Southwestern Energy (SWN) 10-Q 21 Jul 16 2016 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Jul. 19, 2016
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q2
Entity Registrant Name	SOUTHWESTERN ENERGY CO
Entity Central Index Key	7,332
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		493,455,527
Trading Symbol	SWN

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Operating Revenues:
Gas sales	$ 251	$ 457	$ 566	$ 1,082
Oil sales	20	24	31	41
NGL sales	20	15	37	33
Marketing	196	222	394	447
Gas gathering	35	46	73	94
Total Operating Revenues	522	764	1,101	1,697
Operating Costs and Expenses:
Marketing purchases	197	219	393	441
Operating expenses	151	176	316	331
General and administrative expenses	56	60	110	128
Restructuring charges	11		75
Depreciation, depletion and amortization	107	308	250	601
Impairment of natural gas and oil properties	470	1,535	1,504	1,535
Gain on sale of assets, net		(277)		(277)
Taxes, other than income taxes	22	27	45	57
Total Operating Costs and Expenses	1,014	2,048	2,693	2,816
Operating Loss	(492)	(1,284)	(1,592)	(1,119)
Interest Expense:
Interest on debt	56	52	109	102
Other interest charges	2	3	4	52
Interest capitalized	(41)	(54)	(82)	(102)
Total Interest Expense	17	1	31	52
Other Income (Loss), Net		3	(3)	2
Gain (Loss) on Derivatives	(85)	1	(99)	15
Loss Before Income Taxes	(594)	(1,281)	(1,725)	(1,154)
Provision (Benefit) for Income Taxes:
Current		7		7
Deferred	(1)	(500)		(451)
Provision (Benefit) for Income Taxes	(1)	(493)		(444)
Net Loss	(593)	(788)	(1,725)	(710)
Mandatory convertible preferred stock dividend	27	27	54	52
Net Loss Attributable to Common Stock	$ (620)	$ (815)	$ (1,779)	$ (762)
Loss Per Common Share:
Basic	$ (1.61)	$ (2.13)	$ (4.63)	$ (2.01)
Diluted	$ (1.61)	$ (2.13)	$ (4.63)	$ (2.01)
Weighted Average Common Shares Outstanding:
Basic	385,594,815	382,114,011	384,232,831	378,797,446
Diluted	385,594,815	382,114,011	384,232,831	378,797,446

CONDENSED CONSOLIDATED STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME LOSS [Abstract]
Net loss		$ (593)	$ (788)	$ (1,725)	$ (710)
Change in derivatives:
Settlements	[1]		(33)		(58)
Change in fair value of derivative instruments	[2]		(4)		13
Total change in derivatives			(37)		(45)
Change in value of pension and other postretirement liabilities:
Amortization of prior service cost and net loss included in net periodic pension cost	[3]	(1)
Net gain incurred in period	[4]	4		4
Change in currency translation adjustment			2	3	(4)
Comprehensive loss		$ (590)	$ (823)	$ (1,718)	$ (759)
[1]	Net of ($20) million and ($37) million in taxes for the three and six months ended June 30, 2015.
[2]	Net of $1 million and $8 million in taxes for the three and six months ended June 30, 2015.
[3]	Net of $1 million in taxes for the six months ended June 30, 2016.
[4]	Net of $1 million in taxes for the three and six months ended June 30, 2016.

CONDENSED CONSOLIDATED STATEME4

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME LOSS [Abstract]
Settlements tax		$ (20)		$ (37)
Change in fair value of derivative instruments tax		$ 1		$ 8
Amortization of prior service cost and net loss included in net periodic pension cost tax			$ 1
Net gain incurred in period tax	$ 1		$ 1

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 998	$ 15
Accounts receivable, net	235	327
Derivative assets	16	3
Other current assets	29	48
Total current assets	1,278	393
Natural gas and oil properties, using the full cost method, including $3,382 million as of June 30, 2016 and $3,727 million as of December 31, 2015 excluded from amortization	22,657	22,478
Gathering systems	1,280	1,280
Other	592	606
Less: Accumulated depreciation, depletion and amortization	(18,582)	(16,821)
Total property and equipment, net	5,947	7,543
Other long-term assets	152	150
TOTAL ASSETS	7,377	8,086
Current liabilities:
Short-term debt	1	1
Accounts payable	296	513
Taxes payable	61	64
Interest payable	75	75
Dividends payable	27	27
Derivative liabilities	76	3
Other current liabilities	55	24
Total current liabilities	591	707
Long-term debt	5,767	4,704
Pension and other postretirement liabilities	51	50
Other long-term liabilities	395	343
Total long-term liabilities	6,213	5,097
Commitments and contingencies (Note 11)
Equity:
Common stock, $0.01 par value; 1,250,000,000 shares authorized; issued 392,496,825 (1) shares as of June 30, 2016 (does not include 2,100,119 shares declared as a stock dividend on June 14, 2016 to be issued on July 15, 2016) and 390,138,549 as of December 31, 2015	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 as of June 30, 2016 and December 31, 2015, conversion in January 2018
Additional paid-in capital	3,418	3,409
Accumulated deficit	(2,807)	(1,082)
Accumulated other comprehensive loss	(41)	(48)
Common stock in treasury, 31,269 shares as of June 30, 2016 and 47,149 shares as of December 31, 2015, respectively	(1)	(1)
Total equity	573	2,282
TOTAL LIABILITIES AND EQUITY	$ 7,377	$ 8,086

CONDENSED CONSOLIDATED BALANCE6

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2016		Jun. 30, 2016		Dec. 31, 2015
Natural gas and oil properties, using the full cost method, costs excluded from amortization	$ 3,382		$ 3,382		$ 3,727
Common stock, par value	$ 0.01		$ 0.01		$ 0.01
Common stock, shares authorized	1,250,000,000		1,250,000,000		1,250,000,000
Common stock, shares issued	392,496,825	[1]	392,496,825	[1]	390,138,549
Common stock, shares declared as stock dividend	2,100,119
Treasury stock, shares	31,269		31,269		47,149
Series B Preferred Stock [Member]
Preferred stock, par value	$ 0.01		$ 0.01		$ 0.01
Preferred stock, shares authorized	10,000,000		10,000,000		10,000,000
Preferred stock, dividend rate			6.25%		6.25%
Liquidation preference per share	$ 1,000		$ 1,000		$ 1,000
Preferred stock, shares issued	1,725,000		1,725,000		1,725,000
Preferred stock, shares outstanding	1,725,000		1,725,000		1,725,000
[1]	(1) Does not include 98,900,000 shares of common stock issued in July 2016.

CONDENSED CONSOLIDATED STATEME7

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Cash Flows From Operating Activities
Net loss	$ (1,725)	$ (710)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	250	603
Impairment of natural gas and oil properties	1,504	1,535
Amortization of debt issuance cost	4	49
Deferred income taxes		(451)
Loss on derivatives, net of settlement	129	71
Stock-based compensation	17	12
Gain on sale of assets, net		(277)
Restructuring charges	29
Other	7
Change in assets and liabilities:
Accounts receivable	92	162
Inventories	(7)
Accounts payable	(139)	(22)
Taxes payable	(3)	(30)
Interest payable		14
Other assets and liabilities	7	(16)
Net cash provided by operating activities	165	940
Cash Flows From Investing Activities
Capital investments	(241)	(974)
Acquisitions		(569)
Proceeds from sale of property and equipment	54	703
Other	1	10
Net cash used in investing activities	(186)	(830)
Cash Flows From Financing Activities
Payments on current portion of long-term debt	(1)	(1)
Payments on long-term debt		(500)
Payments on short-term debt		(4,500)
Payments on revolving credit facility	(3,268)	(1,534)
Borrowings under revolving credit facility	3,152	1,804
Payments on commercial paper	(242)	(1,182)
Borrowings under commercial paper	242	1,288
Change in bank drafts outstanding	(21)	(1)
Proceeds from issuance of long-term debt	1,191	2,200
Debt issuance costs	(16)	(17)
Proceeds from issuance of common stock		669
Proceeds from issuance of mandatory convertible preferred stock		1,673
Preferred stock dividend	(27)	(25)
Other	(6)
Net cash provided by (used in) financing activities	1,004	(126)
Increase (decrease) in cash and cash equivalents	983	(16)
Cash and cash equivalents at beginning of year	15	53
Cash and cash equivalents at end of period	$ 998	$ 37

CONDENSED CONSOLIDATED STATEME8

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - 6 months ended Jun. 30, 2016 - USD ($) $ in Millions	Common Stock [Member]	Preferred Stock [Member]	Additional Paid-in Capital [Member]	Accumulated Deficit [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Common Stock in Treasury [Member]	Total
Balance, shares at Dec. 31, 2015	390,138,549	1,725,000
Balance at Dec. 31, 2015	$ 4		$ 3,409	$ (1,082)	$ (48)	$ (1)	$ 2,282
Comprehensive loss:
Net loss				(1,725)			(1,725)
Other comprehensive income					7		7
Comprehensive loss							(1,718)
Stock-based compensation			42				42
Preferred stock dividend, shares	3,024,737
Preferred stock dividend			(27)				(27)
Issuance of restricted stock, shares	84,165
Cancellation of restricted stock, shares	(89,095)
Tax withholding - stock compensation, shares	(661,531)
Tax withholding - stock compensation			(6)				(6)
Balance, shares at Jun. 30, 2016	392,496,825	1,725,000
Balance at Jun. 30, 2016	$ 4		$ 3,418	$ (2,807)	$ (41)	$ (1)	$ 573

Basis Of Presentation

Basis Of Presentation	6 Months Ended
	Jun. 30, 2016
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 is also focused on creating and capturing additional value through its natural gas gathering and marketing businesses (“Midstream”). Southwestern conducts most of its businesses through subsidiaries and operates principally in two segments: E&P and Midstream.  Exploration and Production. Southwestern’s primary business is the exploration for and production of natural gas and oil, with current operations principally focused on the development of unconventional natural gas reservoirs located in Pennsylvania, West Virginia and Arkansas. The Company’s operations in northeast Pennsylvania, herein referred to as “Northeast Appalachia,” are primarily focused on the unconventional natural gas reservoir known as the Marcellus Shale. Operations in West Virginia and southwest Pennsylvania, herein referred to as “Southwest Appalachia,” are focused on the Marcellus Shale, the Utica and the Upper Devonian unconventional natural gas and oil reservoirs. Collectively, Southwestern refers to its properties located in Pennsylvania and West Virginia as the “Appalachian Basin.” The Company’s operations in Arkansas are primarily focused on an unconventional natural gas reservoir known as the Fayetteville Shale. Southwestern has exploration and production activities ongoing in Colorado and Louisiana, along with other areas in which it is currently exploring for new development opportunities. The Company also has drilling rigs located in Pennsylvania, West Virginia and Arkansas and provides oilfield products and services, principally serving its E&P operations.  Midstream. Through the Company’s affiliated midstream subsidiaries, Southwestern engage s in natural gas gathering activities in Arkansas and Louisiana. These activities primarily support the Company’s E&P operations and generate revenue from fees associated with the gathering of natural gas. Southwestern’s marketing activities capture opportunities that arise through the marketing and transportation of the natural gas, oil and NGLs produced in its E&P operations.  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, 201 5 (“2015 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 Statement s included in the Company’s 2015 Annual Report.  Certain reclassifications have been made to the prior year financial statements to conform to the 2016 presentation. The effects of the reclassifications were not material to the Company’s unaudited condensed consolidated financial statements. 

Cash And Cash Equivalents

Cash And Cash Equivalents	6 Months Ended
	Jun. 30, 2016
Cash And Cash Equivalents [Abstract]
Cash And Cash Equivalents	 (2) CASH AND CASH EQUIVALENTS  The following table presents a summary of c ash and cash equivalents as of June 30, 2016 and December 31, 2015:     June 30, December 31,  2016 2015  (in millions)   Cash $ 12 $ 15  Marketable securities (1) 986 –  Total cash and cash equivalents $ 998 $ 15 (1) Consists of money market funds . 

