Southwestern Energy (SWN) 10-Q 23 Apr 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015	Apr. 21, 2015
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Entity Registrant Name	SOUTHWESTERN ENERGY CO
Entity Central Index Key	7332
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		384,554,852
Trading Symbol	SWN

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Operating Revenues:
Gas sales	$625	$793
Oil sales	17	2
NGL sales	18
Marketing	225	272
Gas gathering	48	46
Total Operating Revenues	933	1,113
Operating Costs and Expenses:
Marketing purchases	222	271
Operating expenses	155	100
General and administrative expenses	68	57
Depreciation, depletion and amortization	293	225
Taxes, other than income taxes	30	25
Total Operating Costs and Expenses	768	678
Operating Income	165	435
Interest Expense:
Interest on debt	50	25
Other interest charges	49	1
Interest capitalized	-48	-13
Total Interest Expense	51	13
Other Income (Loss), Net	-1	1
Gain (Loss) on Derivatives	14	-100
Income Before Income Taxes	127	323
Provision (Benefit) for Income Taxes:
Current		-1
Deferred	49	130
Total Provision for Income Taxes	49	129
Net Income	78	194
Mandatory convertible preferred stock dividend	25
Participating securities - mandatory convertible preferred stock	7
Net Income Attributable to Common Stock	$46	$194
Earnings Per Common Share:
Basic	$0.12	$0.55
Diluted	$0.12	$0.55
Weighted Average Common Shares Outstanding:
Basic	375,444,030	351,222,538
Diluted	375,578,054	351,985,821

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME [Abstract]
Net income	$78		$194
Change in derivatives:
Settlements	-25	[1]	25	[1]
Ineffectiveness		[2]	1	[2]
Change in fair value of derivative instruments	17	[3]	-54	[3]
Total change in derivatives	-8		-28
Change in currency translation adjustment	-6		-3
Comprehensive income	$64		$163
[1]	Net of $(17) and $17 million in taxes for the three months ended March 31, 2015 and 2014, respectively.
[2]	Net of $0 and $1 million in taxes for the three months ended March 31, 2015 and 2014, respectively.
[3]	Net of $7 and $(36) million in taxes for the three months ended March 31, 2015 and 2014, respectively.

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME [Abstract]
Settlements tax	($17)	$17
Ineffectiveness tax	0	1
Change in fair value of derivative instruments tax	$7	($36)

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Current assets:
Cash and cash equivalents	$17	$53
Accounts receivable	491	530
Inventories	39	37
Derivative assets	295	337
Other current assets	46	158
Total current assets	888	1,115
Natural gas and oil properties, using the full cost method, including $4,997 million as of March 31, 2015 and $4,646 million as of December 31, 2014 excluded from amortization	21,516	20,506
Gathering systems	1,485	1,439
Other	626	612
Less: Accumulated depreciation, depletion and amortization	-9,144	-8,845
Total property and equipment, net	14,483	13,712
Other long-term assets	216	98
TOTAL ASSETS	15,587	14,925
Current liabilities:
Short-term debt	1	4,501
Accounts payable	606	653
Taxes payable	72	92
Interest payable	31	34
Current deferred income taxes	91	109
Dividends payable	25
Derivative liabilities	11	9
Other current liabilities	108	30
Total current liabilities	945	5,428
Long-term debt	5,163	2,466
Deferred income taxes	2,009	1,951
Pension and other postretirement liabilities	45	44
Other long-term liabilities	368	374
Total long-term liabilities	7,585	4,835
Commitments and contingencies (Note 10)
Equity:
Common stock, $0.01 par value; authorized 1,250,000,000 shares; issued 384,572,080 shares as of March 31, 2015 and 354,488,992 as of December 31, 2014	4	4
Preferred stock, $0.01 par value, 10,000,000 shares authorized, 6.25% Series B Mandatory Convertible, $1,000 per share liquidation preference, 1,725,000 shares issued and outstanding
Additional paid-in capital	3,372	1,019
Retained earnings	3,633	3,577
Accumulated other comprehensive income	48	62
Common stock in treasury, 13,893 shares in 2015 and 11,055 in 2014
Total equity	7,057	4,662
TOTAL LIABILITIES AND EQUITY	$15,587	$14,925

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
CONDENSED CONSOLIDATED BALANCE SHEETS [Abstract]
Natural gas and oil properties, using the full cost method, costs excluded from amortization	$4,997	$4,646
Common stock, par value	$0.01	$0.01
Common stock, shares authorized	1,250,000,000	1,250,000,000
Common stock, shares issued	384,572,080	354,488,992
Preferred stock, par value	$0.01
Preferred stock, shares authorized	10,000,000
Preferred stock, dividend rate	6.25%
Preferred stock, liquidation preference per share	$1,000
Preferred stock, shares issued	1,725,000
Preferred stock, shares outstanding	1,725,000
Treasury stock, shares	13,893	11,055

CONDENSED_CONSOLIDATED_STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash Flows From Operating Activities
Net income	$78	$194
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	293	225
Amortization of debt issuance cost	46	1
Deferred income taxes	49	130
Loss on derivatives excluding derivatives, settled	21	62
Stock-based compensation	6	4
Other		1
Change in assets and liabilities:
Accounts receivable	38	-78
Inventories	-3	1
Accounts payable	-35	94
Taxes payable (receivable)	-20	-13
Interest payable	-1	-10
Other assets and liabilities	69	-2
Net cash provided by operating activities	541	609
Cash Flows From Investing Activities
Capital investments	-508	-525
Acquisitions	-591	-9
Proceeds from sale of property and equipment	1	17
Other	3	1
Net cash used in investing activities	-1,095	-516
Cash Flows From Financing Activities
Payments on revolving long-term debt	-830	-1,131
Borrowings under revolving long-term debt	1,330	1,009
Change in bank drafts outstanding	-7	19
Payments on short-term debt	-4,500
Proceeds from issuance of long-term debt	2,200
Debt issuance costs	-17
Proceeds from exercise of common stock options		6
Proceeds from issuance of common stock	669
Proceeds from the issuance of mandatory convertible preferred stock	1,673
Net cash provided by (used in) financing activities	518	-97
Decrease in cash and cash equivalents	-36	-4
Cash and cash equivalents at beginning of year	53	23
Cash and cash equivalents at end of period	$17	$19

CONDENSED_CONSOLIDATED_STATEME4

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (USD $)	Common Stock [Member]	Preferred Stock [Member]	Preferred Stock [Member]	Additional Paid-In Capital [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Accumulated Comprehensive Income (Loss) [Member]	Series B Preferred Stock [Member]	Total
In Millions, except Share data, unless otherwise specified	USD ($)	Series B Preferred Stock [Member]		Series B Preferred Stock [Member]	USD ($)	USD ($)	USD ($)	USD ($)	USD ($)
				USD ($)
Balance at Dec. 31, 2014	$4				$1,019	$3,577	$62		$4,662
Balance, shares at Dec. 31, 2014	354,488,992
Comprehensive income:
Net income						78			78
Other comprehensive loss							-14		-14
Comprehensive income									64
Stock-based compensation					11				11
Preferred stock dividends						-25			-25
Issuance of restricted stock, shares	100,147
Cancellation of restricted stock, shares	-17,023
Issuance of stock, shares	30,000,000	1,725,000
Issuance of stock				1,673	669			1,673	669
Tax withholding - stock compensation, shares	-36
Non-controlling interest						3			3
Balance at Mar. 31, 2015	$4				$3,372	$3,633	$48		$7,057
Balance, shares at Mar. 31, 2015	384,572,080
Balance, shares at Mar. 31, 2015			1,725,000						1,725,000

Basis_Of_Presentation

Basis Of Presentation	3 Months Ended
	Mar. 31, 2015
Basis Of Presentation [Abstract]
Basis Of Presentation	(1) BASIS OF PRESENTATION
	Southwestern Energy Company (including its subsidiaries, collectively “Southwestern” or the “Company”) is an independent energy company engaged in natural gas and oil exploration, development and production (“E&P”). The Company’s current operations are principally focused within the United States on the development of unconventional reservoirs located in Arkansas, Pennsylvania and West Virginia. The Company’s operations in Arkansas are primarily focused on an unconventional natural gas reservoir known as the Fayetteville Shale, and its operations in northeast Pennsylvania are focused on an unconventional natural gas reservoir known as the Marcellus Shale (herein referred to as “Northeast Appalachia”). Recently, the Company acquired a significant stake in properties located in West Virginia and southwest Pennsylvania. These operations, primarily in West Virginia, are focused on the Marcellus Shale, the Utica and the Upper Devonian unconventional natural gas and oil reservoirs (herein referred to as “Southwest Appalachia”). Collectively, the Company’s properties located in West Virginia and Pennsylvania are herein referred to as the “Appalachian Basin.” To a lesser extent, the Company has exploration and production activities ongoing in Colorado, Louisiana, Texas and elsewhere in the United States. The Company also actively seeks to find and develop new natural gas and oil plays with significant exploration and exploitation potential, which it refers to as “New Ventures,” and to obtain additional reserves through acquisitions. The Company also operates drilling rigs in Arkansas, Pennsylvania and West Virginia, and provides oilfield products and services, principally serving its exploration and production operations. Southwestern’s natural gas gathering and marketing (“Midstream Services”) activities primarily support the Company’s E&P activities in Arkansas, Texas, Louisiana, Pennsylvania and West Virginia.
	The accompanying unaudited condensed consolidated financial statements were prepared using accounting principles generally accepted in the United States of America (“GAAP”) for interim financial information and in accordance with the rules and regulations of the Securities and Exchange Commission. Certain information relating to the Company’s organization and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been appropriately condensed or omitted in this Quarterly Report. The Company believes the disclosures made are adequate to make the information presented not misleading.
	The unaudited condensed consolidated financial statements contained in this report include all normal and recurring material adjustments that, in the opinion of management, are necessary for a fair statement of the financial position, results of operations and cash flows for the interim periods presented herein. It is recommended that these unaudited condensed consolidated financial statements be read in conjunction with the consolidated financial statements and the notes thereto included in the Company’s Annual Report for the year ended December 31, 2014 (“2014 Annual Report”).
	The Company’s significant accounting policies, which have been reviewed and approved by the Audit Committee of the Company’s Board of Directors, are summarized in Note 1 in the Notes to the Consolidated Financial Statements included in the Company’s 2014 Annual Report.
	Certain reclassifications have been made to the prior year financial statements to conform to the 2015 presentation. The effects of the reclassifications were not material to the Company’s unaudited condensed consolidated financial statements.

Acquisitions_And_Divestitures

Acquisitions And Divestitures	3 Months Ended
	Mar. 31, 2015
Acquisitions And Divestitures [Abstract]
Acquisitions And Divestitures	(2)  ACQUISITIONS AND DIVESTITURES
	In April 2015, the Company sold its gathering assets located in Bradford and Lycoming counties in northeastern Pennsylvania to Howard Midstream Energy Partners, LLC for an adjusted sales price of approximately $488 million. The net book value of these assets was $213 million and was held in the Midstream segment as of March 31, 2015.  The assets include approximately 100 miles of natural gas gathering pipeline, with nearly 600 million cubic feet per day of capacity.  The proceeds from the transaction were used to substantially repay borrowings under the Company’s $500 million term loan facility that would have matured in December 2016. The transaction is subject to customary post-closing adjustments.
	In March 2015, the Company announced that it executed an agreement with a private buyer to sell the Company’s conventional oil and gas assets located in East Texas and the Arkoma Basin for approximately $218 million. The net book value of these assets is primarily in the full cost pool and is held in the E&P segment as of March 31, 2015. The proceeds from the transaction will be used to reduce Company debt. The transaction is expected to close in the second quarter of 2015 and is subject to customary closing conditions.
	In January 2015, the Company completed an acquisition of certain oil and gas assets including approximately 46,700 net acres in northeast Pennsylvania from WPX Energy, Inc. for an adjusted purchase price of $288 million, subject to customary post-closing adjustments (the “WPX Property Acquisition”). This acreage was producing approximately 50 million net cubic feet of gas per day from 63 operated horizontal wells as of December 2014. As part of this transaction, the Company assumed firm transportation capacity of 260 million cubic feet of gas per day predominantly on the Millennium pipeline. This transaction was funded with the revolving credit facility and was accounted for as a business combination. The Company allocated approximately $169 million of the purchase price of the WPX Property Acquisition to natural gas and oil properties and approximately $119 million to intangible assets in other current assets and other long-term assets, based on the respective fair values of the assets acquired.
	In January 2015, the Company and Statoil ASA completed an acquisition in which the Company’s subsidiary acquired certain oil and gas assets covering approximately 30,000 acres in West Virginia and southwest Pennsylvania comprising approximately 20% of Statoil’s interests in that acreage for $365 million, subject to customary post-closing adjustments (the “Statoil Property Acquisition”). All of these assets are also assets in which the Company has acquired interests under the Chesapeake Property Acquisition (as defined below). This transaction was funded with the revolving credit facility and was accounted for as a business combination. The Company allocated approximately $365 million of the purchase price to natural gas and oil properties, based on the respective fair values of the assets acquired.
	In December 2014, the Company completed an acquisition of certain oil and gas assets from Chesapeake Energy Corporation covering approximately 413,000 net acres in West Virginia and southwest Pennsylvania targeting natural gas, natural gas liquids (“NGLs”) and crude oil contained in the Upper Devonian, Marcellus and Utica Shales for approximately $5.0 billion, subject to customary post-closing adjustments (the “Chesapeake Property Acquisition”). The transaction was temporarily financed using a $4.5 billion 364-day senior unsecured bridge term loan credit facility and a $500 million two-year unsecured term loan.  The Company repaid all principal and interest outstanding on the $4.5 billion bridge facility in January 2015 after permanent financing was finalized and, as a result, expensed $47 million of short-term unamortized debt issuance costs related to the bridge facility in January 2015 recognized in other interest charges on the unaudited condensed consolidated statement of operations. The term loan facility was repaid in full in April 2015 with proceeds from the divestiture of the Company’s northeastern Pennsylvania gathering assets and borrowings under the revolving credit facility.
	The Chesapeake Property Acquisition qualified as a business combination, and as a result, the Company estimated the fair value of the assets acquired and liabilities assumed as of the December 22, 2014 acquisition date. The fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements also utilize assumptions of market participants. The Company used a discounted cash flow model and made market assumptions as to future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development and operating costs, projections of future rates of production, expected recovery rates and risk adjusted discount rates. These assumptions represent Level 3 inputs, as defined in Note 8 – Fair Value Measurements. The following table summarizes the consideration paid for the Chesapeake Property Acquisition and the fair value of the assets acquired and liabilities assumed as of the acquisition date. The purchase price allocation is preliminary and subject to adjustment. These amounts will be finalized as soon as possible, but no later than December 2015.
	Consideration (in millions):
	Cash	$	4,978
	Recognized amounts of identifiable assets acquired and liabilities assumed:
	Assets acquired:
	Proved natural gas and oil properties		1,424
	Unproved natural gas and oil properties		3,605
	Other property and equipment		19
	Inventory		2
	Other receivables		27
	Total assets acquired		5,077
	Liabilities assumed:
	Asset retirement obligations		-42
	Other long-term liabilities		-57
	Total liabilities assumed		-99
		$	4,978
	Summarized below are the consolidated results of operations for the three months ended March 31, 2014 on an unaudited pro forma basis, as if the acquisition and related permanent debt and equity financing, as finalized in January 2015, had occurred on January 1, 2013. The unaudited pro forma financial information was derived from the historical consolidated statement of operations of the Company and the statement of revenues and direct operating expenses for the Chesapeake Property Acquisition properties. The unaudited pro forma financial information does not purport to be indicative of results of operations that would have occurred had the acquisition and related permanent financing occurred on the basis assumed above, nor is such information indicative of the Company’s expected future results of operations. The unaudited pro-forma financial information excludes the WPX and Statoil Property Acquisitions as the impacts are immaterial.
		For the three months ended
		March 31,
		2014
		(in millions, except per share amounts) (unaudited)
	Revenues	$	1,251
	Net income	$	243
	Earnings per common share:
	Basic	$	0.48
	Diluted	$	0.48
	In the second and third quarters of 2014, the Company completed several acquisitions to purchase approximately 380,000 net acres in northwest Colorado principally in the Niobrara formation for approximately $215 million. The Company utilized its revolving credit facility to finance these acquisitions and accounted for them as asset acquisitions.

