Exhibit 99.1

 

 

Antero Resources Reports Third Quarter 2015 Financial Results

 

Denver, Colorado, October 28, 2015—Antero Resources Corporation (NYSE: AR) (“Antero” or the “Company”) today released its third quarter 2015 financial results.  The relevant financial statements are included in Antero’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2015, which has been filed with the Securities and Exchange Commission (“SEC”).

 

Highlights for the Third Quarter of 2015:

 

·                  Net income of $534 million, or $1.93 per share, a 162% increase compared to the prior year quarter

·                  Adjusted net income of $14 million, or $0.05 per share, an 80% decrease compared to the prior year quarter

·                  Adjusted EBITDAX of $291 million, flat compared to the prior year quarter

·                  On a per unit basis, cash production expense declined 18%, or $0.28 per Mcfe, and G&A expense declined 10%, or $0.03 per Mcfe, compared to the prior year quarter

·                  Net daily gas equivalent production averaged 1,506 MMcfe/d, a 39% increase compared to the prior year quarter and a 1% increase compared to the prior quarter

·                  Net daily liquids production, included in the above, averaged 52,250 Bbl/d, a 109% increase compared to the prior year quarter and a 14% increase compared to the prior quarter

·                  Realized natural gas equivalent price including NGLs, oil and settled derivatives averaged $3.83 per Mcfe

·                  Increased credit facility borrowing base by 12.5% to $4.5 billion from $4.0 billion

·                  Closed drop down of water business and received $794 million of cash proceeds and approximately 11.0 million common units of Antero Midstream Partners

 

Recent Developments

 

Antero Resources Borrowing Base Increase

 

On October 26, 2015, Antero’s borrowing base under its upstream credit facility was increased by 12.5% to $4.5 billion, a $500 million increase over Antero’s previous borrowing base of $4.0 billion.  Lender commitments under the facility remain at $4.0 billion. As of September 30, 2015, the Company had $500 million drawn under the upstream credit facility and $535 million in letters of credit outstanding, resulting in $3.0 billion in Antero standalone liquidity and $3.5 billion of unused borrowing base capacity, on a pro forma basis giving effect to the borrowing base increase.

 

Closing of the Water Business Drop Down

 

As previously announced on September 24th, 2015, Antero successfully completed the water business drop down transaction to Antero Midstream Partners, LP (“Antero Midstream”) for $1.05 billion.  In connection with the transaction, Antero received cash consideration of $794 million and 10,988,421 Antero Midstream common units, plus a total of $250 million of potential earn-out payments due at the end of 2019 and 2020 contingent on meeting specific average fresh water delivery volume thresholds.  Transaction proceeds were used by Antero to repay credit facility borrowings.

 

Third Quarter 2015 Financial Results

 

As of September 30, 2015, Antero owned a 66.5% limited partner interest in Antero Midstream.  Antero Midstream’s results are consolidated with Antero’s results.

 

1



 

For the three months ended September 30, 2015, the Company reported net income attributable to common stockholders of $534 million, or $1.93 per basic and diluted share, compared to net income of $204 million, or $0.78 per basic and diluted share in the third quarter of 2014.  GAAP net income for the third quarter of 2015 included the following items:

 

·                  Non-cash gains on unsettled derivatives of $873 million ($543 million net of tax);

·                  Non-cash equity-based stock compensation expense of $24 million ($18 million net of tax); and

·                  Impairment of unproved properties of $9 million ($5 million net of tax)

 

Without the effect of these non-cash items, the Company’s results for the third quarter of 2015 were as follows:

 

·                  Adjusted net income attributable to common stockholders of $14 million, or $0.05 per basic and diluted share, an 80% decrease compared to the third quarter of 2014;

·                  Adjusted EBITDAX of $291 million, in line with the third quarter of 2014; and

·                  Cash flow from operations before changes in working capital of $237 million, a 3% decrease compared to the third quarter of 2014

 

Commenting on third quarter 2015 EBITDAX and Antero’s business model, Paul Rady, Chairman of the Board and CEO, said, “Despite the challenging commodity price environment during the quarter, our results truly show the sustainability of Antero’s business model. Antero’s better than expected production, combined with the Company’s firm transportation portfolio and industry leading hedge position, again allowed Antero to achieve Appalachian leading EBITDAX and cash flow margins during the quarter.  Despite more than a 30% decrease in natural gas prices and 50% decrease in crude oil prices over the last year, Antero generated the same level of EBITDAX as compared to the prior year quarter.”

 

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 third quarter of 2015 averaged 1,506 MMcfe/d, a 39% increase as compared to the third quarter of 2014 and a 1% increase from the second quarter of 2015.  Net daily production was comprised of 1,192 MMcf/d of natural gas (79%), 45,072 Bbl/d of natural gas liquids (“NGLs”) (18%) and 7,178 Bbl/d of crude oil (3%).  Third quarter 2015 net liquids (NGLs and oil) daily production of 52,250 Bbl/d increased 109% as compared to the third quarter of 2014 and 14% from the second quarter of 2015.

 

Average natural gas price before settled derivatives decreased 36% from the prior year quarter to $2.32 per Mcf, a $0.45 per Mcf negative differential to Nymex, as Nymex natural gas prices decreased 32% from the prior year quarter.  Approximately 68% of Antero’s third quarter 2015 natural gas production was realized at favorable price indices, including Columbia Gas Transmission (TCO), Chicago and Nymex.  The remaining 32% of natural gas production was priced at various less favorable index pricing points, primarily Dominion South and Tetco M2.  Antero’s average realized natural gas price after settled derivatives for the third quarter of 2015 was $3.99 per Mcf, a $1.22 positive differential to the Nymex average price for the period, and a 7% decrease compared to the prior year quarter.  During the quarter, Antero realized a cash settled natural gas derivative gain of $183 million, or $1.67 per Mcf.