Reduction In Workforce

Reduction In Workforce	6 Months Ended
	Jun. 30, 2016
Reduction In Workforce [Abstract]
Reduction In Workforce	(3) REDUCTION IN WORKFORCE  In January 2016, the Company announced a 40% workforce reduction of approximately 1,100 employees as a result of lower anticipated drilling activity. This reduction was substantially complete d in the first quarter of 2016 . In April 2016, the Company also partially restructured executive management, which was substantially completed in the second quarter of 2016.  The following table presents a summary of the restructuring charges for the three and six months ended June 3 0 , 2016:    For the three months ended For the six months ended  June 30, 2016 June 30, 2016  (in millions)  Severance (including payroll taxes) (1) $ 2 $ 44  Stock-based compensation (2) 6 24 Pension and other postretirement benefits (3) 3 3  Other benefits – 3  Outplacement services, other – 1  Total restructuring charges (4) $ 11 $ 75 (1) Includes $1 million related to executive management restructuring for the three and six months ended June 30, 2016. (2) Includes $3 million related to executive management restructuring for the three and six months ended June 30, 2016. (3) Includes non-cash charges related to the curtailment and settlement of the pension and other postretirement benefit plans. See Note 12 for additional details regarding the Company’s retirement and employee benefit plans. (4) Total restructuring charges were $11 million and less than $1 million for the Company’s E&P and Midstream segments, respectively, for the three months ended June 30, 2016. For the six months ended June 30, 2016, restructuring charges were $72 million and $3 million for the Company’s E&P and Midstream segments, respectively.  The following table presents a summary of liabilities associated with the Company’s restructuring activities at June 30, 2016, which are reflected in accounts payable on the unaudited condensed consolidated balance sheet (in millions):    Liability at March 31, 2016 $ 24  Additions 2  Distributions (24)  Liability at June 30, 2016 $ 2  Severance payments and other separation costs related to restructuring will be completed by the end of the fourth quarter, resulting in the recognition of approximately $0.5 million of additional expense in the second half of 2016.    

Acquisitions And Divestitures

Acquisitions And Divestitures	6 Months Ended
	Jun. 30, 2016
Acquisitions And Divestitures [Abstract]
Acquisitions And Divestitures	(4) ACQUISITIONS AND DIVESTITURES  In June 2016, the Company entered into a definitive agreement with Antero Resources Corporation to sell approximately 55,000 net acres in West Virginia for $450 million, subject to customary adjustments. The net book value of these assets is in the full cost pool and was held in the E&P segment as of June 30, 2016. The transaction is expected to close in the third quarter of 2016, subject to customary closing conditions and purchase price adjustments. At June 30, 2016, a $45 million deposit from Antero Resources Corporation was included in other current liabilities within the unaudited condensed consolidated balance sheet. The Company intends to use $375 million of proceeds from the sale for general corporate purposes, including to fund capital projects, and to use the remainder to reduce indebtedness.  In May 2015, the Company sold conventional oil and gas assets located in East Texas and the Arkoma Basin for approximately $ 211 million. The net book value of these assets was primarily in the full cost pool and was held in the E&P segment as of the closing date. The proceeds from the transaction were used to reduce the Company’s debt. Approximately $ 205 million of the proceeds received were recorded as a reduction of the capitalized costs of the Company’s natural gas and oil properties in the United States pursuant to the full cost method of accounting.  In April 2015, the Company sold its gathering assets located in Bradford and Lycoming counties in northeast Pennsylvania to Howard Midstream Energy Partners, LLC for an adjusted sales price of approximately $ 489 million. The net book value of these assets was $206 million and was held in the Midstream segment as of the closing date. A gain on sale of $ 283 million was recognized and is included in gain on sale of assets, net on the unaudited condensed consolidated statement of operations. The assets include d approximately 100 miles of natural gas gathering pipelines, 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 .  In January 2015, the Company completed an acquisition of certain natural gas and oil assets including approximately 46,700 net acres in northeast Pennsylvania from WPX Energy, Inc. for an adjusted purchase price of $270 million (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. The firm transport is being amortized over 19 years. As of June 3 0 , 2016 and December 31, 2015 the Company has amortized $13 million and $8 million, respectively. This transaction was funded with the revolving credit facility and was accounted for as a business combination.  In January 2015, the Company completed an acquisition of certain natural gas and oil assets from Statoil ASA covering approximately 30,000 acres in West Virginia and southwest Pennsylvania comprising approximately 20% of Statoil’s interests in that acreage for $ 357 million, (the “Statoil Property Acquisi tion”). All of these assets were also assets in which the Company had 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 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, NGLs and crude oil contained in the Upper Devonian, Marcellus and Utica Shales for approximately $5.0 billion (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. 

Natural Gas And Oil Properties

Natural Gas And Oil Properties	6 Months Ended
	Jun. 30, 2016
Natural Gas And Oil Properties [Abstract]
Natural Gas And Oil Properties	( 5 ) NATURAL GAS AND OIL PROPERTIES  The Company utilizes the full cost method of accounting for costs related to the exploration, development an d acquisition of natural gas and oil properties . Under this method, all such costs (productive and nonproductive), including salaries, benefits and other internal costs directly attributable to these activities a re 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 are subject to a ceiling test that limits such pooled costs , net of applicable deferred taxes, to the aggregate of the present value of future net revenues attributable to proved natural gas , oil and NGL reserves discounted at 10 % (standardized measure) 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, oil and NGL prices may subsequently increase the ceiling. Companies using the full cost method are required to use the average quoted price from the first day of each month from the previous 12 months, incl uding the impact of derivatives designated for hedge accounting , 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 $ 2.24 per MMBtu, West Texas Intermediate oil of $ 39.63 per barrel and NGLs of $ 5.87 per barrel, adjusted for market differentials, the Company’s net book value of its United States and Canada natural gas and oil properties exceeded the ceiling by $297 million (net of tax) at June 30 , 2016 and resulted in a non-cash ceiling test impairment. The Company had no hedge positions that were designated for hedge account ing as of June 3 0 , 2016. 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 average quoted price from the first day of each month from the previous 12 months for Henry Hub natural gas of $ 3.39 per MMBtu, West Texas Intermediate oil of $ 68.17 per barrel and NGLs of $12.53 per barrel , adjusted for market differentials, the net book value of the Company’s United States natura l gas and oil properties exceed ed the ceiling by $944 million (net of tax) at June 30, 2015 and result ed in a non-cash ceiling test impairment . Cash flow hedges of natural gas production in place increased the ceiling amount by approximately $60 million as of June 30, 2015 . In the third and fourth quarters of 2015, the Company’s net book value of its United States natural gas and oil properties exceeded the ceiling by approximately $1,746 million (net of tax) at September 30, 2015 and $1,586 million (net of tax) at December 31, 2015 , resulting in non-cash ceiling test impairments in each quarter . In the first quarter of 2016, the Company’s net book value of its United States natural gas and oil properties exceeded the ceiling by approximately $641 million (net of tax) at March 31, 2016, resulting in a non-cash ceiling test impairment in the quarter. 

Earnings Per Share

Earnings Per Share	6 Months Ended
	Jun. 30, 2016
Earnings Per Share [Abstract]
Earnings Per Share	( 6 ) 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 the reportable period . 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 , the assumed conversion of mandatory convertible preferred stock and the shares of common stock declared as a preferred stock dividend . 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 July 2016, the Company completed an underwritten public offering of 98,900,000 shares of its common stock, with an offering price to the public of $13.00 per share. Net proceeds, after underwriting discount and offering expenses, from the common stock offering were approximately $1,247 million. The proceeds from the offering were used to repay $375 million of the $750 million term loan entered into in November 2015 and to settle certain tender offers by purchasing an aggregate principal amount of approximately $700 million of the Company’s outstanding senior notes due in the first quarter of 2018. The remaining proceeds of the offering will be used for general corporate purposes. The 98,900,000 shares of common stock were issued in July 2016 and are therefore not included in the outstanding common stock share counts or earnings per share calculations for the quarter ended June 30, 2016.  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 pref erred stock entitles the holder 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 total potential shares of common stock resulting from the conversion will range from 63,829,830 to 74,999,895 shares.  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. A ccordingly , 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 Company’s participating securities do not participate in undistributed net losses because they are not contractually obligated to do so.  On June 14, 2016 , the Company declared its quarterly dividend, payable to holders of the mandatory convertible preferred stock, and announced that it would pay the dividend in common stock, in lieu of cash, to the extent permitted by the certificate of designations for the Series B preferred stock. The Company issued 2,100,119 shares of common stock on July 15, 2016 in payment for the dividend .  The following table presents the computation of earnings per share for the three and six months ended June 30 , 201 6 and 201 5 :      For the three months ended For the six months ended  June 30, June 30,  2016 2015 2016 2015  (in millions, except share/per share amounts)  Net loss $ (593) $ (788) $ (1,725) $ (710)  Mandatory convertible preferred stock dividend 27 27 54 52  Net loss attributable to shareholders $ (620) $ (815) $ (1,779) $ (762)   Number of common shares:  Weighted average outstanding 385,594,815 382,114,011 384,232,831 378,797,446  Issued upon assumed exercise of outstanding stock options (1) – – – –  Effect of issuance of non-vested restricted common stock (2) – – – –  Effect of issuance of non-vested performance units (3) – – – –  Effect of issuance of mandatory convertible preferred stock (4) – – – –  Effect of declaration of preferred stock dividends (5) – – – –  Weighted average and potential dilutive outstanding 385,594,815 382,114,011 384,232,831 378,797,446   Loss per common share (6) :  Basic $ (1.61) $ (2.13) $ (4.63) $ (2.01)  Diluted $ (1.61) $ (2.13) $ (4.63) $ (2.01) (1) Due to the net loss for the three and six months ended June 30 , 2016 and 2015 , the unvested stock options were not recognized in diluted earnings per share calculations as they would be antidilutive. Options for 4,028,819 shares and 4,781,109 shares were excluded from the calculation of diluted shares for the three and six months ended June 30, 2016, respectively, because they would have had an antidilutive effect. Options for 3,832,533 shares and 3,768,666 shares were excluded from the calculation of diluted shares for the three and six months ended June 30, 2015, respectively, because they would have had an antidilutive effect. (2) Due to the net loss for the three and six months ended June 30, 2016 and 2015 , the unvested share-based payments were not recognized in diluted earnings per share calculations as they would be antidilutive. The calculation excluded 3,353, 371 shares and 2,844, 365 shares of restricted stock for the three and six months ended June 30, 2016, respectively, because they would have had an antidilutive effect. The calculation excluded 1,507,788 shares and 1,787,257 shares of restricted stock for the three and six months ended June 30, 2015, respectively, because they would have had an antidilutive effect. (3) Due to the net loss f or the three and six months ended June 30 , 2016, 780,920 shares and 577,624 shares, respectively, of performance units were excluded from the calculation of diluted earnings per share as they would have had an antidilutive effect. Due to the net loss for the three and six months ended June 30, 2015, the calculation excluded 129,202 shares and 116,185 shares, respectively, of performance units as they would have had an antidilutive effect. (4) Due to the net loss f or the three and six months ended June 30 , 2016, 74,999,895 of weighted average common shares issuable upon the assumed conversion of the mandatory convertible preferred stock were excluded from the diluted earnings per sh are calculation , respectively, as they would be antidilutive. Due to the net loss for the three and six months ended June 30, 2015, 72,723,440 and 64,687,701 of weighted average common shares issuable upon the assumed conversion of the mandatory convertible preferred stock were excluded from the diluted earnings per sh are calculation , respectively, as they would be antidilutive. (5) Due to the net loss for the three months ended June 30, 2016, 2,100,119 shares of common stock declared as preferred stock dividends were excluded from the diluted earnings per share calculations as they would have had an antidilutive effect. (6) Does not include the effect of 98,900,000 shares of common stock issued in July 2016. 

