)%

Impairment of unproved properties



3,353



34,916



31,563


941%

Depletion, depreciation, and amortization



196,360



359,346



162,986


83%

Accretion of asset retirement obligations



611



808



197


32%

General and administrative (before equity-based compensation)



47,731



62,875



15,144


32%

Equity-based compensation



61,611



55,365



(6,246)


(10)%

Contract termination and rig stacking





10,902



10,902


*

   Total operating expenses



588,927



1,070,456



481,529


82%

         Operating income (loss)



(109,382)



535,945



645,327


*













Other Expenses:












Interest expense



(68,602)



(113,008)



(44,406)


65%

Loss on early extinguishment of debt



(20,386)





20,386


*

Total other expenses



(88,988)



(113,008)



(24,020)


27%

Income (loss) before income taxes



(198,370)



422,937



621,307


*

Income tax (expense) benefit



59,116



(163,249)



(222,365)


*

Income (loss) from continuing operations



(139,254)



259,688



398,942


*

Income from discontinued operations



2,210





(2,210)


*

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



(137,044)



259,688



396,732


*

Net income and comprehensive income attributable to noncontrolling interest





10,630



10,630


*

Net income (loss)


$

(137,044)


$

249,058


$

386,102


*













Adjusted EBITDAX


$

540,118


$

622,803


$

82,685


15%













Production data:












Natural gas (Bcf)



132



222



90


68%

NGLs (MBbl)



2,649



6,895



4,246


160%

Oil (MBbl)



662



889



227


34%

Combined (Bcfe)



152



269



117


77%

Daily combined production (MMcfe/d)



838



1,485



647


77%

Average prices before effects of derivative settlements(2):












Natural gas (per Mcf)


$

4.75


$

2.51


$

(2.24)


(47)%

NGLs (per Bbl)


$

58.01


$

20.06


$

(37.95)


(65)%

Oil (per Bbl)


$

90.24


$

39.93


$

(50.31)


(56)%

Combined (per Mcfe)


$

5.54


$

2.72


$

(2.82)


(51)%

Average realized prices after effects of derivative settlements(2):












Natural gas (per Mcf)


$

4.76


$

4.12


$

(0.64)


(13)%

NGLs (per Bbl)


$

58.01


$

22.66


$

(35.35)


(61)%

Oil (per Bbl)


$

88.73


$

46.40


$

(42.33)


(48)%

Combined (per Mcfe)


$

5.53


$

4.14


$

(1.39)


(25)%

Average Costs (per Mcfe):












Lease operating


$

0.07


$

0.05


$

(0.02)


(29)%

Gathering, compression, processing, and transportation


$

1.23


$

1.23


$


—%

Production and ad valorem taxes


$

0.28


$

0.17


$

(0.11)


(39)%

Marketing, net


$

0.14


$

0.17


$

0.03


21%

Depletion, depreciation, amortization, and accretion


$

1.30


$

1.34


$

0.04


3%

General and administrative (before equity-based compensation)


$

0.31


$

0.23


$

(0.08)


(26)%

______________________________________

*      Not meaningful or applicable

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To view the original version on PR Newswire, visit:http://www.prnewswire.com/news-releases/antero-resources-reports-second-quarter-2015-financial-results-300120763.html

SOURCE Antero Resources Corporation

Michael Kennedy, VP Finance, at (303) 357-6782 or mkennedy@anteroresources.com