 

Antero’s average realized C3+ NGL price before settled derivatives for the third quarter of 2015 was $12.08 per barrel, or approximately 26% of the WTI oil price average for the period.  This represents a 74% decrease for NGL prices compared to the prior year quarter as WTI oil prices decreased 53% from the prior year quarter.  NGL differentials in the Appalachian Basin have widened significantly in the region due to the need to utilize rail transport to move the product to markets.  Logistics and regional shipping costs are expected to improve once the Mariner East II pipeline goes in service, which is anticipated to occur by the end of 2016.  The Company’s average realized NGL price after settled derivatives was $16.47 per barrel, or 35% of the WTI oil price average for the period, which represents a 65% decrease from the prior year quarter.  For the third quarter of 2015, Antero realized a cash settled NGL derivative gain of $18 million, or $4.39 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 settled derivatives for the third quarter of 2015 was $30.49 per barrel, a $15.92 per barrel negative differential to the average WTI oil price for the period, and a 64% decrease compared to the prior year quarter.  The third quarter 2015 negative differential for condensate was a result of an increase in production of high API gravity condensate in the Utica.  The Company’s average realized oil price after settled derivatives decreased 54% from the prior year quarter to $38.18 per barrel, an $8.24 per barrel negative differential to the WTI oil price.  For the third quarter of 2015, Antero realized a cash settled oil derivative gain of $5 million, or $7.69 per barrel.  Including $206 million of total cash settled derivative gains for all products, the average all-in natural gas equivalent price, including NGLs, oil and derivative settlements, was $3.83 per Mcfe for the third quarter of 2015.

 

2



 

Total revenues for the third quarter of 2015 were $1.4 billion as compared to $762 million for the third quarter of 2014.  Revenue for the third quarter of 2015 included an $873 million non-cash gain on unsettled derivatives while the third quarter of 2014 included a $252 million non-cash gain on unsettled derivatives.  Liquids production contributed 22% of combined natural gas, NGLs and oil revenue before derivatives in the third quarter of 2015.  Adjusted net revenue increased 12% to $570 million compared to the third quarter of 2014 (including cash settled derivative gains and losses but excluding non-cash unsettled derivative gains and losses).  For a reconciliation of adjusted net revenue to operating revenue, the most comparable GAAP measure, please read “Non-GAAP Financial Measures.”

 

Net marketing expense was $26 million, or $0.19 per Mcfe, for the third quarter of 2015.  Marketing revenue for the third quarter of 2015 was $36 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 third quarter of 2015 was $62 million.  The largest components of marketing expense were the fixed transportation costs related to excess natural gas takeaway capacity, the cost of purchasing third-party gas and the fixed transportation costs associated with the Company’s underutilized ATEX ethane pipeline capacity.  The decrease in net marketing expense versus the prior quarter was primarily the result of increased production volumes in the Utica Shale flowing on the Company’s Chicago firm transportation portfolio, which includes capacity on Rex, MGT, NGPL and ANR North.

 

Per unit cash production expense (lease operating, gathering, compression, processing and transportation, and production tax) for the third quarter of 2015 was $1.32 per Mcfe which is an 18% 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, a reduction in the estimated liability for property taxes accrued for in prior periods, as well as reduced fuel costs due to lower commodity prices.  Per unit general and administrative expense for the third quarter of 2015, excluding non-cash equity-based compensation expense, was $0.26 per Mcfe, a 10% decrease from the third 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 9% from the prior year quarter to $1.37 per Mcfe due to proved developed reserves increasing at a slower rate than the corresponding cost additions for wells completed during the period.

 

Adjusted EBITDAX of $291 million for the third quarter of 2015 was in line with the prior year quarter.  Adjusted EBITDAX margin for the quarter was $2.10 per Mcfe, representing a 28% decrease from the prior year quarter due to lower commodity prices and lower hedged prices.  For the third quarter of 2015, cash flow from operations before changes in working capital decreased 3% from the prior year to $237 million.

 

For a description of Adjusted EBITDAX and Adjusted 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.”

 

Balance Sheet and Liquidity

 

As of September 30, 2015 the Company’s consolidated net debt was $4.4 billion, of which $500 million were borrowings outstanding under the Company’s senior secured revolving credit facility, and $525 million were borrowings under Antero Midstream’s $1.5 billion senior secured credit facility.  Pro forma for the increased $4.5 billion borrowing base and including the $535 million in letters of credit outstanding, the Company had approximately $4.0 billion in available liquidity and $4.5 billion in unused borrowing base capacity on a consolidated basis as of September 30, 2015.  For a reconciliation of consolidated net debt to consolidated total debt, the most comparable GAAP measure, please read “Non-GAAP Financial Measures.”

 

Third Quarter 2015 Capital Spending

 

Antero’s drilling and completion costs for the three months ended September 30, 2015 were $341 million.  In addition, the Company invested $39 million for land, $20 million for fresh water distribution projects in the Marcellus and Utica Shale plays and $2 million in other capital projects.

 

Antero Midstream Financial Results

 

The following reflects results for Antero Midstream for the three and nine months ended September 30, 2015, and predecessor results for the three and nine months ended September 30, 2014. In addition, Antero Midstream’s recent acquisition of Antero’s integrated water business was accounted for as a transfer of entities under common control.  As a result, the Partnership recast its condensed combined consolidated financial statements to retrospectively reflect the integrated water business as if the assets and liabilities were owned for all past periods presented.  Beginning in the third quarter of 2015, and as a result of the acquisition, Antero Midstream will report its results through two business segments, Gathering and Compression and Water Handling.  To facilitate comparison and

 

3



 

discussion for third quarter 2015, operating results below are only for the Gathering and Compression segment operations.  For operating results associated with the Water Handling segment and its contribution to the recast condensed combined consolidated financial statements contained in Antero Midstream’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2015, please read “Non-GAAP Financial Measures.”