Derivatives And Risk Management

Derivatives And Risk Management	6 Months Ended
	Jun. 30, 2016
Derivatives And Risk Management [Abstract]
Derivatives And Risk Management	(7 ) DERIVATIVES AND RISK MANAGEMENT  The Company is exposed to volatility in market prices and basis di fferentials for natural gas, oil and NGLs which impacts the predictability of its cash flows related to the sale of those commodities . These risks are managed by the Company’s use of certain derivative financial instruments. As of June 3 0, 2016 , the Company’s derivative financial instruments consisted of fixed price swaps, purchased put options, two-way costless collars, three-way costless collars, basis swaps, sold call options and interest rate swaps. The Company had basis swaps and sold call options as of December 31, 2015. 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.  Purchased put options The Company purchases put options from the counterparty by payment of a cash premium. If the market price is lower than the put’s strike price at the time of settlement, the Company receives from the counterparty such difference on purchased put options. If the market price settles above the put’s strike price, no payment is due from either party.  Two-way costless collars Arrangements that contain a fixed floor price (purchased put option) and a fixed ceiling price (sold call option). At the contract settlement date, (1) if the index price is higher than the ceiling price, the Company pays the counterparty the difference between the index price and ceiling price, (2) if the index price is between the floor price and the ceiling price, no payments are due from either party, and (3) if the index price is below the floor price, the Company will receive the difference between the floor price and the index price.  Three-way costless collars Arrangements that contain a two-way costless collar and a sold put option. At the contract settlement date, (1) if the index price is higher than the ceiling price, the Company pays the counterparty the difference between the index price and ceiling price, (2) if the index price is between the middle strike price and the ceiling price, no payments are due from either party, (3) if the index is between the lowest strike price and the middle strike price, the Company will receive the difference between the middle strike price and the index price, and (4) if the index price is below the floor price, the Company will receive the difference between the purchased put strike price and the sold put strike price.  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.  Sold call options The Company sells call options in exchange for a premium. I f the market price exceeds the strike price of the call option a t the time of settlement, the Company pays the counterparty such excess on sold call options. If the market price settles below the call’s strike price , 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 un favorable interest rate changes.  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 following table provides information about the Company’s financial instruments that are sensitive to changes in commodity prices and that are used to protect the Company’s exposure. None of the financial instruments below are designated for hedge accounting treatment. The table presents the notional amount in Bcf, the weighted average contract prices and the fair value by expected maturity dates as of June 30, 2016.     Weighted Average Price per MMBtu  Volume (Bcf) Swaps Sold Puts Purchased Puts Sold Calls Basis Differential Fair value at June 30, 2016 ($ in millions)  Financial protection on production  2016  Fixed price swaps 61 $ 2.57 $ – $ – $ – $ – $ (24)  Purchased put options 17 $ – $ – $ 2.34 $ – $ – $ –  Two-way costless collars 12 $ – $ – $ 2.76 $ 3.35 $ – $ (1)  Basis swaps 7 $ – $ – $ – $ – $ 0.36 $ 5  Total 97 $ (20)  2017  Fixed price swaps 144 $ 3.07 $ – $ – $ – $ – $ (16)  Two-way costless collars 47 $ – $ – $ 2.90 $ 3.33 $ – $ (4)  Three-way costless collars 18 $ – $ 2.25 $ 2.75 $ 3.56 $ – $ (2)  Basis swaps 15 $ – $ – $ – $ – $ 0.02 $ (6)  Total 224 $ (28)   Sold call options  2016 60 $ – $ – $ – $ 5.00 $ – $ –  2017 86 $ – $ – $ – $ 3.25 $ – $ (30)  2018 63 $ – $ – $ – $ 3.50 $ – $ (18)  2019 52 $ – $ – $ – $ 3.50 $ – $ (17)  2020 32 $ – $ – $ – $ 3.75 $ – $ (10)  Total 293 $ (75)  The balance sheet classification of the assets related to derivative financial instruments (none of which are designated for hedge accounting) are summarized below as of June 3 0, 2016 a nd December 31, 2015 :     Derivative Assets  Balance Sheet Classification Fair Value  June 30, 2016 December 31, 2015  (in millions)  Derivatives not designated as hedging instruments: Fixed price swaps Derivative assets $ 1 $ –  Two-way costless collars Derivative assets 6 –  Three-way costless collars Derivative assets 2 –  Basis swaps Derivative assets 7 3  Two-way costless collars Other long-term assets 6 –  Three-way costless collars Other long-term assets 2 –  Total derivative assets $ 24 $ 3   Derivative Liabilities  Balance Sheet Classification Fair Value  June 30, 2016 December 31, 2015  (in millions)  Derivatives not designated as hedging instruments:  Fixed price swaps Derivative liabilities $ 36 $ –  Two-way costless collars Derivative liabilities 10 –  Three-way costless collars Derivative liabilities 3 –  Basis swaps Derivative liabilities 8 –  Sold call options Derivative liabilities 16 –  Interest rate swaps Derivative liabilities 3 3  Fixed price swaps Other long-term liabilities 5 –  Two-way costless collars Other long-term liabilities 7 –  Three-way costless collars Other long-term liabilities 3 –  Sold call options Other long-term liabilities 59 –  Interest rate swaps Other long-term liabilities 5 2  Total derivative liabilities $ 155 $ 5  At June 30, 2016, the net fair value of the Company’s financial instruments related to natural gas was a $123 million liability . The net fair value of the Company’s interest rate swaps was an $8 million liability at June 30, 2016.  Derivative Contracts not Designated for Hedge Accounting  As of June 30 , 2016, the Company did not have any positions designated for hedge accounting treatment . G ains and losses on derivatives that are not designated for hedge accounting treatment , or that do not meet hedge accounting requirements , are recorded as a component of gain (loss) on derivatives on the unaudited condensed consolidated statements of operations . Accordingly, the gain (loss) on derivatives component of the statement s of operations reflects the gains and losses on both settled and unsettled derivatives. The Company calculates gains and losses on settled derivatives as the summation of gains and losses on positions which have settled within the reporting period. Only the settled gains and losses are included in the Company’s realized commodity price calculations.  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 have 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 unaudited condensed consolidated statements of operations.  The following tables summarize the before tax effect of fixed price swaps, purchased put options, two-way costless collars, three-way costless collars, basis swaps, sold call options , and interest rate swaps not designated for hedge accounting on the unaudited condensed consolidated statements of operations for the three and six months ended June 30 , 201 6 and 201 5 :    Gain (Loss) on Derivatives, Unsettled  Recognized in Earnings  Consolidated Statement of Operations For the three months ended For the six months ended  Classification of Gain (Loss) June 30, June 30,  Derivative Instrument on Derivatives, Unsettled 2016 2015 2016 2015  (in millions)  Fixed price swaps Gain (Loss) on Derivatives $ (60) $ (55) $ (40) $ (73)  Purchased put options Gain (Loss) on Derivatives (15) – – –  Two-way costless collars Gain (Loss) on Derivatives (5) – (5) –  Three-way costless collars Gain (Loss) on Derivatives (2) – (2) –  Basis swaps Gain (Loss) on Derivatives (1) 3 (4) (5)  Sold call options Gain (Loss) on Derivatives (25) – (75) 8  Interest rate swaps Gain (Loss) on Derivatives – 2 (3) (1)  Total loss on unsettled derivatives $ (108) $ (50) $ (129) $ (71)   Gain (Loss) on Derivatives, Settled (1)  Recognized in Earnings  Consolidated Statement of Operations For the three months ended For the six months ended  Classification of Gain (Loss) June 30, June 30,  Derivative Instrument on Derivatives, Settled 2016 2015 2016 2015  (in millions)  Fixed price swaps Gain (Loss) on Derivatives $ 12 $ 52 $ 16 $ 94  Purchased put options Gain (Loss) on Derivatives 11 – 11 –  Basis swaps Gain (Loss) on Derivatives – – 4 (6)  Interest rate swaps Gain (Loss) on Derivatives – (1) (1) (2)  Total gain on settled derivatives (2) $ 23 $ 51 $ 30 $ 86   Total gain (loss) on derivatives $ (85) $ 1 $ (99) $ 15  (1) T he Company calculates gain (loss) on derivatives, settled, as the summation of gains and losses on positions that have settled within the period . (2) Excluding interest rate swaps, t hese amounts are included, along with gas sales revenues, in the calculation of the Company’s realized natural gas price .  Derivative Contracts Designated for Hedge Accounting  A ll 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 designated for hedge accounting . Accounting guidance for qualifying hedges allows an unsettled derivative’s unrealized gains and losses to be recorded either in earnings or as a component of other comprehensive income until settled. In the period of settlement, the Company recognizes the gains and losses from these qualifying hedges in gas sales revenues. As of June 30 , 2016, the Company did not have any positions designated for hedge accounting treatment . In 2015, the Company had certain fixed price swaps that were designated for hedge accounting. For the three and six months ended June 3 0 , 2 015, the Company reported a loss in other comprehensive income of $3 million (pre-tax) and a gain in other comprehensive income of $21 million (pre-tax), respectively, related to the effective portion of our unsettled fixed price swaps. The ineffective portion of those fixed price swaps was recognized in earnings and had an inconsequential impact to the unaudited condensed consolidated statement of operations for the three and six months ended June 30 , 2015. For the three and six months ended June 30, 2015 , a gain of $53 million (pre-tax) and a gain of $95 million (pre-tax), respectively, on settled fixed price swaps was transferred from other comprehensive income into gas sales revenues in the consolidated statements of operations.

Reclassifications From Accumula

Reclassifications From Accumulated Other Comprehensive Income (Loss)	6 Months Ended
	Jun. 30, 2016
Reclassifications From Accumulated Other Comprehensive Income (Loss) [Abstract]
Reclassifications From Accumulated Other Comprehensive Income (Loss)	(8 ) RECLASSIFICATIONS FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)  The following tables detail the components of accumulated other comprehensive income (loss) and the related tax effects for the six months ended June 3 0 , 201 6 :     June 30, 2016  Pension and Other Postretirement Foreign Currency Total  (in millions) (1)  Beginning balance at December 31, 2015 $ (25) $ (23) $ (48)  Other comprehensive income before reclassifications 4 3 7  Amounts reclassified from/to other comprehensive income (loss) (2) – – –  Net current-period other comprehensive income (loss) 4 3 7  Ending balance at June 30, 2016 $ (21) $ (20) $ (41) (1) All amounts are net of tax. (2) See separate table below for details about these reclassifications . 1       Details about Accumulated Other Comprehensive Income Affected Line Item in the Consolidated Statement of Operations Amount Reclassified from Accumulated Other Comprehensive Income  For the six months ended June 30, 2016  (in millions)  Pension and other postretirement  Amortization of prior service cost and net loss (1) General and administrative expenses $ 1  Provision (benefit) for income taxes 1  Total reclassifications for the period Net loss $ –  (1) See Note 12 for additional details regarding the Company’s retirement and employee benefit plans. 

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2016
Fair Value Measurements [Abstract]
Fair Value Measurements	( 9 ) FAIR VALUE MEASUREMENTS  The carrying amounts and estimated fair values of the Company’s financial instruments as of June 3 0 , 201 6 and December 31, 201 5 were as follows:    June 30, 2016 December 31, 2015  Carrying Fair Carrying Fair  Amount Value Amount Value  (in millions)  Cash and cash equivalents $ 998 $ 998 $ 15 $ 15  Credit facility – – 116 116  Term loan facility due 2018 744 744 747 747  Term loan facility due 2020 1,180 1,180 – –  Senior notes 3,844 3,580 3,842 2,651  Derivative instruments, net (131) (131) (2) (2)  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 approxim ate 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 value 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 and term loan facilities 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 June 30, 2016 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 sold call options, purchased put options, two-way costless collars and three-way costless collars (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 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.  Assets and liabilities measured at fair value on a recurring basis are summarized below (in millions):    June 30, 2016  Fair Value Measurements Using:  Quoted Prices Significant  in Active Significant Other Unobservable  Markets Observable Inputs Inputs Assets (Liabilities)  (Level 1) (Level 2) (Level 3) at Fair Value Fixed price swap assets $ – $ 1 $ – $ 1  Two-way costless collars assets – – 12 12  Three-way costless collars assets – – 4 4  Basis swap assets – – 7 7  Fixed price swap liabilities – (41) – (41) Two-way costless collars liabilities – – (17) (17)  Three-way costless collars liabilities – – (6) (6)  Basis swap liabilities – – (8) (8)  Sold call option liabilities – – (75) (75)  Interest rate swap liabilities – (8) – (8)  Total $ – $ (48) $ (83) $ (131)   December 31, 2015  Fair Value Measurements Using:  Quoted Prices Significant Other Significant  in Active Markets Observable Inputs Unobservable Inputs Assets (Liabilities)  (Level 1) (Level 2) (Level 3) at Fair Value  Basis swap assets $ – $ – $ 3 $ 3  Interest rate swap liabilities – (5) – (5)  Total $ – $ (5) $ 3 $ (2)  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 unobse rvable inputs (Level 3) for the three and six months ended June 3 0 , 201 6 and 2015. 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 June 30, 2016 and 2015.            For the three months ended For the six months ended  June 30, June 30,  2016 2015 2016 2015  (in millions)  Balance at beginning of period $ (35) $ (8) $ 3 $ (8)  Total gains (losses):  Included in earnings (37) 3 (71) (3)  Purchases, issuances, and settlements:  Settlements (11) – (15) 6  Transfers into/out of Level 3 – – – –  Balance at end of period $ (83) $ (5) $ (83) $ (5)  Change in gains (losses) included in earnings relating to derivatives still held as of June 30 $ (48) $ 3 $ (86) $ 3  