Inventory

Inventory	3 Months Ended
	Mar. 31, 2015
Inventory [Abstract]
Inventory	(3) INVENTORY
	Inventory is comprised of natural gas in underground storage and tubular and other equipment. Natural gas in underground storage is carried at the lower of cost or market and accounted for by a weighted average cost method. Tubulars and other equipment are carried at the lower of cost or market and are accounted for by a moving weighted average cost method that is applied within specific classes of inventory items.
	The components of inventory recorded in current assets as of March 31, 2015 and December 31, 2014 consisted of the following:
			March 31,		December 31,
			2015		2014
		(in millions)
	Tubulars and other equipment	$	37	$	33
	Natural gas in underground storage	$	2	$	4

Natural_Gas_And_Oil_Properties

Natural Gas And Oil Properties	3 Months Ended
	Mar. 31, 2015
Natural Gas And Oil Properties [Abstract]
Natural Gas And Oil Properties
	(4) NATURAL GAS AND OIL PROPERTIES
	The Company utilizes the full cost method of accounting for costs related to the exploration, development and acquisition of natural gas and oil reserves. Under this method, all such costs (productive and nonproductive), including salaries, benefits and other internal costs directly attributable to these activities are capitalized on a country by country basis and amortized over the estimated lives of the properties using the units-of-production method. These capitalized costs, less accumulated amortization and related deferred income taxes, are subject to a ceiling test that limits such pooled costs to the aggregate of the present value of future net revenues attributable to proved natural gas and oil reserves discounted at 10% plus the lower of cost or market value of unproved properties. Any costs in excess of the ceiling are written off as a non-cash expense. The expense may not be reversed in future periods, even though higher natural gas and oil prices may subsequently increase the ceiling. Companies using the full cost method must use the average quoted price from the first day of each month from the previous 12 months, including the impact of derivatives qualifying as cash flow hedges, to calculate the ceiling value of their reserves.
	Using the average quoted price from the first day of each month from the previous 12 months for Henry Hub natural gas of $3.88 per MMBtu, West Texas Intermediate oil of  $79.21 per barrel, and NGLs of $16.38 per barrel, adjusted for market differentials, the Company’s net book value of its United States natural gas and oil properties did not exceed the ceiling amount and did not result in a ceiling test impairment at March 31, 2015. Cash flow hedges of natural gas production in place increased the ceiling amount by approximately $45 million as of March 31, 2015.  Decreases in market prices as well as changes in production rates, levels of reserves, evaluation of costs excluded from amortization, future development costs and production costs could result in future ceiling test impairments.
	Using the first-day-of-the-month prices of natural gas for the first four months of 2015 and NYMEX strip prices for the remainder of 2015, as applicable, the prices required to be used to determine the ceiling amount in the Company’s full cost ceiling test are likely to require write-downs in each of the remaining quarters in 2015.
	Using the average quoted price from the first day of each month from the previous 12 months for Henry Hub natural gas of $3.99 per MMBtu, West Texas Intermediate oil of $94.92 per barrel, and NGLs of $43.64 per barrel, adjusted for market differentials, the net book value of its United States natural gas and oil properties did not exceed the ceiling amount and did not result in a ceiling test impairment at March 31, 2014. Cash flow hedges of natural gas production in place increased the ceiling amount by approximately $40 million as of March 31, 2014.
	All of the Company’s costs directly associated with the acquisition and evaluation of properties in Canada relating to its exploration program as of March 31, 2015 were unproved and did not exceed the ceiling amount. If the Company’s exploration program in Canada is terminated or otherwise unsuccessful on all or a portion of the Company’s Canadian assets, including the effects of changes in laws or regulations due to the new government in New Brunswick or otherwise, a ceiling test impairment may result in the future.

Earnings_Per_Share

Earnings Per Share	3 Months Ended
	Mar. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Share	(5) EARNINGS PER SHARE
	Basic earnings per common share is computed by dividing net income (loss) attributable to common stock by the weighted average number of common shares outstanding during each year. The diluted earnings per share calculation adds to the weighted average number of common shares outstanding: the incremental shares that would have been outstanding assuming the exercise of dilutive stock options, the vesting of unvested restricted shares of common stock and performance units and the assumed conversion of mandatory convertible preferred stock. An antidilutive impact is an increase in earnings per share or a reduction in net loss per share resulting from the conversion, exercise, or contingent issuance of certain securities.
	In January 2015, the Company completed concurrent underwritten public offerings of 30,000,000 shares of its common stock and 34,500,000 depositary shares (both share counts include shares issued as a result of the underwriters exercising their options to purchase additional shares). The common stock offering was priced at $23.00 per share. Net proceeds, after underwriting discount and expenses, from the common stock offering were approximately $669 million. Net proceeds, after underwriting discount and expenses, from the depositary share offering were approximately $1.7 billion. Each depositary share represents a 1/20th interest in a share of the Company’s mandatory convertible preferred stock, with a liquidation preference of $1,000 per share (equivalent to a $50 liquidation preference per depositary share). The proceeds from the offerings were used to partially repay borrowings under the Company’s $4.5 billion 364-day bridge facility with the remaining balance of the bridge facility fully repaid with proceeds from the Company’s January 2015 public offering of $2.2 billion in long-term senior notes.
	The mandatory convertible preferred stock entitles the holders to a proportional fractional interest in the rights and preferences of the convertible preferred stock, including conversion, dividend, liquidation and voting rights. Unless converted earlier at the option of the holders, on or around January 15, 2018 each share of convertible preferred stock will automatically convert into between 37.0028 and 43.4782 shares of the Company’s common stock (and, correspondingly, each depositary share will convert into between 1.85014 and 2.17391 shares of the Company’s common stock), subject to customary anti-dilution adjustments, depending on the volume-weighted average price of the Company’s common stock over a 20 trading day averaging period immediately prior to that date.
	The mandatory convertible preferred stock has the non-forfeitable right to participate on an as converted basis at the conversion rate then in effect in any common stock dividends declared and as such, is considered a participating security. As such, it is included in the computation of basic and diluted earnings per share, pursuant to the two-class method. In the calculation of basic earnings per share attributable to common shareholders, participating securities are allocated earnings based on actual dividend distributions received plus a proportionate share of undistributed net income attributable to common shareholders, if any, after recognizing distributed earnings.
	The following table presents the computation of earnings per share for the three month periods ended March 31, 2015 and 2014:
			For the three months ended
			March 31,
			2015			2014
			(in millions, except share/per share amounts)
	Net income	$	78		$	194
	Mandatory convertible preferred stock dividend		25			–
	Net income attributable to shareholders		53			194
	Participating securities - mandatory convertible preferred stock		7			–
	Net income attributable to common stock		46			194
	Number of common shares:
	Weighted average outstanding		375,444,030			351,222,538
	Issued upon assumed exercise of outstanding stock options (1)		–			348,798
	Effect of issuance of non-vested restricted common stock (1)		133,634			349,608
	Effect of issuance of non-vested performance units		390			64,877
	Effect of mandatory convertible preferred stock (2)		–			–
	Weighted average and potential dilutive outstanding		375,578,054			351,985,821
	Earnings per common share:
	Basic	$	0.12		$	0.55
	Diluted	$	0.12		$	0.55
		-1		Options for 3,704,089 shares and 1,916,645 shares of restricted stock were excluded from the calculation for the three months ended March 31, 2015 because they would have had an antidilutive effect.  Options for 1,179,914 shares and 29,688 shares of restricted stock were excluded from the calculation for the three months ended March 31, 2014 because they would have had an antidilutive effect.
		-2		Weighted average common shares issuable upon the assumed conversion of the mandatory convertible preferred stock totaling 58,333,252 shares were excluded from the computation of diluted earnings per share as such conversion would have been antidilutive.