 

Antero Midstream’s low pressure gathering volumes for the third quarter of 2015 averaged 1,038 MMcf/d, a 95% increase from the third quarter of 2014 and an 8% increase from the second quarter of 2015.  High pressure gathering volumes for the third quarter of 2015 averaged 1,216 MMcf/d, a 129% increase from the third quarter of 2014 and a 2% increase from the second quarter of 2015.  Compression volumes for the third quarter of 2015 averaged 435 MMcf/d, a 275% increase from the third quarter of 2014 and a 4% decrease from the second quarter of 2015.  Condensate gathering volumes averaged 2,856 Bbl/d during the quarter, a 145% increase compared to the prior year quarter.  Volumetric growth was driven by production growth from Antero Resources.

 

Antero Midstream’s revenue for the third quarter of 2015 was $59.3 million as compared to $26.3 million for the prior year quarter, driven primarily by increased throughput volumes across Antero Midstream’s systems.  Direct operating expenses were a $3.2 million credit, driven by an $8.4 million reduction in the estimated liability for property taxes accrued for in prior periods and a slight decrease in other operating expenses during the quarter. Allocated general and administrative expenses totaled $11.3 million, including $4.2 million of non-cash equity-based compensation.  Total cash and non-cash operating expenses were $23.2 million including $15.1 million of depreciation.

 

Capital expenditures associated with gathering and compression totaled $83 million, including $55 million invested in the Marcellus and $28 million invested in the Utica.  Gathering and compression capital expenditures were primarily related to the build-out of midstream infrastructure to support Antero Resources’ development program.  Additionally, Antero Midstream invested $29 million in water handling assets during the quarter.

 

On October 13, 2015, the Board of Directors of Antero Resources Midstream Management LLC, the general partner of Antero Midstream, declared a cash distribution of $0.205 per unit ($0.82 per unit annualized) for the third quarter of 2015.  The distribution represents an 8% increase quarter over quarter and Antero Midstream’s third consecutive quarterly distribution increase since its initial public offering in November 2014.  The distribution will be payable on November 30, 2015 to unitholders of record as of November 11, 2015.

 

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

 

Conference Call

 

A conference call is scheduled on Thursday, October 29, 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, November 6, 2015 at 9:00 am MT at 877-870-5176 (U.S.) or 858-384-5517 (International) using the passcode 10072161.

 

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 November 6, 2015 at 9:00 am MT.

 

Presentation

 

An updated presentation will be posted to the Company’s website before the October 29, 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 derivative 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:

 

4



 

 

 

Three months ended
September 30,

 

Nine months ended
September 30,

 

 

 

2014

 

2015

 

2014

 

2015

 

 

 

 

 

 

 

 

 

 

 

Total operating revenue

 

$

762,490

 

$

1,443,335

 

$

1,242,035

 

$

3,049,736

 

Commodity derivative (gains) losses

 

(308,975

)

(1,079,071

)

63,720

 

(1,836,398

)

Gains on settled derivatives

 

57,451

 

205,919

 

57,333

 

586,639

 

Adjusted net revenue

 

$

510,966

 

$

570,183

 

$

1,363,088

 

$

1,799,977

 

 

Adjusted net income attributable to common stockholders as set forth in this release represents net income 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 from continuing operations attributable to common stockholders as an indicator of financial performance.  The following table reconciles net income from continuing operations attributable to common stockholders to adjusted net income attributable to common stockholders:

 

 

 

Three months ended

 

Nine months ended

 

 

 

September 30,

 

September 30,

 

 

 

2014

 

2015

 

2014

 

2015

 

 

 

 

 

 

 

 

 

 

 

Net income from continuing operations attributable to common stockholders

 

$

203,909

 

$

533,842

 

$

64,655

 

$

782,900

 

Non-cash commodity derivative (gains) losses on unsettled derivatives

 

(251,524

)

(873,152

)

121,053

 

(1,249,759

)

Impairment of unproved properties

 

4,542

 

8,754

 

7,895

 

43,670

 

Equity-based compensation

 

24,285

 

23,915

 

85,896

 

79,280

 

Loss on early extinguishment of debt

 

 

 

20,386

 

 

Contract termination and rig stacking

 

 

 

 

10,902

 

Income tax effect of reconciling items

 

90,474

 

320,711

 

(63,348

)

435,033

 

Adjusted net income attributable to common stockholders

 

$

71,686

 

$

14,070

 

$

236,537

 

$

102,026

 

 

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 for 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.

 

5



 

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
September 30,

 

Nine months ended
September 30,

 

 

 

2014

 

2015

 

2014

 

2015

 

 

 

 

 

 

 

 

 

 

 

Net cash provided by operating activities

 

$

300,717

 

$

246,005

 

$

798,746

 

$

836,600

 

Net change in working capital

 

(55,621

)

(9,078

)

(96,153

)

(98,909

)

Cash flow from operations before changes in working capital

 

$

245,096

 

$

236,927

 

$

702,593

 

$

737,691

 

 

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

 

 

 

As of
September 30,

 

 

 

2015

 

 

 

 

 

Antero:

 

 

 

Bank credit facility

 

$

500,000

 

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

 

6,777

 

Antero Midstream:

 

 

 

Bank credit facility

 

525,000

 

Consolidated total debt

 

4,406,777

 

Cash and cash equivalents

 

27,410

 

Consolidated net debt

 

$

4,379,367

 

 

Adjusted EBITDAX is a non-GAAP financial measure that Antero defines as net income 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, 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

 

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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 derivatives to Adjusted EBITDAX margin:

 

 

 

Three months ended
September 30,

 

Nine months ended
September 30,

 

(in thousands)

 

2014

 

2015

 

2014

 

2015

 

 

 

 

 

 

 

 

 

 

 

Net income from continuing operations including noncontrolling interest

 

$

203,909

 

544,734

 

64,655

 

804,422

 

Commodity derivative fair value (gains) losses

 

(308,975

)

(1,079,071

)

63,720

 

(1,836,398

)

Gains on settled derivative instruments

 

57,451

 

205,919

 

57,333

 

586,639

 