Debt

Debt	6 Months Ended
	Jun. 30, 2016
Debt [Abstract]
Debt	( 10 ) DEBT  The c omponents of debt as of June 30 , 201 6 and December 31, 201 5 consisted of the following:      June 30, 2016  Debt Instrument Unamortized Issuance Cost Unamortized Debt Discount Total  (in millions) Short-term debt:  7.15% Senior Notes due June 2018 $ 1 $ – $ – $ 1  Total short-term debt $ 1 $ – $ – $ 1   Long-term debt:  Variable rate ( 2.930% at June 30, 2016) term loan facility, due November 2018 (1) 750 (6) – 744  Variable rate ( 2.940% at June 30, 2016) term loan facility, due December 2020 1,191 (11) – 1,180  7.35% Senior Notes due October 2017 15 – – 15  7.125% Senior Notes due October 2017 25 – – 25  3.3% Senior Notes due January 2018 (2) 350 (1) – 349  7.5% Senior Notes due February 2018 (2) 600 (1) – 599  7.15% Senior Notes due June 2018 25 – – 25  4.05% Senior Notes due January 2020 (2) 850 (5) – 845  4.10% Senior Notes due March 2022 1,000 (5) (1) 994  4.95% Senior Notes due January 2025 1,000 (7) (2) 991  Total long-term debt $ 5,806 $ (36) $ (3) $ 5,767   Total debt $ 5,807 $ (36) $ (3) $ 5,768    December 31, 2015  Debt Instrument Unamortized Issuance Cost Unamortized Debt Discount Total  (in millions) Short-term debt:  7.15% Senior Notes due June 2018 $ 1 $ – $ – $ 1  Total short-term debt $ 1 $ – $ – $ 1   Long-term debt:  Variable rate ( 1.886% at December 31, 2015) credit facility, expires December 2018 116 – – 116  Variable rate ( 1.775% at December 31, 2015) term loan facility, due November 2018 (1) 750 (3) – 747  7.35% Senior Notes due October 2017 15 – – 15  7.125% Senior Notes due October 2017 25 – – 25  3.3% Senior Notes due January 2018 (2) 350 (2) – 348  7.5% Senior Notes due February 2018 (2) 600 (2) – 598  7.15% Senior Notes due June 2018 26 – – 26  4.05% Senior Notes due January 2020 (2) 850 (5) (1) 844  4.10% Senior Notes due March 2022 1,000 (5) (1) 994  4.95% Senior Notes due January 2025 1,000 (7) (2) 991  Total long-term debt $ 4,732 $ (24) $ (4) $ 4,704   Total debt $ 4,733 $ (24) $ (4) $ 4,705  (1) In July 2016, $375 million was repaid on the term loan facility, extending the maturity from November 2018 to December 2020.  (2) In July 2016, the Company purchased approximately $312 million of the 3.3% Senior Notes due January 2018 and $388 million of the 7.5% Senior Notes due February 2018.  2016 Credit Facility  In June 2016, the Company reduced its existing $2.0 billion unsecured revolving credit facility down to $66 million and entered into a new credit agreement for $1,934 million, consisting of a $1,191 million secured term loan and a new $743 million unsecured revolving credit facility, which matures in December 2020 . The $1,191 million secured term loan is fully drawn, with approximately $285 million of this balance used to pay down the previous revolving credit facility balance in its entirety. As of June 30, 2016, there were no borrowings under either revolving credit facilit y , however, there was $169 million in letters of credit outstanding against the 2016 revolving credit facility.  Loans under the 2016 credit agreement are subject to varying rates of interest based on whether the loan is a Eurodollar loan or an alternate base rate loan. Eurodollar loans bear interest at the Eurodollar rate, which is adjusted LIBOR plus applicable margins ranging from 1.750% to 2.500% . Alternate base rate loans bear interest at the alternate base rate plus the applicable margin ranging from 0.750% to 1.500% . The interest rate on the term loan facility is determined based upon the Company’s public debt ratings and was 250.0 basis points over the London Interbank Offered Rate (“LIBOR”) as of June 30, 2016.  The new term loan and revolving credit facility contains financial covenants that impose certain restrictions on the Company. Under the 2016 credit facility, the Company must keep a minimum interest coverage of 0.75x in 2016, increasing by 0.25x increments to 1.50x in 2019 and 2020 . The Company is also subject to a minimum liquidity requirement of $300 million, which could be increased up to $500 million upon certain conditions, as well as an anti-hoarding provision, requiring unrestricted cash in excess of $100 million to pay down any amounts borrowed under the new revolving credit facility. The financial covenant with respect to minimum interest coverage consists of EBITDAX divided by consolidated interest expense. EBITDAX excludes the effects of interest expense, income taxes, depreciation, depletion and amortization, any non-cash impacts from impairments, certain non-cash hedging activities, stock-based compensation expense, non-cash gains or losses on asset sales, unamortized issuance cost, unamortized debt discount and restructuring costs. Collateral for the new secured term loan is principally E&P properties in the Fayetteville Shale area. This collateral also may support all or a part of revolving credit extensions depending on restrictions in the Company’s senior notes indentures and requires a minimum collateral coverage ratio of 1.50x .  The existing unsecured 2013 revolving credit facility includes a financial covenant under which the Company may not have 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, certain hedging activities and the Company’s pension and other postretirement liabilities.  A s of June 30, 2016 , the Company was in compliance with all of the covenants of the term loan and revolving credit facilities. Although the Company does not anticipate any violations of the financial covenants, its ability to comply with these covenants is dependent upon the success of its exploration and development program and upon factors beyond the Company’s control, such as the market prices for natural gas and oil.  2013 Credit Facility  In December 2013, we entered into a credit agreement that exchanged our previous revolving credit facility. Under the revolving credit facility, we had a borrowing capacity of $2.0 billion. The revolving credit facility was unsecured and was not guaranteed by any of our subsidiaries. In June 2016, this credit facility was substantially exchanged for a new credit facility comprised of a $1,191 m illion secured term loan and a new $743 m illion revolving credit facility. The borrowing capacity of the original 2013 credit agreement was reduced from $2.0 billion to $66 million , remains unsecured and the maturity remain s December 2018 . As of June 30, 2016, there we re no borrowings under this facility.  2015 Term Facility  In November 2015, the Company entered into a $750 million unsecured three -year term loan credit agreement with various lenders that was utilized to repay borrowings under the revolving credit facility. The interest rate on the term loan facility is determined based upon the Company’s public debt ratings from Moody’s and S&P and was 250.0 basis points over LIBOR as of June 30, 2016. The term loan facility requires prepayment unde r certain circumstances from the net cash proceeds of sales of equity or certain assets and borrowings outside the ordinary course of business. In June 2016, the 2015 term loan agreement was amended to extend the maturity date upon a repayment threshold. As a result of the July 2016 equity offering, the Company repaid $375 million of the $750 million term loan, which had the effect of extending the term loan maturity from November 2018 to December 2020.  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 $1.0 billion aggregate principal amount of its 4.95% senior notes due 2025 (the “2025 Notes” together with the 2018 and 2020 Notes, the “Notes”), with net proceeds from the offering totaling approximately $2.2 billion after underwriting discounts and offering expenses. 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 . 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 interest rates on the Notes are determined based upon the public bond ratings from Moody’s and S&P. Downgrades on the Notes from either rating agency increase interest costs by 25.0 basis points per downgrade level on the following semi-annual bond interest payment. In February and June 2016, Moody’s and S&P downgraded the Notes, increasing the interest rates by 175.0 basis points effective July 2016. T he first higher interest rate coupon payment to bondholders will be paid in January 2017 . On July 20, 2016, the Company used a portion of the proceeds from the July 2016 equity offering to settle certain tender offers by purchasing an aggregate principal amount of approximately $700 million of the Company’s outstanding senior notes due in the first quarter of 2018. 

Commitments And Contingencies

Commitments And Contingencies	6 Months Ended
	Jun. 30, 2016
Commitments And Contingencies [Abstract]
Commitments And Contingencies	(1 1 ) COMMITMENTS AND CONTINGENCIES  Operating Commitments and Contingencies  As of June 30, 2016, the Company’s contractual obligations for demand and similar charges under firm transportation and gathering agreements to guarantee access capacity on natural gas and liquids pipelines and gathering systems totaled approximately $ 8.6 billion, $3.3 billion of which related to access capacity on future pipeline and gathering infrastructure projects that still require the granting of regulatory approvals and additional construction efforts. The Company also had guarantee obligations of up to $ 861 million of that amount. As of June 30, 2016, future payments under non-cancelable firm transportation and gathering agreements are as follows:      Payments Due by Period  Total Less than 1 Year 1 to 3 Years 3 to 5 Years 5 to 8 Years More than 8 Years  (in millions)  Infrastructure Currently in Service $ 5,243 $ 561 $ 1,136 $ 883 $ 852 $ 1,811  Pending Regulatory Approval and/or Construction (1) 3,338 13 231 452 672 1,970  Total Transportation Charges $ 8,581 $ 574 $ 1,367 $ 1,335 $ 1,524 $ 3,781  (1) Based on the estimated in-service dates as of June 30, 2016.  In March 2010, the Company successfully bid for exclusive licenses from the Department of Natural Resources of New Brunswick to search and conduct an exploration program covering 2,518,518 net acres in the province in order to test new hydrocarbon basins. In 2015, the provincial government in New Brunswick announced a moratorium on hydraulic fracturing until it is satisfied with a list of conditions. In response to this moratorium, the Company requested and was granted an extension of its licenses to March 2021. In May 2016, the provincial government announced that the moratorium would continue in effect indefinitely. Unless and until the moratorium is lifted, Southwestern will not be able to continue with its program in New Brunswick, and given this development th e Company ha s recognized an impairment of $39 million, net of tax, associated with its investment in New Brunswick in the second quarter of 2016.  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 results of operations of the Company.  Litigation  The Company is subject to various 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 inhe rent uncertainties; therefore, m anagement’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.  Berry-Helfand (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., then pending in the 273rd District Court in Shelby County, Texas. The plaintiff alleged that the subsidiary used information provided by the plaintiff under a confidentiality agreement, which she claimed, among other things, breached the agreement and constituted a misappropriation of a trade secret. Following a trial in December 2010, the court awarded approximately $11 million in actual damages and approximately $24 million in disgorgement of profits. Both sides appealed, and in July 2013 the Texas Court of Appeals for the Twelfth District reversed on all claims except misappropriation of trade secrets, reduced the judgment to the actual damages award and ordered the case remanded for an award of attorneys’ fees to the Company’s subsidiary on one of the claims on which judgment was reversed. Both parties petitioned the Supreme Court of Texas for review. On June 10, 2016, the Supreme Court ruled that insufficient evidence supported the damage award and remanded the case for a new trial. The date for the new trial has not yet been set. The Company’s subsidiary continues to deny that it breached any obligation or misappropriated any trade secret, the only two remaining claims. Based on the Company’s understanding and judgment of the facts and merits of this case, 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. The Company’s assessment may change in the future depending on further court proceedings, 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, fi nancial 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 the Company’s 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. 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 have appealed those orders. Oral argument has not yet been set in either case.  On November 17, 2015, the court in the federal case denied the plaintiff’s motion to certify a class of royalty owners not included in either of the two state cases. On April 11, 2016, the court certified a broader class that includes Arkansas residents and citizens . The plaintiff in the federal case presented two alternative damages theories. Under one theory, plaintiffs have asserted that obligations to affiliates are not “incurred” and therefore the exploration and production subsidiary was not entitled to deduct any post-production costs; the federal court has granted partial summary judgment for the Company’s subsidiaries on this theory. Under another theory, plaintiffs assert that the gathering and treating rates the Company deducted from royalty payments exceeded the affiliates’ actual costs or otherwise were not reasonable. The plaintiffs have not disclosed a specific damage calculation for any putative class, but based on the class representative’s disclosure regarding the calculation of claimed damages, class-wide damages could exceed $100 million. Although trial previously was set for March 15, 2016, following transfer to a different judge and the certification of the class described above, that trial date has been vacated and no new date set.  In addition, in September 2015 three cases were filed in Arkansas state court on behalf of a total of 248 individually named plaintiffs. Each case asserts complaints that are in substance virtually identical to the above-described case. The Company and its subsidiaries have removed two of the cases to federal court, and those cases have been assigned to the court in which the above-described federal case is pending. All three cases have been stayed.  Management believes that, in all of the above cases, 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.  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 Postreti