Derivatives_And_Risk_Managemen

Derivatives And Risk Management	3 Months Ended
	Mar. 31, 2015
Derivatives And Risk Management [Abstract]
Derivatives And Risk Management
	(6) DERIVATIVES AND RISK MANAGEMENT
	The Company is exposed to volatility in market prices and basis differentials for natural gas and oil which impacts the predictability of its cash flows related to the sale of natural gas, NGLs and oil. These risks are managed by the Company’s use of certain derivative financial instruments.  As of March 31, 2015 and December 31, 2014, the Company’s derivative financial instruments consisted of fixed price swaps, basis swaps, fixed price call options, and interest rate swaps. A description of the Company’s derivative financial instruments is provided below:
	Fixed price swaps	The Company receives a fixed price for the contract and pays a floating market price to the counterparty.
	Basis swaps	Arrangements that guarantee a price differential for natural gas from a specified delivery point. The Company receives a payment from the counterparty if the price differential is greater than the stated terms of the contract and pays the counterparty if the price differential is less than the stated terms of the contract.
	Fixed price call options	The Company sells fixed price call options in exchange for a premium. At the time of settlement, if the market price exceeds the fixed price of the call option, the Company pays the counterparty such excess on sold fixed price call options. If the market price settles below the fixed price of the call option, no payment is due from either party.
	Interest rate swaps	Interest rate swaps are used to fix or float interest rates on existing or anticipated indebtedness. The purpose of these instruments is to manage the Company’s existing or anticipated exposure to unfavorable interest rate changes.
	All derivatives are recognized in the balance sheet as either an asset or liability and are measured at fair value other than transactions for which normal purchase/normal sale is applied. Certain criteria must be satisfied in order for derivative financial instruments to be classified and accounted for as either a cash flow or a fair value hedge. Accounting for qualifying hedges requires a derivative’s gains and losses to be recorded either in earnings or as a component of other comprehensive income. Gains and losses on derivatives that are not designated for hedge accounting treatment or that do not meet hedge accounting requirements are recorded in earnings as a component of gain (loss) on derivatives. Within the gain (loss) on derivatives component of the statement of operations are gains (losses) on derivatives excluding derivatives, settled and gains (losses) on derivatives, settled. The Company calculates gains (losses) on derivatives, settled, as the summation of gains and losses on positions which have settled within the period.
	The Company utilizes counterparties for its derivative instruments that it believes are credit-worthy at the time the transactions are entered into and the Company closely monitors the credit ratings of these counterparties. Additionally, the Company performs both quantitative and qualitative assessments of these counterparties based on their credit ratings and credit default swap rates where applicable. However, the events in the financial markets in recent years demonstrate there can be no assurance that a counterparty will be able to meet its obligations to the Company.
	The balance sheet classification of the assets related to derivative financial instruments are summarized below as of March 31, 2015 and December 31, 2014:
			Derivative Assets
			31-Mar-15					31-Dec-14
			Balance Sheet Classification		Fair Value			Balance Sheet Classification		Fair Value
			(in millions)
	Derivatives designated as hedging instruments:
	Fixed price swaps		Derivative assets		$	146		Derivative assets		$	165
	Total derivatives designated as hedging instruments				$	146				$	165
	Derivatives not designated as hedging instruments:
	Basis swaps		Derivative assets		$	3		Derivative assets		$	9
	Fixed price swaps		Derivative assets			146		Derivative assets			163
	Basis swaps		Other long-term assets			–		Other long-term assets			1
	Interest rate swaps		Other long-term assets			–		Other long-term assets			1
	Total derivatives not designated as hedging instruments				$	149				$	174
	Total derivative assets				$	295				$	339
			Derivative Liabilities
			31-Mar-15					31-Dec-14
			Balance Sheet Classification		Fair Value			Balance Sheet Classification		Fair Value
			(in millions)
	Derivatives not designated as hedging instruments:
	Basis swaps		Derivative liabilities		$	6		Derivative liabilities		$	4
	Fixed price call options		Derivative liabilities			2		Derivative liabilities			2
	Interest rate swaps		Derivative liabilities			3		Derivative liabilities			3
	Basis swaps		Other long-term liabilities			–		Other long-term liabilities			2
	Fixed price call options		Other long-term liabilities			3		Other long-term liabilities			10
	Interest rate swaps		Other long-term liabilities			3		Other long-term liabilities			2
	Total derivatives not designated as hedging instruments				$	17				$	23
	Total derivative liabilities				$	17				$	23
	As of March 31, 2015, the Company had fixed price swap derivatives designated for hedge accounting and not designated for hedge accounting on the following volumes of natural gas production (in Bcf):
	Year		Fixed price swaps designated for hedge accounting		Fixed price swaps not designated for		Total		Weighted Average Price to be Swapped ($/MMBtu) (1)
					hedge accounting
	2015		91		90		181		$4.40
		-1		The weighted average swap price is $4.40 for each category and in total.
	Cash Flow Hedges
	The reporting of gains and losses on cash flow derivative hedging instruments depends on whether the gains or losses are effective at offsetting changes in the cash flows of the hedged item. The effective portion of the gains and losses on the derivative hedging instruments are recorded in other comprehensive income until recognized in earnings during the period that the hedged transaction takes place. The ineffective portion of the gains and losses from the derivative hedging instrument are recognized in earnings immediately and had an inconsequential impact to the unaudited condensed consolidated statement of operations for the three month periods ended March 31, 2015 and 2014.
	As of March 31, 2015, accumulated other comprehensive income includes a gain related to its hedging activities of $90 million net of a deferred income tax liability of $56 million. The amount included in accumulated other comprehensive income will be relieved over time and recognized in the statement of operations as the physical transactions being hedged occur. Assuming the market prices of natural gas futures as of March 31, 2015 remain unchanged, the Company would expect to transfer an aggregate after-tax net gain of approximately $90 million from accumulated other comprehensive income to earnings during the next 12 months. Gains or losses from derivative instruments designated as cash flow hedges are reflected as adjustments to natural gas sales in the consolidated statements of operations. Volatility in net income, comprehensive income and accumulated other comprehensive income may occur in the future as a result of the Company’s derivative activities.
	The following tables summarize the before tax effect of all cash flow hedges on the unaudited condensed consolidated financial statements for the three month periods ended March 31, 2015 and 2014:
					Gain (Loss) Recognized in
					Other Comprehensive Income
					(Effective Portion)
					For the three months ended
					March 31,
	Derivative Instrument				2015			2014
					(in millions)
	Fixed price swaps				$	24		$	-90
			Classification of Gain (Loss)		Gain (Loss) Reclassified from Accumulated
			Reclassified from		Other Comprehensive Income
			Accumulated Other		into Earnings (Effective Portion)
			Comprehensive Income		For the three months ended
			into Earnings		March 31,
	Derivative Instrument		(Effective Portion)		2015			2014
					(in millions)
	Fixed price swaps		Gas sales		$	42		$	-42
	Other Derivative Contracts
	For other derivative contracts, the gain or loss on the derivative instrument as well as the offsetting gain or loss on the hedged item are recognized in earnings immediately through gain (loss) on derivatives. Although the Company’s basis swaps meet the objective of managing commodity price exposure, these trades are typically not entered into concurrent with the Company’s derivative instruments that qualify as cash flow hedges and therefore do not generally qualify for hedge accounting. Basis swap derivative instruments that are not designated for hedge accounting are recorded on the balance sheet at their fair values under derivative assets, other long-term assets, other current liabilities, and other long-term liabilities, as applicable and all gains and losses related to these contracts are recognized immediately in the unaudited condensed consolidated statement of operations as a component of gain (loss) on derivatives. As of March 31, 2015, the Company had basis swaps on natural gas production that were not designated for hedge accounting of 11 Bcf and 4 Bcf  in 2015 and 2016, respectively.
As of March 31, 2015, the Company had fixed price call options on 151 Bcf and 120 Bcf of natural gas production in 2015 and 2016, respectively, not designated for hedge accounting and fixed price swaps of 90 Bcf of natural gas production in 2015 not designated for hedge accounting.
The Company is a party to interest rate swaps that were entered into to mitigate the Company’s exposure to volatility in interest rates. The interest rate swaps build to a notional amount of $170 million and expire in June 2020. The Company did not designate the interest rate swaps for hedge accounting.  Changes in the fair value of the interest rate swaps are included in gain (loss) on derivatives in the consolidated statements of operations.
The following tables summarize the before tax effect of fixed price swaps, basis swaps, fixed price call options and interest rate swaps not designated for hedge accounting on the condensed consolidated statements of operations for the three month periods ended March 31, 2015 and 2014:
				Gain (Loss) on Derivatives
				Excluding Derivatives, Settled
				Recognized in Earnings
		Consolidated Statement of Operations		For the three months ended
		Classification of Gain (Loss) on		March 31,
Derivative Instrument		Derivatives, Net of Settlement		2015			2014
				(in millions)
Basis swaps		Gain (Loss) on Derivatives		$	-8		$	-10
Fixed price call options		Gain (Loss) on Derivatives		$	8		$	-27
Fixed price swaps		Gain (Loss) on Derivatives		$	-18		$	-23
Interest rate swaps		Gain (Loss) on Derivatives		$	-3		$	-2
				Gain (Loss)
				on Derivatives, Settled (1)
				Recognized in Earnings
		Consolidated Statement of Operations		For the three months ended
		Classification of Gain (Loss)		March 31,
Derivative Instrument		on Derivatives, Settled (1)		2015			2014
				(in millions)
Basis swaps		Gain (Loss) on Derivatives		$	-6		$	-14
Fixed price swaps		Gain (Loss) on Derivatives		$	42		$	-24
Interest rate swaps		Gain (Loss) on Derivatives		$	-1		$	–
	-1		The Company calculates gain (loss) on derivatives, settled, as the summation of gains and losses on positions that have settled within the period reported.

Reclassification_From_Accumula

Reclassification From Accumulated Other Comprehensive Income	3 Months Ended
	Mar. 31, 2015
Reclassification From Accumulated Other Comprehensive Income [Abstract]
Reclassification From Accumulated Other Comprehensive Income	(7) RECLASSIFICATIONS FROM ACCUMULATED OTHER COMPREHENSIVE INCOME
	The following tables detail the components of accumulated other comprehensive income and the related tax effects for the three months ended March 31, 2015:
			For the three months ended
			31-Mar-15
			(in millions) (1)
			Cash Flow Hedges				Pension and Other Postretirement		Foreign Currency		Total
	Beginning balance at December 31, 2014		$	98			$	-24	$	-12	$	62
	Other comprehensive income (loss) before reclassifications			17				–		-6		11
	Amounts reclassified from other comprehensive loss (2)			-25				–		–		-25
	Net current-period other comprehensive loss			-8				–		-6		-14
	Ending balance at March 31, 2015		$	90			$	-24	$	-18	$	48
		-1		All amounts are net of tax.
		-2		See separate table below for details about these reclassifications.
	Details about Accumulated Other Comprehensive Income			Affected Line Item in the Consolidated Statement of Operations		Amount Reclassified from Accumulated Other Comprehensive Income
						For the three months ended
						31-Mar-15
						(in millions)
	Cash flow hedges
	Settlements			Gas Sales	$	-42
				Provision (Benefit) for Income Taxes		17
				Net Income	$	-25
	Total reclassifications for the period			Net Income	$	-25

Fair_Value_Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2015
Fair Value Measurements [Abstract]
Fair Value Measurements
	(8) FAIR VALUE MEASUREMENTS
	The carrying amounts and estimated fair values of the Company’s financial instruments as of March 31, 2015 and December 31, 2014 were as follows:
		31-Mar-15						31-Dec-14
		Carrying			Fair			Carrying			Fair
		Amount			Value			Amount			Value
		(in millions)
	Cash and cash equivalents	$	17		$	17		$	53		$	53
	Credit facility	$	800		$	800		$	300		$	300
	Term loan facility (1)	$	500			500		$	500		$	500
	Bridge facility (2)	$	–			–		$	4,500		$	4,500
	Senior notes	$	3,864		$	3,983		$	1,667		$	1,751
	Derivative instruments, net	$	278		$	278		$	316		$	316
		-1		The term loan facility was repaid in full in April 2015 with proceeds from the divestiture of the Company’s northeastern Pennsylvania gathering assets and borrowings under the revolving credit facility.
		-2		The bridge facility was repaid in full in January 2015 with proceeds from the issuance of $2.2 billion of long-term senior notes and the $2.3 billion issuance of common and preferred stock.
	The carrying values of cash and cash equivalents, accounts receivable, accounts payable, other current assets and current liabilities on the unaudited condensed consolidated balance sheets approximate fair value because of their short-term nature. For debt and derivative instruments, the following methods and assumptions were used to estimate fair value:
	Debt: The fair values of the Company’s senior notes were based on the market of the Company’s publicly traded debt as determined based on the yield of the Company’s senior notes.
	The carrying values of the borrowings under the Company’s unsecured revolving credit facility and term loan facility approximate fair value because the interest rate is variable and reflective of market rates. The Company considers the fair value of its debt to be a Level 2 measurement on the fair value hierarchy.
	Derivative Instruments: The fair value of all derivative instruments is the amount at which the instrument could be exchanged currently between willing parties. The amounts are based on quoted market prices, best estimates obtained from counterparties and an option pricing model, when necessary, for price option contracts.
	The fair value hierarchy prioritizes the inputs to valuation techniques used to measure fair value. As presented in the tables below, this hierarchy consists of three broad levels:
	Level 1 valuations - Consist of unadjusted quoted prices in active markets for identical assets and liabilities and have the highest priority.
	Level 2 valuations - Consist of quoted market information for the calculation of fair market value.
	Level 3 valuations - Consist of internal estimates and have the lowest priority.
	The Company has classified its derivatives into these levels depending upon the data utilized to determine their fair values. The Company’s fixed price swaps (Level 2) are estimated using third-party discounted cash flow calculations using the NYMEX futures index. The Company utilized discounted cash flow models for valuing its interest rate derivatives (Level 2). The net derivative values attributable to the Company's interest rate derivative contracts as of March 31, 2015 are based on (i) the contracted notional amounts, (ii) active market-quoted London Interbank Offered Rate (“LIBOR”) yield curves and (iii) the applicable credit-adjusted risk-free rate yield curve. The Company’s fixed price call options (Level 3) are valued using the Black-Scholes model, an industry standard option valuation model that takes into account inputs such as contract terms, including maturity, and market parameters, including assumptions of the NYMEX futures index, interest rates, volatility and credit worthiness.  The Company’s basis swaps (Level 3) are estimated using third-party cash flow calculations based upon forward commodity price curves.
	Inputs to the Black-Scholes model, including the volatility input, which is the significant unobservable input for Level 3 fair value measurements, are obtained from a third-party pricing source, with independent verification of the most significant inputs on a monthly basis. An increase (decrease) in volatility would result in an increase (decrease) in fair value measurement, respectively. However, such changes would not have a significant impact.
	Assets and liabilities measured at fair value on a recurring basis are summarized below (in millions):
			31-Mar-15
			Fair Value Measurements Using:
			Quoted Prices			Significant Other Observable Inputs			Significant Unobservable Inputs			Assets (Liabilities)
			In Active Markets
			(Level 1)			(Level 2)			(Level 3)			at Fair Value
	Fixed price swap assets		$	–		$	292		$	–		$	292
	Basis swap assets			–			–			3			3
	Interest rate swap liabilities			–			-6			–			-6
	Basis swap liabilities			–			–			-6			-6
	Fixed price call option liabilities			–			–			-5			-5
	Total		$	–		$	286		$	-8		$	278
			31-Dec-14
			Fair Value Measurements Using:
			Quoted Prices			Significant
			in Active			Other			Significant
			Markets			Observable Inputs			Unobservable Inputs			Assets (Liabilities)
			(Level 1)			(Level 2)			(Level 3)			at Fair Value
	Fixed price swap assets		$	–		$	328		$	–		$	328
	Interest rate swap assets			–			1			–			1
	Basis swap assets			–			–			10			10
	Interest rate swap liabilities			–			-5			–			-5
	Basis swap liabilities			–			–			-6			-6
	Fixed price call option liabilities			–			–			-12			-12
	Total		$	–		$	324		$	-8		$	316
	The table below presents reconciliations for the change in net fair value of derivative assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3) for the three month period ended March 31, 2015 and March 31, 2014. The fair values of Level 3 derivative instruments are estimated using proprietary valuation models that utilize both market observable and unobservable parameters. Level 3 instruments presented in the table consist of net derivatives valued using pricing models incorporating assumptions that, in the Company’s judgment, reflect reasonable assumptions a marketplace participant would have used as of March 31, 2015 and March 31, 2014.
			For the three months ended
			March 31,
			2015			2014
			(in millions)
	Balance at beginning of period		$	-8		$	-19
	Total gains (losses):
	Included in earnings			-6			-51
	Included in other comprehensive income			–			–
	Purchases, issuances, and settlements:
	Purchases			–			–
	Issuances			–			–
	Settlements			6			14
	Transfers into/out of Level 3			–			–
Balance at end of period		$	-8		$	-56
Change in losses included in earnings relating to derivatives still held as of March 31		$	–		$	-37