Interest expense

 

42,455

 

60,921

 

111,057

 

173,929

 

Loss on early extinguishment of debt

 

 

 

20,386

 

 

Income tax expense

 

135,035

 

335,460

 

75,919

 

498,709

 

Depreciation, depletion, amortization, and accretion

 

124,944

 

189,086

 

321,915

 

549,240

 

Impairment of unproved properties

 

4,542

 

8,754

 

7,895

 

43,670

 

Exploration expense

 

7,476

 

1,087

 

21,176

 

3,086

 

Equity-based compensation expense

 

24,285

 

23,915

 

85,896

 

79,280

 

State franchise taxes

 

450

 

2

 

1,738

 

131

 

Contract termination and rig stacking

 

 

 

 

10,902

 

Consolidated Adjusted EBITDAX

 

291,572

 

290,807

 

831,690

 

913,610

 

Income from discontinued operations

 

 

 

2,210

 

 

Gain on sale of assets

 

 

 

(3,564

)

 

Income tax expense

 

 

 

1,354

 

 

Adjusted EBITDAX from discontinued operations

 

 

 

 

 

Total adjusted EBITDAX

 

291,572

 

290,807

 

831,690

 

913,610

 

Interest expense

 

(42,455

)

(60,921

)

(111,057

)

(173,929

)

Exploration expense

 

(7,476

)

(1,087

)

(21,176

)

(3,086

)

Changes in current assets and liabilities

 

55,621

 

9,078

 

96,153

 

98,909

 

State franchise taxes

 

(450

)

(2

)

(1,738

)

(131

)

Other noncash items

 

3,905

 

8,130

 

4,874

 

1,227

 

Net cash provided by operating activities

 

$

300,717

 

246,005

 

798,746

 

836,600

 

 

 

 

Three months ended

 

Nine months ended

 

 

 

September 30,

 

September 30,

 

 

 

2014

 

2015

 

2014

 

2015

 

Adjusted EBITDAX margin ($ per Mcfe):

 

 

 

 

 

 

 

 

 

 

 

 

 

Realized price before cash receipts for settled derivatives

 

$

4.33

 

$

2.34

 

$

5.06

 

$

2.59

 

Gathering, compression, and water distribution revenues

 

0.05

 

0.03

 

0.05

 

0.03

 

Lease operating expense

 

(0.09

)

(0.08

)

(0.07

)

(0.06

)

Gathering, compression, processing and transportation costs

 

(1.29

)

(1.16

)

(1.26

)

(1.20

)

Marketing, net

 

(0.14

)

(0.19

)

(0.14

)

(0.17

)

Production taxes

 

(0.22

)

(0.08

)

(0.26

)

(0.14

)

General and administrative(1)

 

(0.29

)

(0.25

)

(0.30

)

(0.25

)

Gains on settled derivatives

 

0.58

 

1.49

 

0.23

 

1.44

 

Adjusted EBITDAX margin ($ per Mcfe):

 

$

2.93

 

$

2.10

 

$

3.31

 

$

2.24

 

 


(1)         Excludes franchise taxes and equity-based stock compensation that is included in G&A

 

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The following reconciles the financial results from the gathering and compression business and water handling business to the consolidated total statements of operations and capital expenditures in Antero Midstream’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2015:

 

 

 

Gathering and

 

Water

 

Consolidated

 

 

 

Compression

 

Handling

 

Total

 

Three months ended September 30, 2014

 

 

 

 

 

 

 

Revenues:

 

 

 

 

 

 

 

Revenue - affiliate

 

$

26,282

 

$

42,631

 

$

68,913

 

Revenue - third-party

 

 

2,671

 

2,671

 

Total revenues

 

26,282

 

45,302

 

71,584

 

 

 

 

 

 

 

 

 

Operating expenses:

 

 

 

 

 

 

 

Direct operating

 

3,525

 

9,054

 

12,579

 

General and administrative (before equity-based compensation)

 

3,956

 

1,576

 

5,532

 

Equity-based compensation

 

1,562

 

549

 

2,111

 

Depreciation

 

10,227

 

4,390

 

14,617

 

Total

 

19,270

 

15,569

 

34,839

 

Operating income

 

$

7,012

 

$

29,733

 

$

36,745

 

 

 

 

 

 

 

 

 

Three months ended September 30, 2015

 

 

 

 

 

 

 

Revenues:

 

 

 

 

 

 

 

Revenue - affiliate

 

$

59,220

 

$

21,819

 

$

81,039

 

Revenue - third-party

 

38

 

627

 

665

 

Total revenues

 

59,258

 

22,446

 

81,704

 

 

 

 

 

 

 

 

 

Operating expenses:

 

 

 

 

 

 

 

Direct operating

 

(3,164

)

4,773

 

1,609

 

General and administrative (before equity-based compensation)

 

7,060

 

1,498

 

8,558

 

Equity-based compensation

 

4,205

 

1,079

 

5,284

 

Depreciation

 

15,076

 

6,485

 

21,561

 

Total

 

23,177

 

13,835

 

37,012

 

Operating income

 

$

36,081

 

$

8,611

 

$

44,692

 

 

 

 

Gathering and

 

Water

 

Consolidated

 

 

 

Compression

 

Handling

 

Total

 

Nine months ended September 30, 2014

 

 

 

 

 

 

 

Revenues:

 

 

 

 

 

 

 

Revenue - affiliate

 

$

54,978

 

$

107,907

 

$

162,885

 

Revenue - third-party

 

 

2,671

 

2,671

 

Total revenues

 

54,978

 

110,578

 

165,556

 

 

 

 

 

 

 

 

 

Operating expenses:

 

 

 

 

 

 

 

Direct operating

 

6,661

 

25,871

 

32,532

 

General and administrative (before equity-based compensation)

 

9,710

 

4,085

 

13,795

 

Equity-based compensation

 

5,365

 

2,027

 

7,392

 

Depreciation

 

24,991

 