Pension Plan And Other Postretirement Benefits	6 Months Ended
	Jun. 30, 2016
Pension Plan And Other Postretirement Benefits [Abstract]
Pension Plan And Other Postretirement Benefits	 (1 2 ) 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 and six months ended June 30, 2016 and 2015 :    Pension Benefits  For the three months ended For the six months ended  June 30, June 30,  2016 2015 2016 2015  (in millions)  Service cost $ 2 $ 4 $ 6 $ 8  Interest cost 1 2 3 3  Expected return on plan assets (1) (2) (3) (4)  Amortization of prior service cost – – – –  Amortization of net loss 1 – 1 1 Curtailment loss 1 – 1 –  Settlement loss 8 – 8 –  Net periodic benefit cost $ 12 $ 4 $ 16 $ 8  In January 2016, the Company initiated a reduction in workforce that was effectively completed by the end of the first quarter . As a result of the workforce reduction, the Company recognized a $1 million non-cash curtailment loss related to its pension plan for both the curtailment-related decrease to the benefit obligation and the recognition of the proportionate share of unrecognized prior service cost and net loss from other comprehensive income (loss) in the second quarter of 2016. Additionally, the Company recognized a non-cash settlement loss of $8 million related to $28 million of lump sum payments from the pension plan in the second quarter of 2016. The Company expects pension settlements related to the reduction in workforce to be substantially complete by the end of the third quarter.  The Company’s other postretirement benefit plan had a net periodic benefit cost (gain) of ($6) , $1 , ($5) and $2 million for the three months ended June 3 0 , 2016 and 2015 and six months ended June 30, 2016 and 2015, respectively. Included in the net periodic benefit cost for the second quarter is a curtailment gain of $6 million, which more than offset the other components of net periodic benefit cost for the three and six months ended June 30, 2016.  As of June 30 , 2016, the Company has contributed $6 million to the pension and other postretirement benefit plan s. The Company expects to contribute an additional $5 million during the remainder of 2016. The Company recognized a liability of $40 million and $12 million related to its pension and other postretirement benefits, respectively, as of June 30, 2016 compared to a liability of $31 million and $20 million as of December 31, 2015. The Company updated the discount rate used in the measurement of the benefit obligation of the pension plan and other postretirement benefits plan to 4.20% in the second quarter of 2016. The Company used an assumption of 4.60% from January 1, 2016 to March 31, 2016 for both the pension and other postretirement benefit plans.  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 31,269 shares at June 3 0 , 2016 , compared to 47,149 s hares at December 31, 2015 .

Stock-Based Compensation

Stock-Based Compensation	6 Months Ended
	Jun. 30, 2016
Stock-Based Compensation [Abstract]
Stock-Based Compensation	 (1 3 ) STOCK-BASED COMPENSATION  The Company recognized the following amounts in employee stock-based compensation costs for the three and six months ended June 30, 2016 and 201 5 :    For the three months ended For the six months ended  June 30, June 30,  2016 2015 2016 2015  (in millions)  Stock-based compensation cost – expensed (1) (2) $ 14 $ 6 $ 37 $ 12  Stock-based compensation cost – capitalized $ 2 $ 6 $ 5 $ 11 (1) Includes $2 million and $16 million related to the reduction in workforce for the three and six months ended June 30, 2016, respectively. (2) Includes $3 million related to executive management restructuring for the three and six months ended June 30, 2016.  In January 2016, the Company announced a 40% workforce reduction that was substantially concluded by the end of March 2016. In April 2016, the Company also partially restructured executive management, which was substantially completed in the second quarter of 2016. Affected employees were offered a severance package that included, if applicable, amendments to outstanding equity awards that modified forfeiture provisions on separation from the Company. As a result, unvested stock-based equity awards became fully vested at the time of separation. These shares were revalued and recognized immediately as a component of restructuring charges on the Company’s unaudited condensed consolidated statements of operations.  As of June 30, 2016 , there was $ 67 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 y ears .  Stock Options  The following table summarizes s tock option activity for the six months ended June 30, 2016 and provides information for options outstanding an d options exercisable as of June 30, 2016 :    Number Weighted Average  of Options Exercise Price  (in thousands) (per share)  Outstanding at December 31, 2015 5,623 $ 24.57  Granted 156 8.60  Exercised – –  Forfeited or expired (29) 37.71  Outstanding at June 30, 2016 5,750 24.07  Exercisable at June 30, 2016 2,611 $ 35.95  Restricted Stock  The following table summarizes restr icted stock activity for the six months ended June 30, 2016 and provides information for unvested shares as of June 30, 2016 :    Number Weighted Average  of Shares Fair Value  (in thousands) (per share)  Unvested shares at December 31, 2015 7,222 $ 13.24  Granted 77 8.35  Vested (1) (2,462) 9.22  Forfeited (89) 11.64  Unvested shares at June 30, 2016 4,748 $ 12.89 (1) Includes 1,987,379 shares related to the reduction in workforce and 151,575 shares related to the executive management restructuring for the six months ended June 30, 2016.  Equity-Classified Performance Units  The following table summarizes performance unit activity to be paid out in Company stock for the six months ended June 30, 2016 and provides information for unvested units as o f June 30, 2016 . The performance units awarded in 2013 and 2014 inclu de a market condition based on r elative 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 p erformance units is based on economic analysis for each investment opportunity based upon the expected present value added for each dollar to be invested and amortized to com pensation expense on a straight- line basis over the vesting period of the award. The performance units awarded in 2016 and 2015 are based exclusively on TSR. The grant date fair value is calculated using the applicable Performance Measures and the closing price of the Company’s common stock at the grant date.     Number Weighted Average  of Units (1) Fair Value  (in thousands) (per share)  Unvested units at December 31, 2015 407 $ 36.65  Granted 1,502 8.60  Vested (2 ) (412) 7.61  Forfeited (3) (267) 11.13  Unvested units at June 30, 2016 1,230 $ 13.69 (1) T hese 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 applicable Performance Measures. (2) Includes 13,669 units and 37,590 units related to the reduction in workforce and executive management restructuring, respectively, for the six months ended June 30, 2016. (3) Includes 71,157 units and 195,834 units related to the reduction in workforce and executive management restructuring, respectively, for the six months ended June 30, 2016.  Liability-Classified Performance Units  Prior to 2013, c ertain employees were provided performance units vesting equally over three yea rs, payable in cash. The payout of these units wa s based on certain metrics, such as total shareholder return and reserve replacement efficiency, compared to a predetermined group of peer companies and Company goal s . At the end of each performance period, the value of the vest ed performance units, if any, would be paid in cash. In the first quarter of 2016, the Company completed the final payout under these performance unit agreements .

Segment Information

Segment Information	6 Months Ended
	Jun. 30, 2016
Segment Information [Abstract]
Segment Information	 (1 4 ) 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 segment generates revenue through the marketing of both Company and third-party produced natural gas and liquids 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 201 5 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 oper ating income, interest expense, gain (loss) on derivatives, 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  Production Midstream Other Total  (in millions)  Three months ended June 30, 2016:  Revenues from external customers $ 291 $ 231 $ – $ 522  Intersegment revenues (7) 328 – 321  Depreciation, depletion and amortization expense 90 17 – 107  Impairment of natural gas and oil properties 470 – – 470  Operating income (loss) (549) (1) 57 – (492)  Interest expense (3) 16 1 – 17  Other income (loss), net 3 (2) (1) –  Loss on derivatives (85) – – (85)  Benefit for income taxes (3) (1) – – (1)  Assets 5,000 1,227 1,150 (4) 7,377  Capital investments (5) 73 – 1 74   Three months ended June 30, 2015:  Revenues from external customers $ 496 $ 267 $ 1 $ 764  Intersegment revenues (6) 499 (1) 492  Depreciation, depletion and amortization expense 291 17 – 308  Impairment of natural gas and oil properties 1,535 – – 1,535  Operating income (loss) (1,639) 355 – (1,284)  Interest expense (3) – – 1 1  Other income, net 3 – – 3  Gain (loss) on derivatives 2 – (1) 1  Provision (benefit) for income taxes (3) (630) 138 (1) (493)  Assets 11,882 1,352 246 13,480  Capital investments (5) 389 19 7 415               Exploration and  Production Midstream Other Total  (in millions)  Six months ended June 30, 2016:  Revenues from external customers $ 634 $ 467 $ – $ 1,101  Intersegment revenues (14) 713 – 699  Depreciation, depletion and amortization expense 217 33 – 250  Impairment of natural gas and oil properties 1,504 – – 1,504  Operating income (loss) (1,709) (1) 117 (2) – (1,592)  Interest expense (3) 30 1 – 31  Other income (loss), net 1 (3) (1) (3)  Loss on derivatives (98) (1) – (99)  Assets 5,000 1,227 1,150 (4) 7,377  Capital investments (5) 193 2 1 196   Six months ended June 30, 2015:  Revenues from external customers $ 1,156 $ 540 $ 1 $ 1,697  Intersegment revenues (11) 1,164 – 1,153  Depreciation, depletion and amortization expense 569 32 – 601  Impairment of natural gas and oil properties 1,535 – – 1,535  Operating income (loss) (1,561) 443 (1) (1,119)  Interest expense (3) 45 7 – 52  Other income, net 2 – – 2  Gain (loss) on derivatives 17 – (2) 15  Provision (benefit) for income taxes (3) (612) 169 (1) (444)  Assets 11,882 1,352 246 13,480  Capital investments (5) 1,419 157 10 1,586 (1) Operating income (loss) for the E&P segment includes $11 million and $72 million related to restructuring charges for the three and six months ended June 30, 2016, respectively. (2) Operating income (loss) for the Midstream segment includes $3 million related to restructuring charges for the six months e nded June 30, 2016 . (3) Interest expense and the provision for income taxes by segment are an allocation of corporate amounts as they are incurred at the corporate level. (4) Other assets represent corporate assets not allocated to segments and assets for non-reportable segments. At June 30, 2016, other assets includes approximately $986 million in marketable securities. (5) Capital investments includes a $27 million increase and an $11 million decrease for the three months ended June 30, 2016 and 2015 , respectively, and decreases of $51 million and $11 million for the six months ended June 30, 2016 and 2015, respectively, relating to the change in accrued expenditures between periods. E&P capital for the three month period ended June 30, 2015 includes approximately $516 million related to the WPX Property and Statoil Property Acquisitions. Midstream capital for the six months ended June 30, 2015 includes approximately $119 million associated with the intangible asset related to the firm transportation acquired through the WPX Property Acquisition.  Included in intersegment revenues of the Midstream segment are $ 267 million and $ 419 million for the three months ended June 30 , 2016 and 2015, respectively , and $586 million and $995 million for the six months ended June 30, 2016 and 2015, respectively, for marketing of the Company’s E&P sales. Corporate assets include cash and cash equivalents, furniture and fixtures and other costs. Corporate general and administrative costs, depreciation expense and taxes other than income are allocated to the segments.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2016
Income Taxes [Abstract]
Income Taxes	(15) INCOME TAXES  The Company’s effective tax rate was approximately zero for the three and six months ended June 30, 2016, primarily as a result of the recognition of a valuation allowance. A valuation allowance for deferred tax assets, including net operating losses, is recognized when it is more likely than not that some or all of the benefit from the deferred tax asset will not be realized. To assess that likelihood, the Company uses estimates and judgment regarding future taxable income, and considers the tax consequences in the jurisdiction where such taxable income is generated, to determine whether a valuation allowance is required. Such evidence can include current financial position, results of operations, both actual and forecasted, the reversal of deferred tax liabilities, and tax planning strategies as well as the current and forecasted business economic s of the oil and gas industry.  Due to the material write-downs of the carrying value of natural gas and oil properties and operating results, the Company is in a net deferred tax asset position. The Company believes it is more likely than not that these deferred tax assets will not be realized and recorded a $216 million and $647 million tax expense for the increase in our valuation allowance for the three and six months ended June 30, 2016, respectively . Management assesses the available positive and negative evidence to estimate whether sufficient future taxable income will be generated to permit the use of deferred tax assets. A significant piece of objective negative evidence evaluated is the projected cumulative loss incurred over the three -year period ending December 31, 2016. Such objective negative evidence limits the ability to consider other subjective positive evidence, such as projections for future growth. The amount of the deferred tax asset considered realizable, however, could be adjusted if estimates of future taxable income are reduced or increased or if objective negative evidence in the form of cumulative losses is no longer present and additional weight is given to subjective evidence such as future expected growth. 

