Quarterly report pursuant to Section 13 or 15(d)

Summary of Significant Accounting Policies (Policies)

Summary of Significant Accounting Policies (Policies)
3 Months Ended
Mar. 31, 2015
Summary of Significant Accounting Policies  
Basis of Presentation

(a)Basis of Presentation


These consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC applicable to interim financial information and should be read in the context of the December 31, 2014 consolidated financial statements and notes thereto for a more complete understanding of the Company’s operations, financial position, and accounting policies.  The December 31, 2014 consolidated financial statements have been filed with the SEC in the Company’s 2014 Form 10-K.


The accompanying unaudited condensed consolidated financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim financial information, and, accordingly, do not include all of the information and footnotes required by GAAP for complete consolidated financial statements.  In the opinion of management, the accompanying unaudited condensed consolidated financial statements include all adjustments (consisting of normal and recurring accruals) considered necessary to present fairly the Company’s financial position as of March 31, 2015, the results of its operations for the three months ended March 31, 2014 and 2015, and its cash flows for the three months ended March 31, 2014 and 2015.  The Company has no items of other comprehensive income or loss; therefore, its net income or loss is identical to its comprehensive income or loss.  Operating results for the period ended March 31, 2015 are not necessarily indicative of the results that may be expected for the full year because of the impact of fluctuations in prices received for natural gas, NGLs, and oil, natural production declines, the uncertainty of exploration and development drilling results, and other factors.


The Company’s exploration and production activities are accounted for under the successful efforts method.


As of the date these financial statements were filed with the SEC, the Company completed its evaluation of potential subsequent events for disclosure and no items requiring disclosure were identified except for the grants of restricted stock units and stock options as discussed in note 5.

Principles of Consolidation

(b)Principles of Consolidation


The accompanying consolidated financial statements include the accounts of Antero Resources Corporation, its wholly-owned subsidiaries, and any entities in which the Company owns a controlling interest.  All significant intercompany accounts and transactions have been eliminated in the Company’s consolidated financial statements.  Noncontrolling interest in the Company’s consolidated financial statements represents the interests in Antero Midstream which are owned by third-party individuals or entities.  An affiliate of the Company owns the general partner interest in Antero Midstream, as well as all of the incentive distribution rights.  Noncontrolling interest is included as a component of equity in the Company’s consolidated balance sheets.


Use of Estimates

(c)Use of Estimates


The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported assets and liabilities, and disclosure of contingent assets and liabilities, at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period.  Changes in facts and circumstances or discovery of new information may result in revised estimates, and actual results could differ from those estimates.


The Company’s condensed consolidated financial statements are based on a number of significant estimates including estimates of natural gas, NGLs, and oil reserve quantities, which are the basis for the calculation of depletion, depreciation, amortization, and impairment of oil and gas properties.  Reserve estimates by their nature are inherently imprecise.  Other items in the Company’s consolidated financial statements which involve the use of significant estimates include derivative assets and liabilities, accrued revenue, deferred income taxes, asset retirement obligations, equity-based compensation, and commitments and contingencies.

Risks and Uncertainties

(d)Risks and Uncertainties


Historically, the market for natural gas, NGLs, and oil has experienced significant price fluctuations.  Price fluctuations can result from variations in weather, levels of production in the region, availability of transportation capacity to other regions of the country, and various other factors.  Increases or decreases in the prices the Company receives for its production could have a significant impact on the Company’s future results of operations.

Cash and Cash Equivalents

(e)Cash and Cash Equivalents


The Company considers all liquid investments purchased with an initial maturity of three months or less to be cash equivalents.  The carrying value of cash and cash equivalents approximates fair value due to the short-term nature of these instruments.

Derivative Financial Instruments

(f)Derivative Financial Instruments


In order to manage its exposure to natural gas, NGLs, and oil price volatility, the Company enters into derivative transactions from time to time, including commodity swap agreements, basis swap agreements, collar agreements, and other similar agreements relating to the price risk associated with a portion of its production.  To the extent legal right of offset exists with a counterparty, the Company reports derivative assets and liabilities on a net basis.  The Company has exposure to credit risk to the extent the counterparty is unable to satisfy its settlement obligations.  The fair value of our commodity derivative contracts of approximately $2.2 billion at March 31, 2015 includes the following values by bank counterparty:  Citigroup - $406 million; Barclays - $388 million; JP Morgan - $354 million; Credit Suisse - $313 million; Wells Fargo - $258 million; BNP Paribas - $217 million; Scotiabank - $131 million; Toronto Dominion - $49 million; Fifth Third - $37 million; Canadian Imperial Bank of Commerce - $7 million; Bank of Montreal - $4 million; and Morgan Stanley - $3 million.  The credit ratings of certain of these banks were downgraded in recent years because of the sovereign debt crisis in Europe.  The Company actively monitors the creditworthiness of counterparties and assesses the impact, if any, on its derivative position.