10,748

 

35,739

 

Total

 

46,727

 

42,731

 

89,458

 

Operating income

 

$

8,251

 

$

67,847

 

$

76,098

 

 

 

 

 

 

 

 

 

Nine months ended September 30, 2015

 

 

 

 

 

 

 

Revenues:

 

 

 

 

 

 

 

Revenue - affiliate

 

$

168,056

 

$

86,759

 

$

254,815

 

Revenue - third-party

 

38

 

778

 

816

 

Total revenues

 

168,094

 

87,537

 

255,631

 

 

 

 

 

 

 

 

 

Operating expenses:

 

 

 

 

 

 

 

Direct operating

 

19,817

 

19,013

 

38,830

 

General and administrative (before equity-based compensation)

 

16,467

 

3,793

 

20,260

 

Equity-based compensation

 

14,218

 

3,445

 

17,663

 

Depreciation

 

44,748

 

18,767

 

63,515

 

Total

 

95,250

 

45,018

 

140,268

 

Operating income

 

$

72,844

 

$

42,519

 

$

115,363

 

 

8



 

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.

 

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

 

9



 

ANTERO RESOURCES CORPORATION

Condensed Consolidated Balance Sheets

December 31, 2014 and September 30, 2015

(Unaudited)

(In thousands, except share amounts)

 

 

 

2014

 

2015

 

Assets

 

 

 

 

 

Current assets:

 

 

 

 

 

Cash and cash equivalents

 

$

245,979

 

27,410

 

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

 

116,203

 

60,904

 

Accrued revenue

 

191,558

 

115,793

 

Derivative instruments

 

692,554

 

834,482

 

Other current assets

 

5,866

 

1,739

 

Total current assets

 

1,252,160

 

1,040,328

 

Property and equipment:

 

 

 

 

 

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

 

 

 

 

 

Unproved properties

 

2,060,936

 

2,072,475

 

Proved properties

 

6,515,221

 

7,805,203

 

Water handling systems

 

421,012

 

517,513

 

Gathering systems and facilities

 

1,197,239

 

1,448,404

 

Other property and equipment

 

37,687

 

45,494

 

 

 

10,232,095

 

11,889,089

 

Less accumulated depletion, depreciation, and amortization

 

(879,643

)

(1,427,656

)

Property and equipment, net

 

9,352,452

 

10,461,433

 

Derivative instruments

 

899,997

 

2,007,828

 

Other assets

 

68,886

 

67,485

 

Total assets

 

$

11,573,495

 

13,577,074

 

 

 

 

 

 

 

Liabilities and Equity

 

 

 

 

 

Current liabilities:

 

 

 

 

 

Accounts payable

 

$

531,564

 

337,493

 

Accrued liabilities

 

168,614

 

202,186

 

Revenue distributions payable

 

182,352

 

161,513

 

Deferred income tax liability

 

260,373

 

315,366

 

Other current liabilities

 

12,202

 

9,211

 

Total current liabilities

 

1,155,105

 

1,025,769

 

Long-term liabilities:

 

 

 

 

 

Long-term debt

 

4,362,550

 

4,406,777

 

Deferred income tax liability

 

534,423

 

978,139

 

Other liabilities

 

47,587

 

55,965

 

Total liabilities

 

6,099,665

 

6,466,650

 

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 277,029,931 shares, respectively

 

2,621

 

2,770

 

Additional paid-in capital

 

3,513,725

 

4,122,747

 

Accumulated earnings

 

867,447

 

1,650,347

 

Total stockholders’ equity

 

4,383,793

 

5,775,864

 

Noncontrolling interest in consolidated subsidiary

 

1,090,037

 

1,334,560

 

Total equity

 

5,473,830

 

7,110,424

 

Total liabilities and equity

 

$

11,573,495

 

13,577,074

 

 

10



 

ANTERO RESOURCES CORPORATION

Condensed Consolidated Statements of Operations and Comprehensive Income

Three Months Ended September 30, 2014 and 2015

(Unaudited)

(In thousands, except share and per share amounts)

 

 

 

2014

 

2015

 

Revenue:

 

 

 

 

 

Natural gas sales

 

$

310,390

 

$

253,975

 

Natural gas liquids sales

 

91,111

 

50,092

 

Oil sales

 

29,304

 

20,138

 

Gathering, compression, and water distribution

 

4,875

 

4,426

 

Marketing

 

17,835

 

35,633

 

Commodity derivative fair value gains

 

308,975

 

1,079,071

 

Total revenue

 

762,490

 

1,443,335

 

Operating expenses:

 

 

 

 

 

Lease operating

 

8,680

 

10,786

 

Gathering, compression, processing, and transportation

 

128,531

 

160,302

 

Production and ad valorem taxes

 

21,726

 

10,721

 

Marketing

 

32,192

 

61,799

 

Exploration

 

7,476

 

1,087

 

Impairment of unproved properties

 

4,542

 

8,754

 

Depletion, depreciation, and amortization

 

124,624

 

188,667

 

Accretion of asset retirement obligations

 

320

 

419

 

General and administrative (including equity-based compensation expense of $24,285 and $23,915 in 2014 and 2015, respectively)

 

53,000

 

59,685

 

Total operating expenses

 

381,091

 

502,220

 

Operating loss

 

381,399

 

941,115

 

Other expenses:

 

 

 

 

 

Interest

 

(42,455

)

(60,921

)

Income from continuing operations before income taxes

 

338,944

 

880,194

 

Provision for income tax expense

 

(135,035

)

(335,460

)

Net Income and comprehensive income including noncontrolling interest

 

203,909

 

544,734

 

Net income and comprehensive income attributable to noncontrolling interest

 

 

10,892

 

Net Income and comprehensive income attributable to Antero Resources Corporation

 

$

203,909

 

$

533,842

 

 

 

 

 

 

 

Earnings per common share

 

$

0.78

 

$

1.93

 

 

 

 

 

 

 