New Accounting Pronouncements

New Accounting Pronouncements	6 Months Ended
	Jun. 30, 2016
New Accounting Pronouncements [Abstract]
New Accounting Pronouncements	(1 6 ) NEW ACCOUNTING PRONOUNCEMENTS  New Accounting Standards Implemented  In April 2015, the FASB issued Accounting Standards Update No. 2015-03, Interest-Imputation of Interest (Subtopic 835-30) (“Update 2015-03”), in an effort to simplify presentation of debt issuance costs. Update 2015-03 required 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 was not affected by the amendments in this Update. Entities were required to apply the amendments in Update 2015-03 on a retrospective basis, with the balance sheet of each individual period presented adjusted to reflect the period-specific effects of applying the new guidance. In August 2015, the FASB issued Accounting Standards Update No. 2015-15, Interest-Imputation of Interest (Subtopic 835-30) (“Update 2015-15”), which addressed the presentation or subsequent measurement of debt issuance costs related to line-of-credit arrangements, given the absence of authoritative guidance within Update 2015-03 for debt issuance costs related to line-of-credit arrangements. For public entities, Update 2015-03 and Update 2015-15 were effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period. The Company adopted this update in the first quarter of 2016 resulting in an immaterial impact on its unaudited condensed consolidated results of operations, financial position and cash flows. At December 31, 2015, the Company had $24 million in unamortized debt expense that was classified as a long-term asset which is now presented as a contra liability as a result of adoption.  In May 2015, the FASB issued Accounting Standards Update No. 2015-07, Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (Or Its Equivalent) (“Update 2015-07”), which amends ASC 820, Fair Value Measurement. The standard removes the requirement to categorize within the fair value hierarchy investments for which fair value is measured using the net asset value per share practical expedient and removes certain related disclosure requirements. The amendments in Update 2015-07 are effective for reporting periods beginning after December 15, 2015, with early adoption permitted. The Company adopted this update in the first quarter of 2016 resulting in no impact on its unaudited condensed consolidated results of operations, financial position and cash flows.  In September 2015, the FASB issued Accounting Standards Update No. 2015-16, Business Combinations (Topic 805) (“Update 2015-16”), which seeks to reduce the complexity of amounts recognized in a business combination. The amendments in Update 2015-16 require that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The amendments in Update 2015-16 require that the acquirer record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. The amendments in Update 2015-16 require an entity to present separately on the face of the income statement or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods if the adjustment to the provisional amounts had been recognized as of the acquisition date. The amendments in Update 2015-16 were effective for fiscal years beginning after December 15, 2015, including interim periods within those fiscal years. The Company adopted this update in the first quarter of 2016 resulting in no impact on its unaudited condensed consolidated results of operations, financial position and cash flows.  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 was effective for annual reporting periods beginning after December 15, 2015, including interim periods within that reporting period. The Company adopted this update in the first quarter of 2016 resulting in no impact on its unaudited condensed consolidated results of operations, financial position and cash flows.  New Accounting Standards Not Yet Implemented  In May 2014, the FASB issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“Update 2014-09”), which seeks to provide clarity for recognizing revenue. Topic 606 Revenue from Contracts with Customers will supersede the revenue recognition requirement as in Topic 605 Revenue Recognition. Update 2014-09 requires an entity to recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled to those goods or services. Entities may apply the amendments in Update 2014-09 either (a) retrospectively to each reporting period presented, and the entity may elect a practical expedient per the update, or (b) retrospectively with the cumulative effect of initially applying Update 2014-09 recognized at the date of initial application – if an entity elects this transition method it also should provide the additional disclosures in reporting periods. In August 2015, the FASB issued Accounting Standards Update No. 2015-14, Revenue from Contracts with Customers (Topic 606) (“Update 2015-14”). Deferral of the Effective Date, which finalized proposed ASU No. 2015-240 of the same name and responds to stakeholders’ request to defer the effective date of the guidance in ASU No. 2014-09. In March 2016, the FASB issued Accounting Standards Update No. 2016-08, Revenue from Contracts with Customers (Topic 606) – Principal versus Agent Considerations (Reporting Revenue Gross versus Net ) (“Update 2016-08”), which finalized proposed ASU No. 2015-290 of the same name and clarifies the implementation guidance on principal versus agent considerations. In April 2016, the FASB issued Accounting Standards Update No. 2016-10, Revenue from Contracts with Customers (Topic 606) (“Update 2016-10”), which clarifies multiple aspects of Topic 606. In May 2016, the FASB issued Accounting Standards Update No. 2016-12, Revenue from Contracts with Customers (Topic 606) – Narrow-Scope Improvements and Practical Expedients (“Update 2016-12”), which provides clarifying guidance in a few narrow areas and adds some practical expedients to the guidance. For public entities, Upda te 2014-09, Update 2015-14, Update 2016-08 , Update 2016-10 and Update 2016-12 are effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. The Company is currently evaluating the provisions of Upd ate 2014-09, Update 2015-14, Update 2016-08 , Update 2016-10 and Update 2016-12 and assessing the impact, if any, they may have on its consolidated results of operations, financial position or cash flows.  In July 2015, the FASB issued Accounting Standards Update No. 2015-11, Inventory (Topic 330) (“Update 2015-11”), which seeks to simplify the measurement of inventory. Update 2015-11 requires that an entity should measure inventory at the lower of cost and net realizable value, where net realizable value is the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. For public entities, the amendments in Update 2015-11 are effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years, with early adoption permitted. The Company is currently evaluating the provisions of Update 2015-11 and assessing the impact, if any, it may have on its consolidated results of operations, financial position or cash flows.  In February 2016, the FASB issued Accounting Standards Update No. 2016-02, Leases (Topic 842) (“Update 2016-02”), which seeks to increase transparency and comparability among organizations by, among other things, recognizing lease assets and lease liabilities on the balance sheet for leases classified as operating leases under previous GAAP and disclosing key information about leasing arrangements. For public entities, Update 2016-02 becomes effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years, with early adoption permitted. The Company is currently evaluating the provisions of Update 2016-02 and assessing the impact, if any, it may have on its consolidated results of operations, financial position or cash flows.  In March 2016, the FASB issued Accounting Standards Update No. 2016-09, Compensation - Stock Compensation (Topic 718) (“Update 2016-09”), which seeks to simplify accounting for share-based payment transactions including income tax consequences, classification of awards as either equity or liabilities, and the classification on the statement of cash flows. For public entities, Update 2016-09 becomes effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years, with early adoption permitted. The Company is currently evaluating the provisions of Update 2016-09 and assessing the impact, if any, it may have on its consolidated results of operations, financial position or cash flows. 

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2016
Subsequent Events [Abstract]
Subsequent Events	(1 7) SUBSEQUENT EVENTS  In July 2016, the Company completed an underwritten public offering of 98,900,000 shares of its common stock, with an offering price to the public of $13.00 per share. Net proceeds, after underwriting discount and offering expenses, from the common stock offering were approximately $1,247 million. The proceeds from the offering were used to repay $375 million of the $750 million term loan entered into in November 2015 and to settle certain tender offers by purchasing an aggregate principal amount of approximately $700 million of the Company’s outstanding senior notes due in the first quarter of 2018.

Cash And Cash Equivalents (Tabl

Cash And Cash Equivalents (Tables)	6 Months Ended
	Jun. 30, 2016
Cash And Cash Equivalents [Abstract]
Summary Of Cash And Cash Equivalents	  June 30, December 31,  2016 2015  (in millions)   Cash $ 12 $ 15  Marketable securities (1) 986 –  Total cash and cash equivalents $ 998 $ 15 (1) Consists of money market funds .

Reduction In Workforce (Tables)

Reduction In Workforce (Tables)	6 Months Ended
	Jun. 30, 2016
Reduction In Workforce [Abstract]
Summary Of Restructuring Charges	  For the three months ended For the six months ended  June 30, 2016 June 30, 2016  (in millions)  Severance (including payroll taxes) (1) $ 2 $ 44  Stock-based compensation (2) 6 24 Pension and other postretirement benefits (3) 3 3  Other benefits – 3  Outplacement services, other – 1  Total restructuring charges (4) $ 11 $ 75 (1) Includes $1 million related to executive management restructuring for the three and six months ended June 30, 2016. (2) Includes $3 million related to executive management restructuring for the three and six months ended June 30, 2016. (3) Includes non-cash charges related to the curtailment and settlement of the pension and other postretirement benefit plans. See Note 12 for additional details regarding the Company’s retirement and employee benefit plans. (4) Total restructuring charges were $11 million and less than $1 million for the Company’s E&P and Midstream segments, respectively, for the three months ended June 30, 2016. For the six months ended June 30, 2016, restructuring charges were $72 million and $3 million for the Company’s E&P and Midstream segments, respectively.
Summary Of Liabilities Associated With Restructuring Activities	  Liability at March 31, 2016 $ 24  Additions 2  Distributions (24)  Liability at June 30, 2016 $ 2 

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2016
Earnings Per Share [Abstract]
Schedule Of Earnings Per Share	  For the three months ended For the six months ended  June 30, June 30,  2016 2015 2016 2015  (in millions, except share/per share amounts)  Net loss $ (593) $ (788) $ (1,725) $ (710)  Mandatory convertible preferred stock dividend 27 27 54 52  Net loss attributable to shareholders $ (620) $ (815) $ (1,779) $ (762)   Number of common shares:  Weighted average outstanding 385,594,815 382,114,011 384,232,831 378,797,446  Issued upon assumed exercise of outstanding stock options (1) – – – –  Effect of issuance of non-vested restricted common stock (2) – – – –  Effect of issuance of non-vested performance units (3) – – – –  Effect of issuance of mandatory convertible preferred stock (4) – – – –  Effect of declaration of preferred stock dividends (5) – – – –  Weighted average and potential dilutive outstanding 385,594,815 382,114,011 384,232,831 378,797,446   Loss per common share (6) :  Basic $ (1.61) $ (2.13) $ (4.63) $ (2.01)  Diluted $ (1.61) $ (2.13) $ (4.63) $ (2.01) (1) Due to the net loss for the three and six months ended June 30 , 2016 and 2015 , the unvested stock options were not recognized in diluted earnings per share calculations as they would be antidilutive. Options for 4,028,819 shares and 4,781,109 shares were excluded from the calculation of diluted shares for the three and six months ended June 30, 2016, respectively, because they would have had an antidilutive effect. Options for 3,832,533 shares and 3,768,666 shares were excluded from the calculation of diluted shares for the three and six months ended June 30, 2015, respectively, because they would have had an antidilutive effect. (2) Due to the net loss for the three and six months ended June 30, 2016 and 2015 , the unvested share-based payments were not recognized in diluted earnings per share calculations as they would be antidilutive. The calculation excluded 3,353, 371 shares and 2,844, 365 shares of restricted stock for the three and six months ended June 30, 2016, respectively, because they would have had an antidilutive effect. The calculation excluded 1,507,788 shares and 1,787,257 shares of restricted stock for the three and six months ended June 30, 2015, respectively, because they would have had an antidilutive effect. (3) Due to the net loss f or the three and six months ended June 30 , 2016, 780,920 shares and 577,624 shares, respectively, of performance units were excluded from the calculation of diluted earnings per share as they would have had an antidilutive effect. Due to the net loss for the three and six months ended June 30, 2015, the calculation excluded 129,202 shares and 116,185 shares, respectively, of performance units as they would have had an antidilutive effect. (4) Due to the net loss f or the three and six months ended June 30 , 2016, 74,999,895 of weighted average common shares issuable upon the assumed conversion of the mandatory convertible preferred stock were excluded from the diluted earnings per sh are calculation , respectively, as they would be antidilutive. Due to the net loss for the three and six months ended June 30, 2015, 72,723,440 and 64,687,701 of weighted average common shares issuable upon the assumed conversion of the mandatory convertible preferred stock were excluded from the diluted earnings per sh are calculation , respectively, as they would be antidilutive. (5) Due to the net loss for the three months ended June 30, 2016, 2,100,119 shares of common stock declared as preferred stock dividends were excluded from the diluted earnings per share calculations as they would have had an antidilutive effect. (6) Does not include the effect of 98,900,000 shares of common stock issued in July 2016.