Debt

Debt	3 Months Ended
	Mar. 31, 2015
Debt [Abstract]
Debt	(9) DEBT
	The components of debt as of March 31, 2015  and December 31, 2014 consisted of the following:
			March 31,		December 31,
			2015		2014
			(in millions)
	Short-term debt:
	7.15% Senior Notes due 2018		$	1	$	1
	Variable rate (1.515% at December 31, 2014) bridge facility, due December 2015 (1)			–		4,500
	Total short-term debt			1		4,501
	Long-term debt:
	Variable rate (1.673% and 1.515% at March 31, 2015 and December 31, 2014, respectively) unsecured revolving credit facility			800		300
	Variable rate (1.680% and 1.545% at March 31, 2015 and December 31, 2014, respectively) term loan facility, due December 2016 (2)			500		500
	7.35% Senior Notes due 2017			15		15
	7.125% Senior Notes due 2017			25		25
	7.15% Senior Notes due 2018			27		27
	3.3% Senior Notes due 2018			350		–
	7.5% Senior Notes due 2018			600		600
	4.05% Senior Notes due 2020			850		–
	4.10% Senior Notes due 2022			1,000		1,000
	4.95% Senior Notes due 2025			1,000		–
	Unamortized discount			-4		-1
	Total long-term debt			5,163		2,466
	Total debt		$	5,164	$	6,967
		-1		The bridge facility was repaid in full in January 2015 with proceeds from the issuance of $2.2 billion of long-term senior notes and $2.3 billion of common and preferred stock.
		-2		The term loan facility was repaid in full in April 2015 with proceeds from the divestiture of the Company’s northeastern Pennsylvania gathering assets and borrowings under the revolving credit facility.
	Public Offering of Senior Notes
	In January 2015, the Company completed a public offering of $350 million aggregate principal amount of its 3.30% senior notes due 2018 (the “2018 Notes”), $850 million aggregate principal amount of its 4.05% senior notes due 2020 (the “2020 Notes”) and $1 billion aggregate principal amount of its 4.95% senior notes due 2025 (the “2025 Notes”), with net proceeds from the offering totaling approximately $2.2 billion after underwriting discounts and offering expenses. The Notes were sold to the public at a price of 99.949% of their face value for the 2018 Notes, 99.897% of their face value for the 2020 Notes and 99.782% of their face value for the 2025 Notes. The proceeds from this offering were used to repay the remaining principal and interest outstanding under the Company’s $4.5 billion 364-day bridge term loan facility, which was first reduced with proceeds from the Company’s concurrent underwritten public offerings of common and preferred stock, and were also used to repay a portion of amounts outstanding under the Company’s revolving credit facility. As a result of this repayment, the Company expensed $47 million of short-term unamortized debt issuance costs related to the bridge facility in January 2015 recognized in other interest charges on the unaudited condensed consolidated statement of operations for the three months ended March 31, 2015.
	Credit and Term Facilities
	On December 19, 2014, the Company entered into a $500 million unsecured two-year term loan credit agreement with various lenders. The term loan facility, prior to its termination, required prepayment under certain circumstances from the net cash proceeds of sales of equity or certain assets and borrowings outside the ordinary course of business. The term loan facility was repaid in full in April 2015 with proceeds from the divestiture of the Company’s northeast Pennsylvania gathering assets and borrowings under the Company’s revolving credit facility.  The revolving credit facility provides a borrowing capacity of up to $2.0 billion and matures in December 2018, with options for two one-year extensions with participating lender approval.  The amount available under the revolving credit facility may be increased by  $500  million upon the Company’s agreement with its participating lenders. The interest rates on the revolving credit and term loan facility are calculated based upon the Company’s credit rating and are currently 150 basis points over the current LIBOR as of March 31, 2015. The revolving credit facility is, and term loan facility was, unsecured and are not guaranteed by any subsidiaries of the Company. The revolving credit facility contains, and term loan facility contained, covenants imposing certain restrictions on the Company, including a financial covenant under which Southwestern may not issue total debt in excess of 60% of its total adjusted book capital. This financial covenant with respect to capitalization percentages excludes the effects of any full cost ceiling impairments (after December 31, 2011), certain hedging activities and the Company’s pension and other postretirement liabilities. As of March 31, 2015,  the Company was in compliance with the covenants of its revolving credit facility, term loan facility and other debt agreements.

Commitments_And_Contingencies

Commitments And Contingencies	3 Months Ended
	Mar. 31, 2015
Commitments And Contingencies [Abstract]
Commitments And Contingencies
	(10) COMMITMENTS AND CONTINGENCIES
	Operating Commitments and Contingencies
	In the first quarter of 2010, the Company was awarded exclusive licenses by the Province of New Brunswick in Canada to conduct an exploration program covering approximately 2.5 million acres in the province. The licenses require the Company to make certain capital investments in New Brunswick of approximately $47 million Canadian dollars in the aggregate over the license periods. In order to obtain the licenses, the Company provided promissory notes payable on demand to the Minister of Finance of the Province of New Brunswick with an aggregate principal amount of $45 million Canadian dollars. The promissory notes secure the Company’s capital expenditure obligations under the licenses and are returnable to the Company to the extent the Company performs such obligations. If the Company fails to fully perform, the Minister of Finance may retain a portion of the applicable promissory notes in an amount equal to any deficiency. The Company commenced its Canada exploration program in 2010 and, as of March 31, 2015 has invested $45 million Canadian dollars, or $44 million US dollars, in New Brunswick towards the Company’s commitment, fully covering the promissory notes held by the Province of New Brunswick. No liability has been recognized in connection with the promissory notes due to the Company’s investments in New Brunswick as of March 31, 2015 and its future investment plans. In December 2014, New Brunswick’s provincial government announced its intent to impose a moratorium on hydraulic fracturing in the province, and, on March 27, 2015, the provincial legislature approved enabling legislation. The Company has been granted an extension of its licenses through March 2016. The provincial government has announced a list of conditions that must be met before the moratorium can be lifted, but because these conditions are subjective and the government has discretion whether to grant an extension, the Company cannot predict the duration of the moratorium or whether it will be granted any other extension. Unless and until the moratorium is lifted, the Company will not be able to continue with its program in New Brunswick. If future extensions are not granted before the moratorium is lifted or the Company can complete its program, the Company may be required to write off its investment.
	As of March 31, 2015, the Company’s obligations for demand and similar charges under the firm transportation agreements and gathering agreements totaled approximately $5.7 billion and it has guarantee obligations of up to $261 million of that amount.
	Environmental Risk
	The Company is subject to laws and regulations relating to the protection of the environment. Environmental and cleanup related costs of a non-capital nature are accrued when it is both probable that a liability has been incurred and when the amount can be reasonably estimated. Management believes any future remediation or other compliance related costs will not have a material effect on the financial position or reported results of operations of the Company.
	Litigation
	The Company is subject to laws and regulations relating to the protection of the environment. The Company’s policy is to accrue environmental and cleanup related costs of a non-capital nature when it is both probable that a liability has been incurred and when the amount can be reasonably estimated. Management believes any future remediation or other compliance related costs will not have a material effect on our financial position, results of operations, and cash flows.
	Tovah Energy
	In February 2009, one of the Company’s subsidiaries was added as a defendant in a case then styled Tovah Energy, LLC and Toby Berry-Helfand v. David Michael Grimes, et, al., pending in the 273rd District Court in Shelby County, Texas. By the time of trial in December 2010, Ms. Berry-Helfand (the only remaining plaintiff) alleged that, in 2005, she provided our subsidiary with proprietary data regarding two prospects in the James Lime formation pursuant to a confidentiality agreement and that the Company’s subsidiary refused to return the proprietary data to the plaintiff, subsequently acquired leases based upon such proprietary data and profited therefrom. Among other things, she alleged various statutory and common law claims, including, but not limited to, claims of misappropriation of trade secrets, violation of the Texas Theft Liability Act, breach of fiduciary duty and confidential relationships, various fraud based claims and breach of contract, including a claim of breach of a purported right of first refusal on all interests acquired by our subsidiary between February 2005 and February 2006. She also sought disgorgement of the Company’s subsidiary’s profits. A former associate of the plaintiff intervened in the matter claiming to have helped develop the prospect years earlier.
	The jury found in favor of the plaintiff and the intervenor with respect to all of the statutory and common law claims and awarded $11 million in compensatory damages but no special, punitive or other damages. Separately, the jury determined that the Company’s subsidiary’s profits for purposes of disgorgement, if ordered as a remedy, were $382 million. (Disgorgement of profits is an equitable remedy determined by the judge, and it is within the judge’s discretion to award none, some or all of unlawfully obtained profits.) In August 2011, a judgment was entered pursuant to which the plaintiff and the intervenor were entitled to recover approximately $11 million in actual damages and approximately $24 million in disgorgement as well as prejudgment interest and attorneys’ fees, which currently are estimated to be up to $9 million, and all costs of court of the plaintiff and intervenor.
	Both sides appealed and in July 2013, the Tyler Court of Appeals ordered that (1) the judgment awarding the plaintiff and the intervenor $24 million as disgorgement of illicit gains be reversed and judgment rendered that they take nothing, (2) the award of $11 million for actual damages, insofar as it is based on the jury’s findings of breach of fiduciary duty, fraud, breach of contract, and theft of trade secret is reversed and judgment rendered that the plaintiff and the intervenor take nothing under those theories of recovery, (3) the award of $11 million to the plaintiff and the intervenor as damages for misappropriation of trade secret is affirmed, (4) the case be remanded to the trial court for a determination and award of attorney’s fees for the Company’s subsidiary as the prevailing party under the Texas Theft Liability Act, and (5) in all other respects, the judgment is affirmed. All parties petitioned for rehearing. The Tyler Court of Appeals denied rehearing in November 2013.
	The Company’s subsidiary filed a petition for review in the Supreme Court of Texas in February 2014. The plaintiff and the intervenor filed a cross-petition for review in April 2014, but conditioned their filing on the court’s granting the Company’s subsidiary’s petition for review; i.e., if the court denies the Company’s subsidiary’s petition for review, then the plaintiff and the intervenor are not seeking further review of the court of appeals’ judgment. In October 2014, the Supreme Court requested full briefing on the merits of the case, which is expected to be completed in May 2015. Based on the Company’s understanding and judgment of the facts and merits of this case, including appellate matters, and after considering the advice of counsel, the Company has determined that, although reasonably possible, a materially adverse final outcome to this action is not probable. As such, the Company has not accrued any amounts with respect to this action. If the Supreme Court declines to rule on the case or affirms all aspects of the court of appeals’ judgment, then the Company’s subsidiary would owe the $11 million in damages, plus interest and attorneys fees, offset by any award of attorneys’ fees for its prevailing on the theft count. The Company’s assessment may change in the future due to occurrence of certain events, such as the result of the petitions for review at the Supreme Court of Texas, and such a re-assessment could lead to the determination that the potential liability is probable and could be material to the Company’s results of operations, financial position or cash flows.
	Arkansas Royalty Litigation
	Certain of the Company’s subsidiaries are defendants in three cases, two filed in Arkansas state court in 2010 and 2013 and one in federal court in 2014, on behalf of putative classes of royalty owners on some of our leases located in Arkansas. The chief complaint in all three cases is that one of the Company’s subsidiaries underpaid the royalty owners by, among other things, deducting from royalty payments costs for gathering, transportation, and compression of natural gas in excess of what is permitted by the relevant leases. The Company’s subsidiaries removed the two cases filed in state court to federal court, but both were remanded to state court. In September and October 2014 the judges in the two Arkansas state actions entered orders certifying classes of royalty owners who are citizens of Arkansas. The Company’s subsidiaries are appealing those orders. Discovery regarding the plaintiffs’ theories of liability and amount of claimed damages is in the very early stages. Management believes that the deductions from royalty payments as calculated are permitted and intends to defend the cases vigorously. The Company’s assessment may change in the future due to the occurrence of certain events, such as adverse judgments, and such a re-assessment could lead to the determination that the potential liability is probable and could be material to the Company’s results of operations, financial position or cash flows.
	Other
	The Company is subject to various other litigation, claims and proceedings that have arisen in the ordinary course of business, such as for alleged breaches of contract, miscalculation of royalties, and pollution, contamination or nuisance. Management believes that such litigation, claims and proceedings, individually or in aggregate and after taking into account insurance, are not likely to have a material adverse impact on the Company’s financial position, results of operations or cash flows. Many of these matters are in early stages, so the allegations and the damage theories have not been fully developed, and are all subject to inherent uncertainties; therefore, Management’s view may change in the future. If an unfavorable final outcome were to occur, there exists the possibility of a material impact on the Company’s financial position, results of operations or cash flows for the period in which the effect becomes reasonably estimable. The Company accrues for such items when a liability is both probable and the amount can be reasonably estimated.
	Indemnifications
	The Company provides certain indemnifications in relation to dispositions of assets.  These indemnifications typically relate to disputes, litigation or tax matters existing at the date of disposition. No liability has been recognized in connection with these indemnifications.