Earnings per common share—assuming dilution

 

$

0.78

 

$

1.93

 

 

 

 

 

 

 

Weighted average number of shares outstanding:

 

 

 

 

 

Basic

 

262,049,948

 

277,007,427

 

Diluted

 

262,069,878

 

277,014,756

 

 

11



 

ANTERO RESOURCES CORPORATION

Condensed Consolidated Statements of Operations and Comprehensive Income

Nine Months Ended September 30, 2014 and 2015

(Unaudited)

(In thousands, except share and per share amounts)

 

 

 

2014

 

2015

 

Revenue:

 

 

 

 

 

Natural gas sales

 

$

936,877

 

$

810,982

 

Natural gas liquids sales

 

244,807

 

188,403

 

Oil sales

 

89,059

 

55,627

 

Gathering, compression, and water distribution

 

11,964

 

15,084

 

Marketing

 

23,048

 

143,242

 

Commodity derivative fair value gains (losses)

 

(63,720

)

1,836,398

 

Total revenue

 

1,242,035

 

3,049,736

 

Operating expenses:

 

 

 

 

 

Lease operating

 

18,570

 

25,561

 

Gathering, compression, processing, and transportation

 

315,878

 

490,633

 

Production and ad valorem taxes

 

64,123

 

57,458

 

Marketing

 

58,119

 

214,201

 

Exploration

 

21,176

 

3,086

 

Impairment of unproved properties

 

7,895

 

43,670

 

Depletion, depreciation, and amortization

 

320,984

 

548,013

 

Accretion of asset retirement obligations

 

931

 

1,227

 

General and administrative (including equity-based compensation expense of $85,896 and $79,280 in 2014 and 2015, respectively)

 

162,342

 

177,925

 

Contract termination and rig stacking

 

 

10,902

 

Total operating expenses

 

970,018

 

1,572,676

 

Operating income

 

272,017

 

1,477,060

 

Other expenses:

 

 

 

 

 

Interest

 

(111,057

)

(173,929

)

Loss on early extinguishment of debt

 

(20,386

)

 

Total other expenses

 

(131,443

)

(173,929

)

Income from continuing operations before income taxes and discontinued operations

 

140,574

 

1,303,131

 

Provision for income tax expense

 

(75,919

)

(498,709

)

Income from continuing operations

 

64,655

 

804,422

 

Discontinued operations:

 

 

 

 

 

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

 

2,210

 

 

Net income and comprehensive income including noncontrolling interest

 

66,865

 

804,422

 

Net income and comprehensive income attributable to noncontrolling interest

 

 

21,522

 

Net income and comprehensive income attributable to Antero Resources Corporation

 

$

66,865

 

$

782,900

 

 

 

 

 

 

 

Earnings per common share:

 

 

 

 

 

Continuing operations

 

$

0.25

 

$

2.87

 

Discontinued operations

 

0.01

 

 

Total

 

$

0.26

 

$

2.87

 

 

 

 

 

 

 

Earnings per common share—assuming dilution

 

 

 

 

 

Continuing operations

 

$

0.25

 

$

2.87

 

Discontinued operations

 

0.01

 

 

Total

 

$

0.26

 

$

2.87

 

 

 

 

 

 

 

Weighted average number of shares outstanding:

 

 

 

 

 

Basic

 

262,049,756

 

273,144,573

 

Diluted

 

262,066,632

 

273,153,965

 

 

12



 

ANTERO RESOURCES CORPORATION

Condensed Consolidated Statements of Cash Flows

Nine Months Ended September 30, 2014 and 2015

(Unaudited)

(In thousands)

 

 

 

2014

 

2015

 

Cash flows from operating activities:

 

 

 

 

 

Net income including noncontrolling interest

 

$

66,865

 

$

804,422

 

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

 

 

 

 

 

Depletion, depreciation, amortization, and accretion

 

321,915

 

549,240

 

Impairment of unproved properties

 

7,895

 

43,670

 

Derivative fair value (gains) losses

 

63,720

 

(1,836,398

)

Gains on settled derivatives

 

57,333

 

586,639

 

Deferred income tax expense

 

75,919

 

498,709

 

Equity-based compensation expense

 

85,896

 

79,280

 

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

 

4,874

 

12,129

 

Changes in current assets and liabilities:

 

 

 

 

 

Accounts receivable

 

(36,145

)

15,299

 

Accrued revenue

 

(47,189

)

75,765

 

Other current assets

 

975

 

4,127

 

Accounts payable

 

530

 

(1,302

)

Accrued liabilities

 

105,278

 

29,537

 

Revenue distributions payable

 

72,857

 

(20,839

)

Other current liabilities

 

(153

)

(3,678

)

Net cash provided by operating activities

 

798,746

 

836,600

 

Cash flows used in investing activities:

 

 

 

 

 

Additions to unproved properties

 

(518,247

)

(170,291

)

Drilling and completion costs

 

(1,723,657

)

(1,350,498

)

Additions to water handling systems

 

(156,467

)

(79,227

)

Additions to gathering systems and facilities

 

(406,666

)

(282,813

)

Additions to other property and equipment

 

(12,539

)

(5,225

)

Change in other assets

 

(6,896

)

11,190

 

Proceeds from asset sales

 

 

40,000

 

Net cash used in investing activities

 

(2,824,472

)

(1,836,864

)

Cash flows from financing activities:

 

 

 

 

 

Issuance of common stock

 

 

537,832

 

Issuance of common units in Antero Midstream Partners LP

 

 

240,972

 

Issuance of senior notes

 

1,102,500

 

750,000

 

Repayment of senior notes

 

(260,000

)

 

Borrowings (repayments) on bank credit facility, net

 

1,217,000

 

(705,000

)

Make-whole premium on debt extinguished

 

(17,383

)

 

Payments of deferred financing costs

 

(27,570

)

(17,190

)

Distributions to noncontrolling interest in consolidated subsidiary

 

 

(21,358

)

Other

 

 