Derivatives And Risk Manageme29

Derivatives And Risk Management (Tables)	6 Months Ended
	Jun. 30, 2016
Derivatives And Risk Management [Abstract]
Schedule Of Derivative Instruments, Notional Amount In BCF, Weighted Average Contract Prices And Fair Value	  Weighted Average Price per MMBtu  Volume (Bcf) Swaps Sold Puts Purchased Puts Sold Calls Basis Differential Fair value at June 30, 2016 ($ in millions)  Financial protection on production  2016  Fixed price swaps 61 $ 2.57 $ – $ – $ – $ – $ (24)  Purchased put options 17 $ – $ – $ 2.34 $ – $ – $ –  Two-way costless collars 12 $ – $ – $ 2.76 $ 3.35 $ – $ (1)  Basis swaps 7 $ – $ – $ – $ – $ 0.36 $ 5  Total 97 $ (20)  2017  Fixed price swaps 144 $ 3.07 $ – $ – $ – $ – $ (16)  Two-way costless collars 47 $ – $ – $ 2.90 $ 3.33 $ – $ (4)  Three-way costless collars 18 $ – $ 2.25 $ 2.75 $ 3.56 $ – $ (2)  Basis swaps 15 $ – $ – $ – $ – $ 0.02 $ (6)  Total 224 $ (28)   Sold call options  2016 60 $ – $ – $ – $ 5.00 $ – $ –  2017 86 $ – $ – $ – $ 3.25 $ – $ (30)  2018 63 $ – $ – $ – $ 3.50 $ – $ (18)  2019 52 $ – $ – $ – $ 3.50 $ – $ (17)  2020 32 $ – $ – $ – $ 3.75 $ – $ (10)  Total 293 $ (75) 
Balance Sheet Classification Of Derivative Financial Instruments	  Derivative Assets  Balance Sheet Classification Fair Value  June 30, 2016 December 31, 2015  (in millions)  Derivatives not designated as hedging instruments: Fixed price swaps Derivative assets $ 1 $ –  Two-way costless collars Derivative assets 6 –  Three-way costless collars Derivative assets 2 –  Basis swaps Derivative assets 7 3  Two-way costless collars Other long-term assets 6 –  Three-way costless collars Other long-term assets 2 –  Total derivative assets $ 24 $ 3   Derivative Liabilities  Balance Sheet Classification Fair Value  June 30, 2016 December 31, 2015  (in millions)  Derivatives not designated as hedging instruments:  Fixed price swaps Derivative liabilities $ 36 $ –  Two-way costless collars Derivative liabilities 10 –  Three-way costless collars Derivative liabilities 3 –  Basis swaps Derivative liabilities 8 –  Sold call options Derivative liabilities 16 –  Interest rate swaps Derivative liabilities 3 3  Fixed price swaps Other long-term liabilities 5 –  Two-way costless collars Other long-term liabilities 7 –  Three-way costless collars Other long-term liabilities 3 –  Sold call options Other long-term liabilities 59 –  Interest rate swaps Other long-term liabilities 5 2  Total derivative liabilities $ 155 $ 5 
Summary Of Before Tax Effect Of Cash Flow Hedges On Consolidated Financial Statements	   Gain (Loss) on Derivatives, Unsettled  Recognized in Earnings  Consolidated Statement of Operations For the three months ended For the six months ended  Classification of Gain (Loss) June 30, June 30,  Derivative Instrument on Derivatives, Unsettled 2016 2015 2016 2015  (in millions)  Fixed price swaps Gain (Loss) on Derivatives $ (60) $ (55) $ (40) $ (73)  Purchased put options Gain (Loss) on Derivatives (15) – – –  Two-way costless collars Gain (Loss) on Derivatives (5) – (5) –  Three-way costless collars Gain (Loss) on Derivatives (2) – (2) –  Basis swaps Gain (Loss) on Derivatives (1) 3 (4) (5)  Sold call options Gain (Loss) on Derivatives (25) – (75) 8  Interest rate swaps Gain (Loss) on Derivatives – 2 (3) (1)  Total loss on unsettled derivatives $ (108) $ (50) $ (129) $ (71)   Gain (Loss) on Derivatives, Settled (1)  Recognized in Earnings  Consolidated Statement of Operations For the three months ended For the six months ended  Classification of Gain (Loss) June 30, June 30,  Derivative Instrument on Derivatives, Settled 2016 2015 2016 2015  (in millions)  Fixed price swaps Gain (Loss) on Derivatives $ 12 $ 52 $ 16 $ 94  Purchased put options Gain (Loss) on Derivatives 11 – 11 –  Basis swaps Gain (Loss) on Derivatives – – 4 (6)  Interest rate swaps Gain (Loss) on Derivatives – (1) (1) (2)  Total gain on settled derivatives (2) $ 23 $ 51 $ 30 $ 86   Total gain (loss) on derivatives $ (85) $ 1 $ (99) $ 15  (1) T he Company calculates gain (loss) on derivatives, settled, as the summation of gains and losses on positions that have settled within the period . (2) Excluding interest rate swaps, t hese amounts are included, along with gas sales revenues, in the calculation of the Company’s realized natural gas price .

Reclassifications From Accumu30

Reclassifications From Accumulated Other Comprehensive Income (Loss) (Tables)	6 Months Ended
	Jun. 30, 2016
Reclassifications From Accumulated Other Comprehensive Income (Loss) [Abstract]
Components Of Accumulated Other Comprehensive Income (Loss)	    June 30, 2016  Pension and Other Postretirement Foreign Currency Total  (in millions) (1)  Beginning balance at December 31, 2015 $ (25) $ (23) $ (48)  Other comprehensive income before reclassifications 4 3 7  Amounts reclassified from/to other comprehensive income (loss) (2) – – –  Net current-period other comprehensive income (loss) 4 3 7  Ending balance at June 30, 2016 $ (21) $ (20) $ (41) (1) All amounts are net of tax. (2) See separate table below for details about these reclassifications . 1
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 six months ended June 30, 2016  (in millions)  Pension and other postretirement  Amortization of prior service cost and net loss (1) General and administrative expenses $ 1  Provision (benefit) for income taxes 1  Total reclassifications for the period Net loss $ –  (1) See Note 12 for additional details regarding the Company’s retirement and employee benefit plans.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2016
Fair Value Measurements [Abstract]
Carrying Amount And Estimated Fair Values Of Financial Instruments	  June 30, 2016 December 31, 2015  Carrying Fair Carrying Fair  Amount Value Amount Value  (in millions)  Cash and cash equivalents $ 998 $ 998 $ 15 $ 15  Credit facility – – 116 116  Term loan facility due 2018 744 744 747 747  Term loan facility due 2020 1,180 1,180 – –  Senior notes 3,844 3,580 3,842 2,651  Derivative instruments, net (131) (131) (2) (2) 
Summary Of Assets And Liabilities Measured At Fair Value On Recurring Basis	  June 30, 2016  Fair Value Measurements Using:  Quoted Prices Significant  in Active Significant Other Unobservable  Markets Observable Inputs Inputs Assets (Liabilities)  (Level 1) (Level 2) (Level 3) at Fair Value Fixed price swap assets $ – $ 1 $ – $ 1  Two-way costless collars assets – – 12 12  Three-way costless collars assets – – 4 4  Basis swap assets – – 7 7  Fixed price swap liabilities – (41) – (41) Two-way costless collars liabilities – – (17) (17)  Three-way costless collars liabilities – – (6) (6)  Basis swap liabilities – – (8) (8)  Sold call option liabilities – – (75) (75)  Interest rate swap liabilities – (8) – (8)  Total $ – $ (48) $ (83) $ (131)   December 31, 2015  Fair Value Measurements Using:  Quoted Prices Significant Other Significant  in Active Markets Observable Inputs Unobservable Inputs Assets (Liabilities)  (Level 1) (Level 2) (Level 3) at Fair Value  Basis swap assets $ – $ – $ 3 $ 3  Interest rate swap liabilities – (5) – (5)  Total $ – $ (5) $ 3 $ (2) 
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 For the six months ended  June 30, June 30,  2016 2015 2016 2015  (in millions)  Balance at beginning of period $ (35) $ (8) $ 3 $ (8)  Total gains (losses):  Included in earnings (37) 3 (71) (3)  Purchases, issuances, and settlements:  Settlements (11) – (15) 6  Transfers into/out of Level 3 – – – –  Balance at end of period $ (83) $ (5) $ (83) $ (5)  Change in gains (losses) included in earnings relating to derivatives still held as of June 30 $ (48) $ 3 $ (86) $ 3 

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2016
Debt [Abstract]
Components Of Debt	   June 30, 2016  Debt Instrument Unamortized Issuance Cost Unamortized Debt Discount Total  (in millions) Short-term debt:  7.15% Senior Notes due June 2018 $ 1 $ – $ – $ 1  Total short-term debt $ 1 $ – $ – $ 1   Long-term debt:  Variable rate ( 2.930% at June 30, 2016) term loan facility, due November 2018 (1) 750 (6) – 744  Variable rate ( 2.940% at June 30, 2016) term loan facility, due December 2020 1,191 (11) – 1,180  7.35% Senior Notes due October 2017 15 – – 15  7.125% Senior Notes due October 2017 25 – – 25  3.3% Senior Notes due January 2018 (2) 350 (1) – 349  7.5% Senior Notes due February 2018 (2) 600 (1) – 599  7.15% Senior Notes due June 2018 25 – – 25  4.05% Senior Notes due January 2020 (2) 850 (5) – 845  4.10% Senior Notes due March 2022 1,000 (5) (1) 994  4.95% Senior Notes due January 2025 1,000 (7) (2) 991  Total long-term debt $ 5,806 $ (36) $ (3) $ 5,767   Total debt $ 5,807 $ (36) $ (3) $ 5,768    December 31, 2015  Debt Instrument Unamortized Issuance Cost Unamortized Debt Discount Total  (in millions) Short-term debt:  7.15% Senior Notes due June 2018 $ 1 $ – $ – $ 1  Total short-term debt $ 1 $ – $ – $ 1   Long-term debt:  Variable rate ( 1.886% at December 31, 2015) credit facility, expires December 2018 116 – – 116  Variable rate ( 1.775% at December 31, 2015) term loan facility, due November 2018 (1) 750 (3) – 747  7.35% Senior Notes due October 2017 15 – – 15  7.125% Senior Notes due October 2017 25 – – 25  3.3% Senior Notes due January 2018 (2) 350 (2) – 348  7.5% Senior Notes due February 2018 (2) 600 (2) – 598  7.15% Senior Notes due June 2018 26 – – 26  4.05% Senior Notes due January 2020 (2) 850 (5) (1) 844  4.10% Senior Notes due March 2022 1,000 (5) (1) 994  4.95% Senior Notes due January 2025 1,000 (7) (2) 991  Total long-term debt $ 4,732 $ (24) $ (4) $ 4,704   Total debt $ 4,733 $ (24) $ (4) $ 4,705  (1) In July 2016, $375 million was repaid on the term loan facility, extending the maturity from November 2018 to December 2020.  (2) In July 2016, the Company purchased approximately $312 million of the 3.3% Senior Notes due January 2018 and $388 million of the 7.5% Senior Notes due February 2018.

Commitments And Contingencies (

Commitments And Contingencies (Tables)	6 Months Ended
	Jun. 30, 2016
Commitments And Contingencies [Abstract]
Schedule Of Future Obligation Under Transportation Agreements	  Payments Due by Period  Total Less than 1 Year 1 to 3 Years 3 to 5 Years 5 to 8 Years More than 8 Years  (in millions)  Infrastructure Currently in Service $ 5,243 $ 561 $ 1,136 $ 883 $ 852 $ 1,811  Pending Regulatory Approval and/or Construction (1) 3,338 13 231 452 672 1,970  Total Transportation Charges $ 8,581 $ 574 $ 1,367 $ 1,335 $ 1,524 $ 3,781  (1) Based on the estimated in-service dates as of June 30, 2016.

Pension Plan And Other Postre34

Pension Plan And Other Postretirement Benefits (Tables)	6 Months Ended
	Jun. 30, 2016
Pension Plan And Other Postretirement Benefits [Abstract]
Pension And Other Postretirement Benefit Costs	  Pension Benefits  For the three months ended For the six months ended  June 30, June 30,  2016 2015 2016 2015  (in millions)  Service cost $ 2 $ 4 $ 6 $ 8  Interest cost 1 2 3 3  Expected return on plan assets (1) (2) (3) (4)  Amortization of prior service cost – – – –  Amortization of net loss 1 – 1 1 Curtailment loss 1 – 1 –  Settlement loss 8 – 8 –  Net periodic benefit cost $ 12 $ 4 $ 16 $ 8 

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2016
Stock-Based Compensation [Abstract]
Schedule Of Stock-Based Compensation Costs	  For the three months ended For the six months ended  June 30, June 30,  2016 2015 2016 2015  (in millions)  Stock-based compensation cost – expensed (1) (2) $ 14 $ 6 $ 37 $ 12  Stock-based compensation cost – capitalized $ 2 $ 6 $ 5 $ 11 (1) Includes $2 million and $16 million related to the reduction in workforce for the three and six months ended June 30, 2016, respectively. (2) Includes $3 million related to executive management restructuring for the three and six months ended June 30, 2016.
Summary Of Stock Option Activity	  Number Weighted Average  of Options Exercise Price  (in thousands) (per share)  Outstanding at December 31, 2015 5,623 $ 24.57  Granted 156 8.60  Exercised – –  Forfeited or expired (29) 37.71  Outstanding at June 30, 2016 5,750 24.07  Exercisable at June 30, 2016 2,611 $ 35.95 
Summary Of Restricted Stock Activity	  Number Weighted Average  of Shares Fair Value  (in thousands) (per share)  Unvested shares at December 31, 2015 7,222 $ 13.24  Granted 77 8.35  Vested (1) (2,462) 9.22  Forfeited (89) 11.64  Unvested shares at June 30, 2016 4,748 $ 12.89 Includes 1,987,379 shares related to the reduction in workforce and 151,575 shares related to the executive management restructuring for the six months ended June 30, 2016.
Summary Of Performance Unit Activity	  Number Weighted Average  of Units (1) Fair Value  (in thousands) (per share)  Unvested units at December 31, 2015 407 $ 36.65  Granted 1,502 8.60  Vested (2 ) (412) 7.61  Forfeited (3) (267) 11.13  Unvested units at June 30, 2016 1,230 $ 13.69 (1) T hese 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 applicable Performance Measures. (2) Includes 13,669 units and 37,590 units related to the reduction in workforce and executive management restructuring, respectively, for the six months ended June 30, 2016. (3) Includes 71,157 units and 195,834 units related to the reduction in workforce and executive management restructuring, respectively, for the six months ended June 30, 2016. 