Pension_Plan_And_Other_Postret

Pension Plan And Other Postretirement Benefits	3 Months Ended
	Mar. 31, 2015
Pension Plan And Other Postretirement Benefits [Abstract]
Pension Plan And Other Postretirement Benefits	(11) PENSION PLAN AND OTHER POSTRETIREMENT BENEFITS
	The Company has defined pension and postretirement benefit plans which cover substantially all of the Company’s employees. Net periodic pension costs include the following components for the three  months ended March 31, 2015 and 2014:
		Pension Benefits
		For the three months ended
		March 31,
		2015		2014
		(in millions)
	Service cost	$	4	$	3
	Interest cost		1		1
	Expected return on plan assets		-2		-1
	Amortization of prior service cost		–		–
	Amortization of net loss		1		–
	Net periodic benefit cost	$	4	$	3
	The Company’s postretirement benefit plan had a net periodic benefit cost of $1 million as of each of the three month periods ended March 31, 2015 and 2014. As of March 31, 2015, the Company has contributed $3 million to the pension plan and expects to contribute an additional $9 million to the pension plan in 2015.
	The Company maintains a non-qualified deferred compensation supplemental retirement savings plan (“Non-Qualified Plan”) for certain key employees who may elect to defer and contribute a portion of their compensation, as permitted by the plan. Shares of the Company’s common stock purchased under the terms of the Non-Qualified Plan are presented as treasury stock and totaled 13,893 shares at March 31, 2015 compared to 11,055 shares at December 31, 2014.

StockBased_Compensation

Stock-Based Compensation	3 Months Ended
	Mar. 31, 2015
Stock-Based Compensation [Abstract]
Stock-Based Compensation	(12) STOCK-BASED COMPENSATION
	The Company recognized the following amounts in employee stock-based compensation costs for the three months ended March 31, 2015 and 2014:
			For the three months ended
			March 31,
			2015			2014
			(in millions)
	Stock-based compensation cost  –  expensed		$	6		$	4
	Stock-based compensation cost – capitalized		$	5		$	5
	As of March 31, 2015, there was $106 million of total unrecognized compensation cost related to the Company’s unvested stock option grants, restricted stock grants, and performance units. This cost is expected to be recognized over a weighted-average period of 3 years.
	The following table summarizes stock option activity for the three months ended March 31, 2015 and provides information for options outstanding and options exercisable as of March 31, 2015:
					Weighted
					Average
			Number		Exercise
			of Options		Price
			(in thousands)
	Outstanding at December 31, 2014		3,622		$	35.41
	Granted		223			26.35
	Exercised		–			–
	Forfeited or expired		-2			36.50
	Outstanding at March 31, 2015		3,843			34.89
	Exercisable at March 31, 2015		2,277		$	36.13
	The following table summarizes restricted stock activity for the three months ended March 31, 2015 and provides information for unvested shares as of March 31, 2015:
					Weighted
					Average
			Number		Grant Date
			of Shares		Fair Value
			(in thousands)
	Unvested shares at December 31, 2014		2,376		$	34.00
	Granted		97			26.27
	Vested		-7			35.57
	Forfeited		-17			34.02
	Unvested shares at March 31, 2015		2,449		$	33.68
	The following table summarizes performance unit activity to be paid out in Company stock for the three months ended March 31, 2015 and provides information for unvested units as of March 31, 2015. The performance units include a market condition based on Relative Total Shareholder Return (“TSR”) and a performance condition based on the Company's Present Value Index (“PVI”), collectively the “Performance Measures”. The fair value of the TSR market condition of the performance units is based on a Monte Carlo model and is amortized to compensation expense on a straight-line basis over the vesting period of the award. The fair value of the PVI performance condition of the performance units is based on the economic analysis for each investment opportunity based upon the expected present value added for each dollar to be invested and amortized to compensation expense on a straight line basis over the vesting period of the award. The grant date fair value is calculated using the Performance Measures and the closing price of the Company’s common stock at the grant date.
					Weighted
					Average
			Number		Grant Date
			of Units (1)		Fair Value
			(in thousands)
	Unvested units at December 31, 2014		223		$	40.44
	Granted		443			35.22
	Unvested units at March 31, 2015		666		$	36.97
		-1		These amounts reflect the number of performance units granted in thousands. The actual payout of shares may range from a minimum of zero shares to a maximum of two shares contingent upon the actual performance against the Performance Measures.
	Liability-Classified Performance Units
	Certain employees were provided performance units vesting equally over three years.  The payout of these units is based on certain metrics, such as total shareholder return and reserve replacement efficiency, compared to a predetermined group of peer companies and Company goal.  At the end of each performance period, the value of the vested performance units, if any, is paid in cash.  As of March 31, 2015 and December 31, 2014, the Company’s liability under the performance unit agreements was $26 million and $51 million, respectively.

Segment_Information

Segment Information	3 Months Ended
	Mar. 31, 2015
Segment Information [Abstract]
Segment Information
	(13) SEGMENT INFORMATION
	The Company’s reportable business segments have been identified based on the differences in products or services provided. Revenues for the E&P segment are derived from the production and sale of natural gas and liquids. The Midstream Services segment generates revenue through the marketing of both Company and third-party produced natural gas volumes and through gathering fees associated with the transportation of natural gas to market.
	Summarized financial information for the Company’s reportable segments is shown in the following table. The accounting policies of the segments are the same as those described in Note 1 of the Notes to Consolidated Financial Statements included in Item 8 of the 2014 Annual Report. Management evaluates the performance of its segments based on operating income, defined as operating revenues less operating costs. Income before income taxes, for the purpose of reconciling the operating income amount shown below to consolidated income before income taxes, is the sum of operating income, interest expense, and other income (loss). The “Other” column includes items not related to the Company’s reportable segments including real estate and corporate items.
			Exploration
			and		Midstream
			Production		Services		Other			Total
			(in millions)
	Three months ended March 31, 2015:
	Revenues from external customers		$	660	$	273	$	–		$	933
	Intersegment revenues			-5		665		1			661
	Operating income (loss)			78		88		-1			165
	Other loss			-1		–		–			-1
	Gain (loss) on derivatives			15		–		-1			14
	Depreciation, depletion and amortization			278		15		–			293
	Interest expense (1)			45		7		-1			51
	Provision for income taxes (1)			18		31		–			49
	Assets			13,703		1,616		268	-2		15,587
	Capital investments (3)			1,030		138		3			1,171
	Three months ended March 31, 2014:
	Revenues from external customers		$	796	$	317	$	–		$	1,113
	Intersegment revenues			6		913		–			919
	Operating income			352		83		–			435
	Other income (loss), net			2		–		-1			1
	Loss on derivatives			-100		–		–			-100
	Depreciation, depletion and amortization			211		14		–			225
	Interest expense (1)			9		4		–			13
	Provision for income taxes (1)			98		31		–			129
	Assets			6,621		1,544		258	-2		8,423
	Capital investments (3)			499		39		4			542
		-1		Interest expense and the provision for income taxes by segment are allocated as they are incurred at the corporate level.
		-2		Other assets represent corporate assets not allocated to segments and assets for non reportable segments.
		-3		Capital investments includes an immaterial increase and $6 million increase for the three month periods ended March 31, 2015 and 2014, respectively, relating to the change in accrued expenditures between periods.  E&P capital for the three months ended March 31, 2015 includes approximately $534 million related to the WPX and Statoil Property Acquisitions. Midstream capital for the three months ended March 31, 2015 includes approximately $119 million of firm transport associated with the WPX Property Acquisition.
	Included in intersegment revenues of the Midstream Services segment are $576 million and $824 million for the three months ended March 31, 2015 and 2014, respectively, for marketing of the Company’s E&P sales. Corporate assets include cash and cash equivalents, furniture and fixtures, prepaid debt and other costs. Corporate general and administrative costs, depreciation expense and taxes other than income are allocated to the segments. At March 31, 2015, E&P segment assets included $71 million and at March 31, 2014, E&P segment assets included $80 million related to the Company’s activities in Canada.

New_Accounting_Pronouncements_

New Accounting Pronouncements Not Yet Adopted	3 Months Ended
	Mar. 31, 2015
New Accounting Pronouncements Not Yet Adopted [Abstract]
New Accounting Pronouncements Not Yet Adopted	(14)  NEW ACCOUNTING PRONOUNCEMENTS NOT YET ADOPTED
	In November 2014, the FASB issued Accounting Standards Update No. 2014-16, Derivatives and Hedging – Determining Whether the Host Contract in a Hybrid Financial Instrument Issued in the Form of a Share Is More Akin to Debt or to Equity (Subtopic 815-15) (“Update 2014-16”), addresses diversity in practice related to the determination of whether derivative features embedded in hybrid instruments issued in the form of a share should be bifurcated and accounted for separately. For public entities, Update 2014-16 is effective for annual reporting periods beginning after December 15, 2015 including interim periods within that reporting period. The Company is currently evaluating the provisions of Update 2014-16 and assessing the impact, if any, it may have on its consolidated results of operations, financial position or cash flows.
	In April 2015, the FASB issued Accounting Standards Update No. 2015-03, Interest-Imputation of Interest (Subtopic 835-30) (“Update 2015-03”), which seeks to simplify presentation of debt issuance costs. Update 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this Update. Entities should apply the amendments in Update 2015-03 on a retrospective basis, wherein the balance sheet of each individual period presented should be adjusted to reflect the period-specific effects of applying the new guidance. For public entities, Update 2015-03 is effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period. The Company is currently evaluating the provisions of Update 2015-03 and assessing the impact, if any, it may have on its consolidated results of operations, financial position or cash flows.

Acquisitions_And_Divestitures_

Acquisitions And Divestitures (Tables) (Chesapeake Property Acquisition [Member])	3 Months Ended
	Mar. 31, 2015
Chesapeake Property Acquisition [Member]
Business Acquisition [Line Items]
Summary Of Consideration Paid And Fair Value Of Assets Acquired And Liabilities Assumed
	Consideration (in millions):
	Cash	$	4,978
	Recognized amounts of identifiable assets acquired and liabilities assumed:
	Assets acquired:
	Proved natural gas and oil properties		1,424
	Unproved natural gas and oil properties		3,605
	Other property and equipment		19
	Inventory		2
	Other receivables		27
	Total assets acquired		5,077
	Liabilities assumed:
	Asset retirement obligations		-42
	Other long-term liabilities		-57
	Total liabilities assumed		-99
		$	4,978
Summary Of Consolidated Results Of Operations On Pro Forma Basis
		For the three months ended
		March 31,
		2014
		(in millions, except per share amounts) (unaudited)
	Revenues	$	1,251
	Net income	$	243
	Earnings per common share:
	Basic	$	0.48
	Diluted	$	0.48

Inventory_Tables

Inventory (Tables)	3 Months Ended
	Mar. 31, 2015
Inventory [Abstract]
Components Of Inventory
			March 31,		December 31,
			2015		2014
		(in millions)
	Tubulars and other equipment	$	37	$	33
	Natural gas in underground storage	$	2	$	4

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	3 Months Ended
	Mar. 31, 2015
Earnings Per Share [Abstract]
Schedule Of Earnings Per Share
			For the three months ended
			March 31,
			2015			2014
			(in millions, except share/per share amounts)
	Net income	$	78		$	194
	Mandatory convertible preferred stock dividend		25			–
	Net income attributable to shareholders		53			194
	Participating securities - mandatory convertible preferred stock		7			–
	Net income attributable to common stock		46			194
	Number of common shares:
	Weighted average outstanding		375,444,030			351,222,538
	Issued upon assumed exercise of outstanding stock options (1)		–			348,798
	Effect of issuance of non-vested restricted common stock (1)		133,634			349,608
	Effect of issuance of non-vested performance units		390			64,877
	Effect of mandatory convertible preferred stock (2)		–			–
	Weighted average and potential dilutive outstanding		375,578,054			351,985,821
	Earnings per common share:
	Basic	$	0.12		$	0.55
	Diluted	$	0.12		$	0.55
		-1		Options for 3,704,089 shares and 1,916,645 shares of restricted stock were excluded from the calculation for the three months ended March 31, 2015 because they would have had an antidilutive effect.  Options for 1,179,914 shares and 29,688 shares of restricted stock were excluded from the calculation for the three months ended March 31, 2014 because they would have had an antidilutive effect.
		-2		Weighted average common shares issuable upon the assumed conversion of the mandatory convertible preferred stock totaling 58,333,252 shares were excluded from the computation of diluted earnings per share as such conversion would have been antidilutive.