(3,561

)

Net cash provided by financing activities

 

2,014,547

 

781,695

 

Net decrease in cash and cash equivalents

 

(11,179

)

(218,569

)

Cash and cash equivalents, beginning of period

 

17,487

 

245,979

 

Cash and cash equivalents, end of period

 

$

6,308

 

$

27,410

 

 

 

 

 

 

 

Supplemental disclosure of cash flow information:

 

 

 

 

 

Cash paid during the period for interest

 

$

67,299

 

$

116,579

 

Supplemental disclosure of noncash investing activities:

 

 

 

 

 

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

 

$

227,368

 

$

(193,288

)

 

13



 

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

 

 

 

Three Months Ended September 30,

 

Amount of
Increase

 

Percent

 

(in thousands)

 

2014

 

2015

 

(Decrease)

 

Change

 

Operating revenues:

 

 

 

 

 

 

 

 

 

Natural gas sales

 

$

310,390 

 

$

253,975

 

$

(56,415

)

(18

)%

NGLs sales

 

91,111

 

50,092

 

(41,019

)

(45

)%

Oil sales

 

29,304

 

20,138

 

(9,166

)

(31

)%

Gathering, compression, and water distribution

 

4,875

 

4,426

 

(449

)

(9

)%

Marketing

 

17,835

 

35,633

 

17,798

 

100

%

Commodity derivative fair value gains

 

308,975

 

1,079,071

 

770,096

 

249

%

Total operating revenues

 

762,490

 

1,443,335

 

680,845

 

89

%

Operating expenses:

 

 

 

 

 

 

 

 

 

Lease operating

 

8,680

 

10,786

 

2,106

 

24

%

Gathering, compression, processing, and transportation

 

128,531

 

160,302

 

31,771

 

25

%

Production and ad valorem taxes

 

21,726

 

10,721

 

(11,005

)

(51

)%

Marketing

 

32,192

 

61,799

 

29,607

 

92

%

Exploration

 

7,476

 

1,087

 

(6,389

)

(85

)%

Impairment of unproved properties

 

4,542

 

8,754

 

4,212

 

93

%

Depletion, depreciation, and amortization

 

124,624

 

188,667

 

64,043

 

51

%

Accretion of asset retirement obligations

 

320

 

419

 

99

 

31

%

General and administrative (before equity-based compensation)

 

28,715

 

35,770

 

7,055

 

25

%

Equity-based compensation

 

24,285

 

23,915

 

(370

)

(2

)%

Total operating expenses

 

381,091

 

502,220

 

121,129

 

32

%

Operating income

 

381,399

 

941,115

 

559,716

 

147

%

 

 

 

 

 

 

 

 

 

 

Other Expenses:

 

 

 

 

 

 

 

 

 

Interest expense

 

(42,455

)

(60,921

)

(18,466

)

43

%

Income before income taxes

 

338,944

 

880,194

 

541,250

 

160

%

Income tax expense

 

(135,035

)

(335,460

)

(200,425

)

148

%

Net income and comprehensive income including noncontrolling interest

 

203,909

 

544,734

 

340,825

 

167

%

Net income and comprehensive income attributable to noncontrolling interest

 

 

10,892

 

10,892

 

*

 

Net income and comprehensive income attributable to Antero Resources Corporation

 

$

203,909 

 

$

533,842

 

$

329,933

 

162

%

 

 

 

 

 

 

 

 

 

 

Adjusted EBITDAX

 

$

291,572 

 

$

290,807

 

$

(765

)

*

 

 


*                 Not meaningful or applicable

 

14



 

 

 

Three Months Ended September 30,

 

Amount of
Increase

 

Percent

 

 

 

2014

 

2015

 

(Decrease)

 

Change

 

Production data:

 

 

 

 

 

 

 

 

 

Natural gas (Bcf)

 

86

 

110

 

24

 

28

%

NGLs (MBbl)

 

1,953

 

4,147

 

2,194

 

112

%

Oil (MBbl)

 

348

 

660

 

312

 

90

%

Combined (Bcfe)

 

99

 

139

 

40

 

39

%

Daily combined production (MMcfe/d)

 

1,080

 

1,506

 

426

 

39

%

Average prices before effects of derivative settlements:

 

 

 

 

 

 

 

 

 

Natural gas (per Mcf)

 

$

3.63

 

$

2.32

 

$

(1.31

)

(36

)%

NGLs (per Bbl)

 

$

46.66

 

$

12.08

 

$

(34.58

)

(74

)%

Oil (per Bbl)

 

$

84.17

 

$

30.49

 

$

(53.68

)

(64

)%

Combined (per Mcfe)

 

$

4.33

 

$

2.34

 

$

(1.99

)

(46

)%

Average realized prices after effects of derivative settlements:

 

 

 

 

 

 

 

 

 

Natural gas (per Mcf)

 

$

4.31

 

$

3.99

 

$

(0.32

)

(7

)%

NGLs (per Bbl)

 

$

46.66

 

$

16.47

 

$

(30.19

)

(65

)%

Oil (per Bbl)

 

$

82.47

 

$

38.18

 

$

(44.29

)

(54

)%

Combined (per Mcfe)

 

$

4.91

 

$

3.83

 

$

(1.08

)

(22

)%

Average Costs (per Mcfe):

 

 

 

 

 

 

 

 

 

Lease operating

 

$

0.09

 

$

0.08

 

$

(0.01

)

(11

)%

Gathering, compression, processing, and transportation

 

$

1.29

 

$

1.16

 

$

(0.13

)

(10

)%

Production and ad valorem taxes

 

$

0.22

 

$

0.08

 

$

(0.14

)

(64

)%

Marketing, net

 

$

0.14

 

$

0.19

 

$

0.05

 

36

%

Depletion, depreciation, amortization, and accretion

 

$

1.26

 

$

1.37

 

$

0.11

 

9

%

General and administrative (before equity-based compensation)

 

$

0.29

 

$

0.26

 