The Company records derivative instruments on the consolidated balance sheets as either an asset or liability measured at fair value and records changes in the fair value of derivatives in current earnings as they occur.  Changes in the fair value of commodity derivatives are classified as revenues on the Company’s condensed consolidated statements of operations.  The Company’s derivatives have not been designated as hedges for accounting purposes.


Income Taxes

(g)Income Taxes


The Company recognizes deferred tax assets and liabilities for temporary differences resulting from net operating loss carryforwards for income tax purposes and the differences between the financial statement and tax basis of assets and liabilities.  The effect of changes in the tax laws or tax rates is recognized in income in the period such changes are enacted.  Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion, or all, of the deferred tax assets will not be realized.


Unrecognized tax benefits represent potential future tax obligations for uncertain tax positions taken on previously filed tax returns that may not ultimately be sustained.  The Company recognizes interest expense related to unrecognized tax benefits in interest expense and fines and penalties for tax-related matters as income tax expense.

Fair Value Measures

(h)Fair Value Measurements


FASB ASC Topic 820, Fair Value Measurements and Disclosures, clarifies the definition of fair value, establishes a framework for measuring fair value, and expands disclosures about fair value measurements.  This guidance also relates to all nonfinancial assets and liabilities that are not recognized or disclosed on a recurring basis (e.g., those measured at fair value in a business combination, the initial recognition of asset retirement obligations, and impairments of proved oil and gas properties, and other long-lived assets).  Fair value is the price that the Company estimates would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date.  A fair value hierarchy is used to prioritize inputs to valuation techniques used to estimate fair value.  An asset or liability subject to the fair value requirements is categorized within the hierarchy based on the lowest level of input that is significant to the fair value measurement.  The Company’s assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the asset or liability.  The highest priority (Level 1) is given to unadjusted, quoted market prices in active markets for identical assets or liabilities, and the lowest priority (Level 3) is given to unobservable inputs.  Level 2 inputs are data, other than quoted prices included within Level 1, which are observable for the asset or liability, either directly or indirectly.  Instruments which are valued using Level 2 inputs include non-exchange traded derivatives such as over-the-counter commodity price swaps and basis swaps.  Valuation models used to measure fair value of these instruments consider various Level 2 inputs including (i) quoted forward prices for commodities, (ii) time value, (iii) quoted forward interest rates, (iv) current market prices and contractual prices for the underlying instruments, (v) risk of nonperformance by the Company and the counterparty, and (vi) other relevant economic measures.

Industry Segments and Geographic Information

(i)Industry Segments and Geographic Information


Management has evaluated how the Company is organized and managed and has identified the following segments: (1) the exploration, development, and production of natural gas, NGLs, and oil; (2) gathering and compression; (3) fresh water distribution and (4) marketing of excess firm transportation capacity.


All of the Company’s assets are located in the United States and substantially all of its production revenues are attributable to customers located in the United States.


Marketing Revenues and Expenses

(j)Marketing Revenues and Expenses


In 2014, the Company commenced activities to purchase and sell third-party natural gas and NGLs and to market its excess firm transportation capacity in order to utilize this excess capacity.  Marketing revenues include sales of purchased third-party gas and NGLs, as well as revenues from the release of firm transportation capacity to others.  Marketing expenses include the cost of purchased third-party natural gas and NGLs.  The Company classifies firm transportation costs related to capacity contracted for in advance of having sufficient production and infrastructure to fully utilize the capacity (excess capacity) as marketing expenses since it is marketing this excess capacity to third parties.  Firm transportation for which the Company has sufficient production capacity (even though it may not use the transportation capacity because of alternative delivery points with more favorable pricing) is considered unutilized capacity. The costs of unutilized capacity are charged to transportation expense.




Certain reclassifications have been made to prior periods’ financial information related to marketing revenues and expenses to conform to the 2015 presentation.

Earnings (loss) per common share

(l)Earnings (loss) per common share


Earnings (loss) per common share were calculated based on the weighted average number of shares outstanding of 262,049,659 and 265,294,794 for the three months ended March 31, 2014 and 2015, respectively.  Because of the loss incurred for the three months ended March 31, 2014, the effect of outstanding equity awards was antidilutive during such time.  Earnings per common share—assuming dilution for the three months ended March 31, 2015 was calculated based on the diluted weighted average number of shares outstanding of 265,300,080, including 5,286 dilutive shares attributable to non-vested restricted stock and restricted stock unit awards.


For the three months ended March 31, 2015,  1,970,774 non-vested shares of restricted stock and restricted stock unit awards and 81,021 stock options were anti-dilutive and therefore excluded from the calculation of diluted earnings per share.