Derivatives_And_Risk_Managemen1

Derivatives And Risk Management (Tables)	3 Months Ended
	Mar. 31, 2015
Derivatives And Risk Management [Abstract]
Balance Sheet Classification Of Derivative Financial Instruments
			Derivative Assets
			31-Mar-15					31-Dec-14
			Balance Sheet Classification		Fair Value			Balance Sheet Classification		Fair Value
			(in millions)
	Derivatives designated as hedging instruments:
	Fixed price swaps		Derivative assets		$	146		Derivative assets		$	165
	Total derivatives designated as hedging instruments				$	146				$	165
	Derivatives not designated as hedging instruments:
	Basis swaps		Derivative assets		$	3		Derivative assets		$	9
	Fixed price swaps		Derivative assets			146		Derivative assets			163
	Basis swaps		Other long-term assets			–		Other long-term assets			1
	Interest rate swaps		Other long-term assets			–		Other long-term assets			1
	Total derivatives not designated as hedging instruments				$	149				$	174
	Total derivative assets				$	295				$	339
			Derivative Liabilities
			31-Mar-15					31-Dec-14
			Balance Sheet Classification		Fair Value			Balance Sheet Classification		Fair Value
			(in millions)
	Derivatives not designated as hedging instruments:
	Basis swaps		Derivative liabilities		$	6		Derivative liabilities		$	4
	Fixed price call options		Derivative liabilities			2		Derivative liabilities			2
	Interest rate swaps		Derivative liabilities			3		Derivative liabilities			3
	Basis swaps		Other long-term liabilities			–		Other long-term liabilities			2
	Fixed price call options		Other long-term liabilities			3		Other long-term liabilities			10
	Interest rate swaps		Other long-term liabilities			3		Other long-term liabilities			2
	Total derivatives not designated as hedging instruments				$	17				$	23
	Total derivative liabilities				$	17				$	23
Schedule Of Derivative Instruments, Volumes Of Natural Gas Production
	Year		Fixed price swaps designated for hedge accounting		Fixed price swaps not designated for		Total		Weighted Average Price to be Swapped ($/MMBtu) (1)
					hedge accounting
	2015		91		90		181		$4.40
		-1		The weighted average swap price is $4.40 for each category and in total.
Summary Of Before Tax Effect Of Cash Flow Hedges On Consolidated Financial Statements
					Gain (Loss) Recognized in
					Other Comprehensive Income
					(Effective Portion)
					For the three months ended
					March 31,
	Derivative Instrument				2015			2014
					(in millions)
	Fixed price swaps				$	24		$	-90
			Classification of Gain (Loss)		Gain (Loss) Reclassified from Accumulated
			Reclassified from		Other Comprehensive Income
			Accumulated Other		into Earnings (Effective Portion)
			Comprehensive Income		For the three months ended
			into Earnings		March 31,
	Derivative Instrument		(Effective Portion)		2015			2014
					(in millions)
	Fixed price swaps		Gas sales		$	42		$	-42
Summary Of Before Tax Effect Of Fair Value Hedges Not Designated For Hedge Accounting
					Gain (Loss) on Derivatives
					Excluding Derivatives, Settled
					Recognized in Earnings
			Consolidated Statement of Operations		For the three months ended
			Classification of Gain (Loss) on		March 31,
	Derivative Instrument		Derivatives, Net of Settlement		2015			2014
					(in millions)
	Basis swaps		Gain (Loss) on Derivatives		$	-8		$	-10
	Fixed price call options		Gain (Loss) on Derivatives		$	8		$	-27
	Fixed price swaps		Gain (Loss) on Derivatives		$	-18		$	-23
	Interest rate swaps		Gain (Loss) on Derivatives		$	-3		$	-2
					Gain (Loss)
					on Derivatives, Settled (1)
					Recognized in Earnings
			Consolidated Statement of Operations		For the three months ended
			Classification of Gain (Loss)		March 31,
	Derivative Instrument		on Derivatives, Settled (1)		2015			2014
					(in millions)
	Basis swaps		Gain (Loss) on Derivatives		$	-6		$	-14
	Fixed price swaps		Gain (Loss) on Derivatives		$	42		$	-24
	Interest rate swaps		Gain (Loss) on Derivatives		$	-1		$	–
		-1		The Company calculates gain (loss) on derivatives, settled, as the summation of gains and losses on positions that have settled within the period reported.

Reclassification_From_Accumula1

Reclassification From Accumulated Other Comprehensiv Income (Tables)	3 Months Ended
	Mar. 31, 2015
Reclassification From Accumulated Other Comprehensive Income [Abstract]
Components Of Accumulated Other Comprehensive Income (Loss)
			For the three months ended
			31-Mar-15
			(in millions) (1)
			Cash Flow Hedges				Pension and Other Postretirement		Foreign Currency		Total
	Beginning balance at December 31, 2014		$	98			$	-24	$	-12	$	62
	Other comprehensive income (loss) before reclassifications			17				–		-6		11
	Amounts reclassified from other comprehensive loss (2)			-25				–		–		-25
	Net current-period other comprehensive loss			-8				–		-6		-14
	Ending balance at March 31, 2015		$	90			$	-24	$	-18	$	48
		-1		All amounts are net of tax.
		-2		See separate table below for details about these reclassifications.
Amounts Reclassified From Accumulated Other Comprehensive Income (Loss)
	Details about Accumulated Other Comprehensive Income			Affected Line Item in the Consolidated Statement of Operations		Amount Reclassified from Accumulated Other Comprehensive Income
						For the three months ended
						31-Mar-15
						(in millions)
	Cash flow hedges
	Settlements			Gas Sales	$	-42
				Provision (Benefit) for Income Taxes		17
				Net Income	$	-25
	Total reclassifications for the period			Net Income	$	-25

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2015
Fair Value Measurements [Abstract]
Carrying Amount And Estimated Fair Values Of Financial Instruments
		31-Mar-15						31-Dec-14
		Carrying			Fair			Carrying			Fair
		Amount			Value			Amount			Value
		(in millions)
	Cash and cash equivalents	$	17		$	17		$	53		$	53
	Credit facility	$	800		$	800		$	300		$	300
	Term loan facility (1)	$	500			500		$	500		$	500
	Bridge facility (2)	$	–			–		$	4,500		$	4,500
	Senior notes	$	3,864		$	3,983		$	1,667		$	1,751
	Derivative instruments, net	$	278		$	278		$	316		$	316
		-1		The term loan facility was repaid in full in April 2015 with proceeds from the divestiture of the Company’s northeastern Pennsylvania gathering assets and borrowings under the revolving credit facility.
		-2		The bridge facility was repaid in full in January 2015 with proceeds from the issuance of $2.2 billion of long-term senior notes and the $2.3 billion issuance of common and preferred stock.
Summary Assets And Liabilities Measured At Fair Value On Recurring Basis
			31-Mar-15
			Fair Value Measurements Using:
			Quoted Prices			Significant Other Observable Inputs			Significant Unobservable Inputs			Assets (Liabilities)
			In Active Markets
			(Level 1)			(Level 2)			(Level 3)			at Fair Value
	Fixed price swap assets		$	–		$	292		$	–		$	292
	Basis swap assets			–			–			3			3
	Interest rate swap liabilities			–			-6			–			-6
	Basis swap liabilities			–			–			-6			-6
	Fixed price call option liabilities			–			–			-5			-5
	Total		$	–		$	286		$	-8		$	278
			31-Dec-14
			Fair Value Measurements Using:
			Quoted Prices			Significant
			in Active			Other			Significant
			Markets			Observable Inputs			Unobservable Inputs			Assets (Liabilities)
			(Level 1)			(Level 2)			(Level 3)			at Fair Value
	Fixed price swap assets		$	–		$	328		$	–		$	328
	Interest rate swap assets			–			1			–			1
	Basis swap assets			–			–			10			10
	Interest rate swap liabilities			–			-5			–			-5
	Basis swap liabilities			–			–			-6			-6
	Fixed price call option liabilities			–			–			-12			-12
	Total		$	–		$	324		$	-8		$	316
Reconciliations For Change In Net Fair Value Of Derivative Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Significant Unobservable Inputs (Level 3)
			For the three months ended
			March 31,
			2015			2014
			(in millions)
	Balance at beginning of period		$	-8		$	-19
	Total gains (losses):
	Included in earnings			-6			-51
	Included in other comprehensive income			–			–
	Purchases, issuances, and settlements:
	Purchases			–			–
	Issuances			–			–
	Settlements			6			14
	Transfers into/out of Level 3			–			–
	Balance at end of period		$	-8		$	-56
	Change in losses included in earnings relating to derivatives still held as of March 31		$	–		$	-37

Debt_Tables

Debt (Tables)	3 Months Ended
	Mar. 31, 2015
Debt [Abstract]
Components Of Debt			March 31,		December 31,
			2015		2014
			(in millions)
	Short-term debt:
	7.15% Senior Notes due 2018		$	1	$	1
	Variable rate (1.515% at December 31, 2014) bridge facility, due December 2015 (1)			–		4,500
	Total short-term debt			1		4,501
	Long-term debt:
	Variable rate (1.673% and 1.515% at March 31, 2015 and December 31, 2014, respectively) unsecured revolving credit facility			800		300
	Variable rate (1.680% and 1.545% at March 31, 2015 and December 31, 2014, respectively) term loan facility, due December 2016 (2)			500		500
	7.35% Senior Notes due 2017			15		15
	7.125% Senior Notes due 2017			25		25
	7.15% Senior Notes due 2018			27		27
	3.3% Senior Notes due 2018			350		–
	7.5% Senior Notes due 2018			600		600
	4.05% Senior Notes due 2020			850		–
	4.10% Senior Notes due 2022			1,000		1,000
	4.95% Senior Notes due 2025			1,000		–
	Unamortized discount			-4		-1
	Total long-term debt			5,163		2,466
	Total debt		$	5,164	$	6,967
		-1		The bridge facility was repaid in full in January 2015 with proceeds from the issuance of $2.2 billion of long-term senior notes and $2.3 billion of common and preferred stock.
		-2		The term loan facility was repaid in full in April 2015 with proceeds from the divestiture of the Company’s northeastern Pennsylvania gathering assets and borrowings under the revolving credit facility.

Pension_Plan_And_Other_Postret1

Pension Plan And Other Postretirement Benefits (Tables)	3 Months Ended
	Mar. 31, 2015
Pension Plan And Other Postretirement Benefits [Abstract]
Pension And Other Postretirement Benefit Costs
		Pension Benefits
		For the three months ended
		March 31,
		2015		2014
		(in millions)
	Service cost	$	4	$	3
	Interest cost		1		1
	Expected return on plan assets		-2		-1
	Amortization of prior service cost		–		–
	Amortization of net loss		1		–
	Net periodic benefit cost	$	4	$	3

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2015
Stock-Based Compensation [Abstract]
Schedule Of Stock-Based Compensation Costs
			For the three months ended
			March 31,
			2015			2014
			(in millions)
	Stock-based compensation cost  –  expensed		$	6		$	4
	Stock-based compensation cost – capitalized		$	5		$	5
Summary Of Stock Option Activity
					Weighted
					Average
			Number		Exercise
			of Options		Price
			(in thousands)
	Outstanding at December 31, 2014		3,622		$	35.41
	Granted		223			26.35
	Exercised		–			–
	Forfeited or expired		-2			36.50
	Outstanding at March 31, 2015		3,843			34.89
	Exercisable at March 31, 2015		2,277		$	36.13
Summary Of Restricted Stock Activity
					Weighted
					Average
			Number		Grant Date
			of Shares		Fair Value
			(in thousands)
	Unvested shares at December 31, 2014		2,376		$	34.00
	Granted		97			26.27
	Vested		-7			35.57
	Forfeited		-17			34.02
	Unvested shares at March 31, 2015		2,449		$	33.68
Summary Of Performance Unit Activity					Weighted
					Average
			Number		Grant Date
			of Units (1)		Fair Value
			(in thousands)
	Unvested units at December 31, 2014		223		$	40.44
	Granted		443			35.22
	Unvested units at March 31, 2015		666		$	36.97
		-1		These amounts reflect the number of performance units granted in thousands. The actual payout of shares may range from a minimum of zero shares to a maximum of two shares contingent upon the actual performance against the Performance Measures.

Segment_Information_Tables

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2015
Segment Information [Abstract]
Summary Financial Information For Company's Reportable Segments
			Exploration
			and		Midstream
			Production		Services		Other			Total
			(in millions)
	Three months ended March 31, 2015:
	Revenues from external customers		$	660	$	273	$	–		$	933
	Intersegment revenues			-5		665		1			661
	Operating income (loss)			78		88		-1			165
	Other loss			-1		–		–			-1
	Gain (loss) on derivatives			15		–		-1			14
	Depreciation, depletion and amortization			278		15		–			293
	Interest expense (1)			45		7		-1			51
	Provision for income taxes (1)			18		31		–			49
	Assets			13,703		1,616		268	-2		15,587
	Capital investments (3)			1,030		138		3			1,171
	Three months ended March 31, 2014:
	Revenues from external customers		$	796	$	317	$	–		$	1,113
	Intersegment revenues			6		913		–			919
	Operating income			352		83		–			435
	Other income (loss), net			2		–		-1			1
	Loss on derivatives			-100		–		–			-100
	Depreciation, depletion and amortization			211		14		–			225
	Interest expense (1)			9		4		–			13
	Provision for income taxes (1)			98		31		–			129
	Assets			6,621		1,544		258	-2		8,423
	Capital investments (3)			499		39		4			542
		-1		Interest expense and the provision for income taxes by segment are allocated as they are incurred at the corporate level.
		-2		Other assets represent corporate assets not allocated to segments and assets for non reportable segments.
		-3		Capital investments includes an immaterial increase and $6 million increase for the three month periods ended March 31, 2015 and 2014, respectively, relating to the change in accrued expenditures between periods.  E&P capital for the three months ended March 31, 2015 includes approximately $534 million related to the WPX and Statoil Property Acquisitions. Midstream capital for the three months ended March 31, 2015 includes approximately $119 million of firm transport associated with the WPX Property Acquisition.