$

(0.03

)

(10

)%

 

15



 

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

 

 

 

Nine Months Ended September 30,

 

Amount of
Increase

 

Percent

 

(in thousands)

 

2014

 

2015

 

(Decrease)

 

Change

 

Operating revenues:

 

 

 

 

 

 

 

 

 

Natural gas sales

 

$

936,877

 

$

810,982

 

$

(125,895

)

(13

)%

NGLs sales

 

244,807

 

188,403

 

(56,404

)

(23

)%

Oil sales

 

89,059

 

55,627

 

(33,432

)

(38

)%

Gathering, compression, and water handling

 

11,964

 

15,084

 

3,120

 

26

%

Marketing

 

23,048

 

143,242

 

120,194

 

521

%

Commodity derivative fair value gains (losses)

 

(63,720

)

1,836,398

 

1,900,118

 

*

 

Total operating revenues

 

1,242,035

 

3,049,736

 

1,807,701

 

146

%

Operating expenses:

 

 

 

 

 

 

 

 

 

Lease operating

 

18,570

 

25,561

 

6,991

 

38

%

Gathering, compression, processing, and transportation

 

315,878

 

490,633

 

174,755

 

55

%

Production and ad valorem taxes

 

64,123

 

57,458

 

(6,665

)

(10

)%

Marketing

 

58,119

 

214,201

 

156,082

 

269

%

Exploration

 

21,176

 

3,086

 

(18,090

)

(85

)%

Impairment of unproved properties

 

7,895

 

43,670

 

35,775

 

453

%

Depletion, depreciation, and amortization

 

320,984

 

548,013

 

227,029

 

71

%

Accretion of asset retirement obligations

 

931

 

1,227

 

296

 

32

%

General and administrative (before equity-based compensation)

 

76,446

 

98,645

 

22,199

 

29

%

Equity-based compensation

 

85,896

 

79,280

 

(6,616

)

(8

)%

Contract termination and rig stacking

 

 

10,902

 

10,902

 

*

 

Total operating expenses

 

970,018

 

1,572,676

 

602,658

 

62

%

Operating income

 

272,017

 

1,477,060

 

1,205,043

 

443

%

 

 

 

 

 

 

 

 

 

 

Other Expenses:

 

 

 

 

 

 

 

 

 

Interest expense

 

(111,057

)

(173,929

)

(62,872

)

57

%

Loss on early extinguishment of debt

 

(20,386

)

 

20,386

 

*

 

Total other expenses

 

(131,443

)

(173,929

)

(42,486

)

32

%

Income from continuing operations before income taxes and discontinued operations

 

140,574

 

1,303,131

 

1,162,557

 

827

%

Income tax expense

 

(75,919

)

(498,709

)

(422,790

)

557

%

Income from continuing operations

 

64,655

 

804,422

 

739,767

 

1,144

%

Income from discontinued operations

 

2,210

 

 

(2,210

)

*

 

Net income and comprehensive income including noncontrolling interest

 

66,865

 

804,422

 

737,557

 

1,103

%

Net income and comprehensive income attributable to noncontrolling interest

 

 

21,522

 

21,522

 

*

 

Net income and comprehensive income attributable to Antero Resources Corporation

 

$

66,865

 

$

782,900

 

$

716,035

 

1,071

%

 

 

 

 

 

 

 

 

 

 

Adjusted EBITDAX

 

$

831,690

 

$

913,610

 

$

81,920

 

10

%

 

16



 

 

 

Nine Months Ended September 30,

 

Amount of
Increase

 

Percent

 

 

 

2014

 

2015

 

(Decrease)

 

Change

 

Production data:

 

 

 

 

 

 

 

 

 

Natural gas (Bcf)

 

217

 

332

 

115

 

53

%

NGLs (MBbl)

 

4,602

 

11,042

 

6,440

 

140

%

Oil (MBbl)

 

1,010

 

1,549

 

539

 

53

%

Combined (Bcfe)

 

251

 

407

 

156

 

62

%

Daily combined production (MMcfe/d)

 

920

 

1,492

 

572

 

62

%

Average prices before effects of derivative settlements:

 

 

 

 

 

 

 

 

 

Natural gas (per Mcf)

 

$

4.31

 

$

2.45

 

$

(1.86

)

(43

)%

NGLs (per Bbl)

 

$

53.20

 

$

17.06

 

$

(36.14

)

(68

)%

Oil (per Bbl)

 

$

88.15

 

$

35.91

 

$

(52.24

)

(59

)%

Combined (per Mcfe)

 

$

5.06

 

$

2.59

 

$

(2.47

)

(49

)%

Average realized prices after effects of derivative settlements:

 

 

 

 

 

 

 

 

 

Natural gas (per Mcf)

 

$

4.58

 

$

4.07

 

$

(0.51

)

(11

)%

NGLs (per Bbl)

 

$

53.20

 

$

20.34

 

$

(32.86

)

(62

)%

Oil (per Bbl)

 

$

86.57

 

$

42.90

 

$

(43.67

)

(50

)%

Combined (per Mcfe)

 

$

5.29

 

$

4.03

 

$

(1.26

)

(24

)%

Average Costs (per Mcfe):

 

 

 

 

 

 

 

 

 

Lease operating

 

$

0.07

 

$

0.06

 

$

(0.01

)

(14

)%

Gathering, compression, processing, and transportation

 

$

1.26

 

$

1.20

 

$

(0.06

)

(5

)%

Production and ad valorem taxes

 

$

0.26

 

$

0.14

 

$

(0.12

)

(46

)%

Marketing, net

 

$

0.14

 

$

0.17

 

$

0.03

 

21

%

Depletion, depreciation, amortization, and accretion

 

$

1.28

 

$

1.35

 

$

0.07

 

5

%

General and administrative (before equity-based compensation)

 

$

0.30

 

$

0.24

 

$

(0.06

)

(20

)%

 


*                      Not meaningful or applicable

 

17