Acquisitions_And_Divestitures_1

Acquisitions And Divestitures (Narrative) (Details) (USD $)	1 Months Ended		3 Months Ended	1 Months Ended	0 Months Ended	1 Months Ended	12 Months Ended	0 Months Ended	6 Months Ended
In Millions, unless otherwise specified	Jan. 31, 2015	Dec. 31, 2014	Mar. 31, 2015	Mar. 31, 2015	Dec. 19, 2014	Apr. 22, 2015	Dec. 31, 2014	Dec. 22, 2014	Sep. 30, 2014
									acre
Bridge Loan [Member]
Business Acquisition [Line Items]
Term loan, maturity date			2015-12
Bridge loan	$4,500	$4,500	$4,500	$4,500			$4,500
Debt instrument, term	364 days	364 days	364 days
Debt issuance costs	47
Oil And Gas Assets Located In East Texas And Arkona Basin [Member]
Business Acquisition [Line Items]
Proceeds from sale of oil and gas property and equipment				218
Unsecured Debt [Member] | Term Loan [Member]
Business Acquisition [Line Items]
Loans payable		500	500	500	500	500	500
Term loan, maturity date						2016-12	2016-12
Debt instrument, term		2 years			2 years
WPX Property Acquisition [Member]
Business Acquisition [Line Items]
Area of land purchased	46,700
Cash consideration	288
Net production per day of acreage sold in MMcf		50					50
Number of horizontal wells operated		63
Firm transportation capacity assumed, per day		260
Allocated to natural gas and oil properties	169
Allocated to intangible assets	119
Statoil Property Acquisition [Member]
Business Acquisition [Line Items]
Area of land purchased	30,000
Allocated to natural gas and oil properties	365
Percentage of interest acquired	20.00%
Cost to acquire property	365
Chesapeake Property Acquisition [Member]
Business Acquisition [Line Items]
Area of land purchased		413,000					413,000
Cash consideration								4,978
Niobrara Formation In Colorado [Member]
Business Acquisition [Line Items]
Area of land purchased									380,000
Cost to acquire property									215
Subsequent Event [Member] | Gathering Assets Located In Bradford And Lycoming Counties [Member]
Business Acquisition [Line Items]
Proceeds from sale of oil and gas property and equipment						488
Net book value of assets sold						$213
Number of miles of natural gas gathering pipeline						100
Pipeline capacity per day						600

Acquisitions_And_Divestitures_2

Acquisitions And Divestitures (Summary Of Consideration Paid And Fair Value Of Assets Acquired And Liabilities Assumed) (Details) (Chesapeake Property Acquisition [Member], USD $)	0 Months Ended
In Millions, unless otherwise specified	Dec. 22, 2014	Dec. 22, 2014
Chesapeake Property Acquisition [Member]
Business Acquisition [Line Items]
Cash	$4,978
Proved natural gas and oil properties	1,424	1,424
Unproved natural gas and oil properties	3,605	3,605
Other property and equipment	19	19
Inventory	2	2
Other receivables	27	27
Total assets acquired	5,077	5,077
Asset retirement obligations	-42	-42
Other long-term liabilities	-57	-57
Total liabilities assumed	-99	-99
Total assets acquired and liabilities assumed	$4,978	$4,978

Acquisitions_And_Divestitures_3

Acquisitions And Divestitures (Summary Of Consolidated Results Of Operations On Pro Forma Basis) (Details) (Chesapeake Property Acquisition [Member], USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2014
Chesapeake Property Acquisition [Member]
Business Acquisition [Line Items]
Revenues	$1,251
Net Income	$243
Basic	$0.48
Diluted	$0.48

Inventory_Details

Inventory (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Inventory [Abstract]
Tubulars and other equipment	$37	$33
Natural gas in underground storage	$2	$4

Natural_Gas_And_Oil_Properties1

Natural Gas And Oil Properties (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Discount rate of natural gas and oil reserves	10.00%
Cash flow hedges impact on ceiling value, net of tax	$45	$40
Henry Hub Natural Gas [Member]
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Full cost ceiling test, price	3.88	3.99
Oil [Member] | West Texas Intermediate Oil [Member]
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Full cost ceiling test, price	79.21	94.92
NGL [Member] | West Texas Intermediate Oil [Member]
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Full cost ceiling test, price	16.38	43.64

Earnings_Per_Share_Narrative_D

Earnings Per Share (Narrative) (Details) (USD $)	1 Months Ended		3 Months Ended
	Jan. 31, 2015	Dec. 31, 2014	Mar. 31, 2015
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Proceeds from issuance of shares	$2,300,000,000
Preferred stock, dividend rate			6.25%
Preferred stock, liquidation preference per share	$1,000		$1,000
Bridge Loan [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Bridge loan	4,500,000,000	4,500,000,000	4,500,000,000
Debt instrument, term	364 days	364 days	364 days
Common Stock [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares issued	30,000,000
Share price	$23
Proceeds from issuance of shares	669,000,000
Depositary Shares [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares issued	34,500,000
Proceeds from issuance of shares	1,700,000,000
Depositary shares conversion rate	0.05
Preferred stock, liquidation preference per share	$50
Convertible Preferred Stock [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Trading day period			20 days
Senior Notes [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Proceeds from issuance of debt	$2,200,000,000
Minimum [Member] | Depositary Shares [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares issued upon conversion			1.85014
Minimum [Member] | Convertible Preferred Stock [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares issued upon conversion			37.0028
Maximum [Member] | Depositary Shares [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares issued upon conversion			2.17391
Maximum [Member] | Convertible Preferred Stock [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares issued upon conversion			43.4782

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net income	$78	$194
Preferred stock dividends	25
Mandatory convertible preferred stock dividend	25
Net income attributable to shareholders	53	194
Participating securities - mandatory convertible preferred stock	7
Net Income Attributable to Common Stock	$46	$194
Number of common shares, Weighted average outstanding	375,444,030	351,222,538
Number of common shares: Issued upon assumed exerciese of outstanding stock options		348,798
Number of common shares: Effect of issuance of nonvested restricted common stock	133,634	349,608
Number of common shares: Effect of issuance of nonvested performance units	390	64,877
Number of common shares: Effect of issuance of mandatory convertible preferred stock	0	0
Diluted	375,578,054	351,985,821
Basic	$0.12	$0.55
Diluted	$0.12	$0.55
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, shares	3,704,089	1,179,914
Restricted Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, shares	1,916,645	29,688
Mandatory Convertible Preferred Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, shares	58,333,252

Derivatives_And_Risk_Managemen2

Derivatives And Risk Management (Narrative) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015
Derivative [Line Items]
Accumulated other comprehensive income, net gain related to hedging activities	$90
Deferred income tax liability, accumulated other comprehensive income	56
Cash flow hedge after-tax net gain to be transferred from accumulated other comprehensive income to earnings during the next twelve months	90
Interest Rate Swaps [Member]
Derivative [Line Items]
Notional amount	$170
Year 2015 [Member] | Fixed Price Swaps [Member]
Derivative [Line Items]
Volume of natural gas production	181,000,000,000
Designated as Hedging Instrument [Member] | Year 2015 [Member] | Fixed Price Swaps [Member]
Derivative [Line Items]
Volume of natural gas production	91,000,000,000
Not Designated as Hedging Instrument [Member] | Year 2015 [Member] | Basis Swaps [Member]
Derivative [Line Items]
Volume of natural gas production	11,000,000,000
Not Designated as Hedging Instrument [Member] | Year 2015 [Member] | Fixed Price Call Options [Member]
Derivative [Line Items]
Volume of natural gas production	151,000,000,000
Not Designated as Hedging Instrument [Member] | Year 2015 [Member] | Fixed Price Swaps [Member]
Derivative [Line Items]
Volume of natural gas production	90,000,000,000
Not Designated as Hedging Instrument [Member] | Year 2016 [Member] | Basis Swaps [Member]
Derivative [Line Items]
Volume of natural gas production	4,000,000,000
Not Designated as Hedging Instrument [Member] | Year 2016 [Member] | Fixed Price Call Options [Member]
Derivative [Line Items]
Volume of natural gas production	120,000,000,000

Derivatives_And_Risk_Managemen3

Derivatives And Risk Management (Balance Sheet Classification Of Derivative Financial Instruments) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Derivatives, Fair Value [Line Items]
Derivative assets	$295	$339
Derivative liabilities	17	23
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	146	165
Designated as Hedging Instrument [Member] | Fixed Price Swaps [Member] | Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	146	165
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	149	174
Derivative liabilities	17	23
Not Designated as Hedging Instrument [Member] | Fixed Price Swaps [Member] | Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	146	163
Not Designated as Hedging Instrument [Member] | Basis Swaps [Member] | Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	3	9
Not Designated as Hedging Instrument [Member] | Basis Swaps [Member] | Other Long-Term Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets		1
Not Designated as Hedging Instrument [Member] | Basis Swaps [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	6	4
Not Designated as Hedging Instrument [Member] | Basis Swaps [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities		2
Not Designated as Hedging Instrument [Member] | Interest Rate Swaps [Member] | Other Long-Term Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets		1
Not Designated as Hedging Instrument [Member] | Interest Rate Swaps [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	3	3
Not Designated as Hedging Instrument [Member] | Interest Rate Swaps [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	3	2
Not Designated as Hedging Instrument [Member] | Fixed Price Call Options [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	2	2
Not Designated as Hedging Instrument [Member] | Fixed Price Call Options [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	$3	$10

Derivatives_And_Risk_Managemen4

Derivatives And Risk Management (Schedule Of Derivative Instruments, Volumes Of Natural Gas Production) (Details) (Year 2015 [Member], Fixed Price Swaps [Member])	3 Months Ended
	Mar. 31, 2015
	ft3
Derivative [Line Items]
Volume of natural gas production	181,000,000,000
Weighted average price to be swapped	4.4
Designated as Hedging Instrument [Member]
Derivative [Line Items]
Volume of natural gas production	91,000,000,000
Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Volume of natural gas production	90,000,000,000

Derivatives_And_Risk_Managemen5

Derivatives And Risk Management (Summary Of Before Tax Effect Of Cash Flow Hedges On Consolidated Financial Statements) (Details) (Fixed Price Swaps [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income, Effective Portion	$24	($90)
Gas Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated Other Comprehensive Income into Earnings, Effective Portion	$42	($42)

Derivatives_And_Risk_Managemen6

Derivatives And Risk Management (Summary Of Before Tax Effect Of Fair Value Hedges Not Designated For Hedge Accounting) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Basis Swaps [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) on Derivatives, Excluding Derivatives, Settled	($8)	($10)
Derivative Instruments, Gain (Loss) on Derivatives, Settled	-6	-14
Fixed Price Call Options [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) on Derivatives, Excluding Derivatives, Settled	8	-27
Fixed Price Swaps [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) on Derivatives, Excluding Derivatives, Settled	-18	-23
Derivative Instruments, Gain (Loss) on Derivatives, Settled	42	-24
Interest Rate Swaps [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) on Derivatives, Excluding Derivatives, Settled	-3	-2
Derivative Instruments, Gain (Loss) on Derivatives, Settled	($1)

Reclassification_From_Accumula2

Reclassification From Accumulated Other Comprehensive Income (Components Of Accumulated Other Comprehensive Income (Loss)) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance, December 31, 2014	$62
Other comprehensive income (loss) before reclassifications	11
Amounts reclassified from other comprehensive loss	-25
Net current-period other comprehensive loss	-14
Ending balance, March 31, 2015	48
Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance, December 31, 2014	98
Other comprehensive income (loss) before reclassifications	17
Amounts reclassified from other comprehensive loss	-25
Net current-period other comprehensive loss	-8
Ending balance, March 31, 2015	90
Pension And Other Postretirement [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance, December 31, 2014	-24
Other comprehensive income (loss) before reclassifications
Amounts reclassified from other comprehensive loss
Net current-period other comprehensive loss
Ending balance, March 31, 2015	-24
Foreign Currency [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance, December 31, 2014	-12
Other comprehensive income (loss) before reclassifications	-6
Net current-period other comprehensive loss	-6
Ending balance, March 31, 2015	($18)

Reclassification_From_Accumula3

Reclassification From Accumulated Other Comprehensive Income (Amounts Reclassified From Accumulated Other Comprehensive Income (Loss)) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Gas sales	$625	$793
Provision (benefit) for income taxes	49	129
Net Income	78	194
Reclassification Out Of Accumulated Other Comprehensive Loss [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net Income	-25
Cash Flow Hedges [Member] | Reclassification Out Of Accumulated Other Comprehensive Loss [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Provision (benefit) for income taxes	17
Net Income	-25
Cash Flow Hedges [Member] | Reclassification Out Of Accumulated Other Comprehensive Loss [Member] | Settlements [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Gas sales	($42)

Fair_Value_Measurements_Carryi

Fair Value Measurements (Carrying Amount And Estimated Fair Values Of Financial Instruments) (Details) (USD $)	1 Months Ended
	Jan. 31, 2015	Mar. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proceeds from issuance of shares	$2,300,000,000
Carrying Amount [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents		17,000,000	53,000,000
Credit facility		800,000,000	300,000,000
Senior notes		3,864,000,000	1,667,000,000
Derivative instruments		278,000,000	316,000,000
Carrying Amount [Member] | Bridge Loan [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loans			4,500,000,000
Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents		17,000,000	53,000,000
Credit facility		800,000,000	300,000,000
Senior notes		3,983,000,000	1,751,000,000
Derivative instruments		278,000,000	316,000,000
Fair Value [Member] | Bridge Loan [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loans			4,500,000,000
Unsecured Debt [Member] | Carrying Amount [Member] | Term Loan [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loans		500,000,000	500,000,000
Unsecured Debt [Member] | Fair Value [Member] | Term Loan [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loans		500,000,000	500,000,000
Senior Notes [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proceeds from issuance of debt	$2,200,000,000

Fair_Value_Measurements_Summar

Fair Value Measurements (Summary Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Quoted Prices in Active Markets for Identical Assets, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total
Significant Observable Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	286	324
Significant Unobservable Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	-8	-8
Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	278	316
Fixed Price Swaps [Member] | Quoted Prices in Active Markets for Identical Assets, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets
Fixed Price Swaps [Member] | Significant Observable Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	292	328
Fixed Price Swaps [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	292	328
Basis Swaps [Member] | Quoted Prices in Active Markets for Identical Assets, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets
Derivative liabilities
Basis Swaps [Member] | Significant Unobservable Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	3	10
Derivative liabilities	-6	-6
Basis Swaps [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	3	10
Derivative liabilities	-6	-6
Interest Rate Swaps [Member] | Quoted Prices in Active Markets for Identical Assets, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets
Derivative liabilities
Interest Rate Swaps [Member] | Significant Observable Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		1
Derivative liabilities	-6	-5
Interest Rate Swaps [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets		1
Derivative liabilities	-6	-5
Fixed Price Call Options [Member] | Quoted Prices in Active Markets for Identical Assets, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities
Fixed Price Call Options [Member] | Significant Unobservable Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	-5	-12
Fixed Price Call Options [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	($5)	($12)

Fair_Value_Measurements_Reconc

Fair Value Measurements (Reconciliations For Change In Net Fair Value Of Derivative Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Significant Unobservable Inputs (Level 3)) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Fair Value Measurements [Abstract]
Balance at beginning of period	($8)	($19)
Included in earnings	-6	-51
Included in other comprehensive income
Purchases, issuances, and settlements:
Purchases
Issuances
Settlements	6	14
Transfers into/out of Level 3
Balance at end of period	-8	-56
Change in losses included in earnings relating to derivatives still held as of March 31		($37)

Debt_Narrative_Details

Debt (Narrative) (Details) (USD $)	3 Months Ended	1 Months Ended		0 Months Ended
	Mar. 31, 2015	Jan. 31, 2015	Dec. 31, 2014	Dec. 19, 2014	Apr. 22, 2015
	item
Credit Facility [Member]
Debt Instrument [Line Items]
Unsecured revolving credit facility, borrowing capacity	$2,000,000,000
Unsecured revolving credit facility, maturity date	1-Dec-18
Number of extension options	2
Extension term	1 year
Unsecured revolving credit facility, increase in current borrowing capacity potential	500,000,000
Debt percentage of adjusted book capital structure covenant	60.00%
Credit Facility [Member] | Over LIBOR [Member]
Debt Instrument [Line Items]
Basis points	1.50%
Senior Notes [Member]
Debt Instrument [Line Items]
Proceeds from issuance of debt		2,200,000,000
Bridge Loan [Member]
Debt Instrument [Line Items]
Bridge loan	4,500,000,000	4,500,000,000	4,500,000,000
Debt instrument, term	364 days	364 days	364 days
Debt issuance costs		47,000,000
Term Loan [Member] | Unsecured Debt [Member]
Debt Instrument [Line Items]
Debt instrument, term			2 years	2 years
Loans payable	500,000,000		500,000,000	500,000,000	500,000,000
3.3% Senior Notes due 2018 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Senior notes	350,000,000	350,000,000
Stated interest rate	3.30%	3.30%
Maturity date	2018	2018
Percentage of face amount, sold to public		99.95%
4.05% Senior Notes due 2020 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Senior notes	850,000,000	850,000,000
Stated interest rate	4.05%	4.05%
Maturity date	2020	2020
Percentage of face amount, sold to public		99.90%
4.95% Senior Notes due 2025 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Senior notes	$1,000,000,000	$1,000,000,000
Stated interest rate	4.95%	4.95%
Maturity date	2025	2025
Percentage of face amount, sold to public		99.78%

Debt_Components_Of_Debt_Detail

Debt (Components Of Debt) (Details) (USD $)	1 Months Ended	3 Months Ended	12 Months Ended	1 Months Ended
	Jan. 31, 2015	Mar. 31, 2015	Dec. 31, 2014	Apr. 22, 2015	Dec. 19, 2014
Debt Instrument [Line Items]
Total short-term debt		$1,000,000	$4,501,000,000
Unamortized discount		-4,000,000	-1,000,000
Long-term debt		5,163,000,000	2,466,000,000
Total debt		5,164,000,000	6,967,000,000
Proceeds from issuance of shares	2,300,000,000
Credit Facility [Member]
Debt Instrument [Line Items]
Variable rate (1.673% and 1.515% at March 31, 2015 and December 31, 2014, respectively) unsecured revolving credit facility		800,000,000	300,000,000
Credit facility, maturity date		1-Dec-18
7.35% Senior Notes due 2017 [Member] | Credit Facility [Member]
Debt Instrument [Line Items]
Credit facility, variable interest rate		1.67%	1.52%
Senior Notes [Member]
Debt Instrument [Line Items]
Stated interest rate		7.15%
Senior Notes [Member] | 7.15% Senior Notes due 2018 [Member]
Debt Instrument [Line Items]
Senior notes		1,000,000	1,000,000
Maturity date		2018
Bridge Loan [Member]
Debt Instrument [Line Items]
Variable rate (1.515% at December 31, 2014) bridge facility, due December 2015	4,500,000,000	4,500,000,000	4,500,000,000
Term loan, maturity date		2015-12
Term loan, variable interest rate			1.52%
Senior Notes [Member]
Debt Instrument [Line Items]
Proceeds from issuance of debt	2,200,000,000
Senior Notes [Member] | 7.35% Senior Notes due 2017 [Member]
Debt Instrument [Line Items]
Senior notes		15,000,000	15,000,000
Stated interest rate		7.35%
Maturity date		2017
Senior Notes [Member] | 7.125% Senior Notes due 2017 [Member]
Debt Instrument [Line Items]
Senior notes		25,000,000	25,000,000
Stated interest rate		7.13%
Maturity date		2017
Senior Notes [Member] | 7.15% Senior Notes due 2018 [Member]
Debt Instrument [Line Items]
Senior notes		27,000,000	27,000,000
Stated interest rate		7.15%
Maturity date		2018
Senior Notes [Member] | 3.3% Senior Notes due 2018 [Member]
Debt Instrument [Line Items]
Senior notes	350,000,000	350,000,000
Stated interest rate	3.30%	3.30%
Maturity date	2018	2018
Senior Notes [Member] | 7.5% Senior Notes Due 2018 [Member]
Debt Instrument [Line Items]
Senior notes		600,000,000	600,000,000
Stated interest rate		7.50%
Maturity date		2018
Senior Notes [Member] | 4.05% Senior Notes due 2020 [Member]
Debt Instrument [Line Items]
Senior notes	850,000,000	850,000,000
Stated interest rate	4.05%	4.05%
Maturity date	2020	2020
Senior Notes [Member] | 4.10% Senior Notes Due 2022 [Member]
Debt Instrument [Line Items]
Senior notes		1,000,000,000	1,000,000,000
Stated interest rate		4.10%
Maturity date		2022
Senior Notes [Member] | 4.95% Senior Notes due 2025 [Member]
Debt Instrument [Line Items]
Senior notes	1,000,000,000	1,000,000,000
Stated interest rate	4.95%	4.95%
Maturity date	2025	2025
Unsecured Debt [Member] | Term Loan [Member]
Debt Instrument [Line Items]
Variable rate (1.680% and 1.545% at March 31, 2015 and December 31, 2014, respectively) term loan facility, due December 2016		$500,000,000	$500,000,000	$500,000,000	$500,000,000
Term loan, maturity date			2016-12	2016-12
Term loan, variable interest rate		1.68%	1.55%

Commitments_And_Contingencies_

Commitments And Contingencies (Details)	1 Months Ended		3 Months Ended
	Jul. 31, 2013	Aug. 31, 2011	Mar. 31, 2015	Mar. 31, 2015	Dec. 31, 2010	Mar. 31, 2010
	USD ($)	USD ($)	USD ($)	CAD	USD ($)	CAD
						acre
Commitments And Contingencies [Abstract]
Investment in New Brunswick towards Company's commitment			$44,000,000	45,000,000
Guarantee obligations relative to the firms transportation agreements and gathering project and services			261,000,000
Unrecorded capital investments obligation, Exploration program acres coverage (acres)						2,500,000
Unrecorded capital investments obligation						47,000,000
Unrecorded promissory note payable						45,000,000
Promissory note payable, liability recognized			0
Obligation under transportation agreements			5,700,000,000
Litigation settlement, gross		11,000,000
Litigation, portion of profits considered for disgorgement					382,000,000
Disgorgement damages awarded in favor of the plaintiff and intervenor		24,000,000
Litigation, interest and attorney's fees claimed by plaintiffs		9,000,000			11,000,000
Disgorgement recoverable by plaintiff to be reversed	24,000,000
Actual damages recoverable by plaintiff to be reversed	$11,000,000

Pension_Plan_And_Other_Postret2

Pension Plan And Other Postretirement Benefits (Narrative) (Details) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Defined Contribution Pension [Member]
Defined Benefit Plan Disclosure [Line Items]
Common stock purchased under the terms of the Non-Qualified Plan presented as treasury stock	13,893		11,055
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	$4	$3
Employer contributions	3
Company's expected additional annual contribution	9
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	$1	$1

Pension_Plan_And_Other_Postret3

Pension Plan And Other Postretirement Benefits (Pension And Other Postretirement Benefit Costs) (Details) (Pension Benefits [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$4	$3
Interest cost	1	1
Expected return on plan assets	-2	-1
Amortization of net loss	1
Net periodic benefit cost	$4	$3

StockBased_Compensation_Narrat

Stock-Based Compensation (Narrative) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation cost related to the Company's unvested stock option grants, restricted stock grants, and performance units	$106
Weighted average period over which cost is recognized, years	3 years
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period for stock awards from grant date	3 years
Deferred tax liability recorded	$26	$51

StockBased_Compensation_Schedu

Stock-Based Compensation (Schedule Of Stock-Based Compensation Costs - Stock Options) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Stock-Based Compensation [Abstract]
Stock-based compensation costs - expensed	$6	$4
Stock-based compensation costs - capitalized	$5	$5

StockBased_Compensation_Summar

Stock-Based Compensation (Summary Of Stock Option Activity) (Details) (USD $)	3 Months Ended
	Mar. 31, 2015
Stock-Based Compensation [Abstract]
Stock options, Outstanding at December 31, 2014, Number of options	3,622,000
Stock options, Granted, Number of options	223,000
Stock options, Exercised, Number of options
Stock options, Forfeited or expired, Number of options	-2,000
Stock options, Outstanding at March 31, 2015, Number of options	3,843,000
Stock options, Outstanding at December 31, 2014, Weighted average exercise price	$35.41
Stock options, Granted, Weighted average exercise price	$26.35
Stock options, Exercised, Weighted average exercise price
Stock options, Forfeited or expired, Weighted average exercise price	$36.50
Stock options, Outstanding at March 31, 2015, Weighted average exercise price	$34.89
Stock options, Exercisable at March 31, 2015	2,277,000
Stock options, Exercisable at March 31, 2015, Weighted average exercise price	$36.13

StockBased_Compensation_Summar1

Stock-Based Compensation (Summary Of Restricted Stock Activity) (Details) (Restricted Stock [Member], USD $)	3 Months Ended
	Mar. 31, 2015
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unvested shares/units at December 31, 2014, Number of Shares	2,376,000
Granted, Number of Shares/Units	97,000
Vested, Number of Shares/Units	-7,000
Forfeited, Number of Shares/Units	-17,000
Unvested shares/units at March 31, 2015, Number of Shares	2,449,000
Unvested shares/units at December 31, 2014, Weighted Average Grant Date Fair Value	$34
Granted, Weighted Average Grant Date Fair Value	$26.27
Vested, Weighted Average Grant Date Fair Value	$35.57
Forfeited, Weighted Average Grant Date Fair Value	$34.02
Unvested shares at March 31, 2015, Weighted Average Grant Date Fair Value	$33.68

StockBased_Compensation_Summar2

Stock-Based Compensation (Summary Of Performance Unit Activity) (Details) (Performance Units [Member], USD $)	3 Months Ended
	Mar. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unvested shares/units at December 31, 2014, Number of Shares	223,000
Granted, Number of Shares/Units	443,000
Unvested shares/units at March 31, 2015, Number of Shares	666,000
Unvested shares/units at December 31, 2014, Weighted Average Grant Date Fair Value	$40.44
Granted, Weighted Average Grant Date Fair Value	$35.22
Unvested shares at March 31, 2015, Weighted Average Grant Date Fair Value	$36.97
Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted, Number of Shares/Units	0
Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted, Number of Shares/Units	2

Segment_Information_Details

Segment Information (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Revenues	$933	$1,113
Operating income (loss)	165	435
Other income (loss), net	-1	1
Gain (loss) on derivatives	14	-100
Depreciation, depletion and amortization	293	225
Interest expense	51	13
Provision (benefit) for income taxes	49	129
Assets	15,587	8,423	14,925
Capital investments	1,171	542
Change in accrued expenditures		6
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	-661	-919
Exploration and Production [Member]
Segment Reporting Information [Line Items]
Revenues	660	796
Operating income (loss)	78	352
Other income (loss), net	-1	2
Gain (loss) on derivatives	15	-100
Depreciation, depletion and amortization	278	211
Interest expense	45	9
Provision (benefit) for income taxes	18	98
Assets	13,703	6,621
Capital investments	1,030	499
Exploration and Production [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	5	-6
Exploration and Production [Member] | Canada [Member]
Segment Reporting Information [Line Items]
Assets	71	80
Midstream Services [Member]
Segment Reporting Information [Line Items]
Revenues	273	317
Operating income (loss)	88	83
Depreciation, depletion and amortization	15	14
Interest expense	7	4
Provision (benefit) for income taxes	31	31
Assets	1,616	1,544
Capital investments	138	39
Midstream Services [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	-665	-913
Other [Member]
Segment Reporting Information [Line Items]
Operating income (loss)	-1
Other income (loss), net		-1
Gain (loss) on derivatives	-1
Interest expense	-1
Assets	268	258
Capital investments	3	4
Other [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	-1
Marketing [Member] | Midstream Services [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	-576	-824
WPX and Statoil Property Acquisitions [Member] | Exploration and Production [Member]
Segment Reporting Information [Line Items]
Capital investments	534
WPX Property Acquisition [Member] | Midstream Services [Member]
Segment Reporting Information [Line Items]
Capital investments	$119