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2016
Segment Information [Abstract]
Summary Financial Information For Company's Reportable Segments	   Exploration and  Production Midstream Other Total  (in millions)  Three months ended June 30, 2016:  Revenues from external customers $ 291 $ 231 $ – $ 522  Intersegment revenues (7) 328 – 321  Depreciation, depletion and amortization expense 90 17 – 107  Impairment of natural gas and oil properties 470 – – 470  Operating income (loss) (549) (1) 57 – (492)  Interest expense (3) 16 1 – 17  Other income (loss), net 3 (2) (1) –  Loss on derivatives (85) – – (85)  Benefit for income taxes (3) (1) – – (1)  Assets 5,000 1,227 1,150 (4) 7,377  Capital investments (5) 73 – 1 74   Three months ended June 30, 2015:  Revenues from external customers $ 496 $ 267 $ 1 $ 764  Intersegment revenues (6) 499 (1) 492  Depreciation, depletion and amortization expense 291 17 – 308  Impairment of natural gas and oil properties 1,535 – – 1,535  Operating income (loss) (1,639) 355 – (1,284)  Interest expense (3) – – 1 1  Other income, net 3 – – 3  Gain (loss) on derivatives 2 – (1) 1  Provision (benefit) for income taxes (3) (630) 138 (1) (493)  Assets 11,882 1,352 246 13,480  Capital investments (5) 389 19 7 415               Exploration and  Production Midstream Other Total  (in millions)  Six months ended June 30, 2016:  Revenues from external customers $ 634 $ 467 $ – $ 1,101  Intersegment revenues (14) 713 – 699  Depreciation, depletion and amortization expense 217 33 – 250  Impairment of natural gas and oil properties 1,504 – – 1,504  Operating income (loss) (1,709) (1) 117 (2) – (1,592)  Interest expense (3) 30 1 – 31  Other income (loss), net 1 (3) (1) (3)  Loss on derivatives (98) (1) – (99)  Assets 5,000 1,227 1,150 (4) 7,377  Capital investments (5) 193 2 1 196   Six months ended June 30, 2015:  Revenues from external customers $ 1,156 $ 540 $ 1 $ 1,697  Intersegment revenues (11) 1,164 – 1,153  Depreciation, depletion and amortization expense 569 32 – 601  Impairment of natural gas and oil properties 1,535 – – 1,535  Operating income (loss) (1,561) 443 (1) (1,119)  Interest expense (3) 45 7 – 52  Other income, net 2 – – 2  Gain (loss) on derivatives 17 – (2) 15  Provision (benefit) for income taxes (3) (612) 169 (1) (444)  Assets 11,882 1,352 246 13,480  Capital investments (5) 1,419 157 10 1,586 (1) Operating income (loss) for the E&P segment includes $11 million and $72 million related to restructuring charges for the three and six months ended June 30, 2016, respectively. (2) Operating income (loss) for the Midstream segment includes $3 million related to restructuring charges for the six months e nded June 30, 2016 . (3) Interest expense and the provision for income taxes by segment are an allocation of corporate amounts as they are incurred at the corporate level. (4) Other assets represent corporate assets not allocated to segments and assets for non-reportable segments. At June 30, 2016, other assets includes approximately $986 million in marketable securities. (5) Capital investments includes a $27 million increase and an $11 million decrease for the three months ended June 30, 2016 and 2015 , respectively, and decreases of $51 million and $11 million for the six months ended June 30, 2016 and 2015, respectively, relating to the change in accrued expenditures between periods. E&P capital for the three month period ended June 30, 2015 includes approximately $516 million related to the WPX Property and Statoil Property Acquisitions. Midstream capital for the six months ended June 30, 2015 includes approximately $119 million associated with the intangible asset related to the firm transportation acquired through the WPX Property Acquisition.

Basis Of Presentation (Narrativ

Basis Of Presentation (Narrative) (Details)	6 Months Ended
	Jun. 30, 2016segment
Basis Of Presentation [Abstract]
Number of segments	2

Cash And Cash Equivalents (Summ

Cash And Cash Equivalents (Summary Of Cash And Cash Equivalents) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
Cash And Cash Equivalents [Abstract]
Cash	$ 12	$ 15
Marketable securities	986
Total cash and cash equivalents	$ 998	$ 15	$ 37	$ 53

Reduction In Workforce (Narrati

Reduction In Workforce (Narrative) (Details) $ in Millions	1 Months Ended	3 Months Ended	6 Months Ended
	Jan. 31, 2016employee	Jun. 30, 2016USD ($)	Dec. 31, 2016USD ($)	Jun. 30, 2016USD ($)
Restructuring Cost and Reserve [Line Items]
Restructuring charges		$ 11		$ 75
Workforce Reduction [Member]
Restructuring Cost and Reserve [Line Items]
Positions eliminated, percent	40.00%
Positions eliminated | employee	1,100
Restructuring charges		$ 11		$ 75
Scenario, Forecast [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring charges			$ 0.5

Reduction In Workforce (Summary

Reduction In Workforce (Summary Of Restructuring Charges) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2016
Restructuring Cost and Reserve [Line Items]
Severance (including payroll taxes)		$ 29
Total restructuring charges	$ 11	75
Exploration and Production [Member]
Restructuring Cost and Reserve [Line Items]
Total restructuring charges	11	72
Midstream Services [Member]
Restructuring Cost and Reserve [Line Items]
Total restructuring charges		3
Workforce Reduction [Member]
Restructuring Cost and Reserve [Line Items]
Severance (including payroll taxes)	2	44
Stock-based compensation	6	24
Pension and other postretirement benefits	3	3
Other benefits		3
Outplacement services, other		1
Total restructuring charges	11	75
Workforce Reduction [Member] | Executive Management [Member]
Restructuring Cost and Reserve [Line Items]
Severance (including payroll taxes)	1	1
Stock-based compensation	3	3
Workforce Reduction [Member] | Exploration and Production [Member]
Restructuring Cost and Reserve [Line Items]
Total restructuring charges	11	72
Workforce Reduction [Member] | Midstream Services [Member]
Restructuring Cost and Reserve [Line Items]
Total restructuring charges	$ 1	$ 3

Reduction In Workforce (Summa41

Reduction In Workforce (Summary Of Liabilities Associated With Restructuring Activities) (Details) - Workforce Reduction [Member] $ in Millions	3 Months Ended
	Jun. 30, 2016USD ($)
Restructuring Cost and Reserve [Line Items]
Liability at March 31, 2016	$ 24
Additions	2
Distributions	(24)
Liability at June 30, 2016	$ 2

Acquisitions And Divestitures (

Acquisitions And Divestitures (Narrative) (Details) $ in Millions	1 Months Ended					6 Months Ended			12 Months Ended
	Jun. 30, 2016USD ($)a	May 31, 2015USD ($)	Apr. 30, 2015USD ($)miMMcf	Jan. 31, 2015USD ($)aMMcf	Dec. 31, 2014USD ($)aMMcf	Dec. 31, 2016USD ($)	Jun. 30, 2016USD ($)a	Jun. 30, 2015USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)aitemMMcf
Business Acquisition [Line Items]
Capital spending							$ 241	$ 974
Area of land purchased | a					413,000					413,000
Bridge Loan [Member]
Business Acquisition [Line Items]
Bridge loan				$ 4,500	$ 4,500				$ 4,500	$ 4,500
Debt instrument, term				364 days	364 days				364 days
Debt issuance costs				$ 47
Long-term Debt [Member] | Term Loan due December 2016 [Member]
Business Acquisition [Line Items]
Loans payable	$ 500				$ 500		$ 500			$ 500
Maturity date, month and year							2016-12
Debt instrument, term					2 years
WPX Property Acquisition [Member]
Business Acquisition [Line Items]
Area of land purchased | a				46,700
Cash consideration				$ 270
Net production per day of acreage sold in MMcf | MMcf					50					50
Number of horizontal wells operated | item										63
Firm transportation capacity assumed, per day | MMcf				260
Firm transportation, useful life				19 years
Amortization							$ 13		$ 8
Statoil Property Acquisition [Member]
Business Acquisition [Line Items]
Area of land purchased | a				30,000
Percentage of interest acquired				20.00%
Cost to acquire property				$ 357
Chesapeake Property Acquisition [Member]
Business Acquisition [Line Items]
Cash consideration					$ 5,000
West Virginia [Member]
Business Acquisition [Line Items]
Area of land sold | a	55,000						55,000
Proceeds from sale of oil and gas property and equipment	$ 450
Deposit received	$ 45						$ 45
East Texas and Arkoma Basin [Member]
Business Acquisition [Line Items]
Proceeds from sale of oil and gas property and equipment		$ 211
Reduction in capitalized costs relating to proceeds		$ (205)
Bradford And Lycoming Counties, Pennsylvania [Member]
Business Acquisition [Line Items]
Proceeds from sale of oil and gas property and equipment			$ 489
Net book value			206
Gain on sale of property			$ 283
Number of miles of natural gas gathering pipeline | mi			100
Pipeline capacity per day | MMcf			600
Scenario, Forecast [Member]
Business Acquisition [Line Items]
Capital spending						$ 375

Natural Gas And Oil Properties

Natural Gas And Oil Properties (Narrative) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016USD ($)$ / MMBTU$ / bbl	Jun. 30, 2015USD ($)$ / MMBTU$ / bbl	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)
Natural Gas and Oil Properties [Line Items]
Natural gas, oil and NGL reserves discount	10.00%
Period of time needed to calculate ceiling value of reserves	12 months	12 months
Cash flow hedges impact on ceiling value, net of tax | $		$ 60
Impairment of natural gas and oil properties, net of tax | $	$ 297	$ 944	$ 641	$ 1,586	$ 1,746
Natural Gas [Member] | Henry Hub [Member]
Natural Gas and Oil Properties [Line Items]
Full cost ceiling test, price | $ / MMBTU	2.24	3.39
Oil [Member] | West Texas Intermediate [Member]
Natural Gas and Oil Properties [Line Items]
Full cost ceiling test, price | $ / bbl	39.63	68.17
NGL [Member]
Natural Gas and Oil Properties [Line Items]
Full cost ceiling test, price | $ / bbl	5.87	12.53

Earnings Per Share (Narrative)

Earnings Per Share (Narrative) (Details) - USD ($)	Jul. 15, 2016	Jul. 31, 2016	Nov. 30, 2015	Jan. 31, 2015	Dec. 31, 2014	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Payments on long-term debt							$ 500,000,000
Debt Instrument						$ 5,807,000,000		$ 4,733,000,000
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
Price per share				$ 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				5.00%
Liquidation preference per share				$ 50
Series B Preferred Stock [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Liquidation preference per share				$ 1,000		$ 1,000		$ 1,000
Trading day period						20 days
Long-term Debt [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Debt Instrument						$ 5,806,000,000		$ 4,732,000,000
Long-term Debt [Member] | Term Loan due November 2018 [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Debt Instrument						$ 750,000,000		$ 750,000,000
Debt instrument, term			3 years
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] | Series B Preferred Stock [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares issued upon conversion						37.0028
Potential number of shares issued upon conversion						63,829,830
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] | Series B Preferred Stock [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares issued upon conversion						43.4782
Potential number of shares issued upon conversion						74,999,895
Subsequent Event [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Common stock, shares issued as stock dividend	2,100,119
Subsequent Event [Member] | Common Stock [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares issued		98,900,000
Price per share		$ 13
Proceeds from issuance of shares		$ 1,247,000,000
Subsequent Event [Member] | Long-term Debt [Member] | Term Loan due November 2018 [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Payments on long-term debt		375,000,000
Subsequent Event [Member] | Senior Notes [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Purchase of note principal		$ 700,000,000

Earnings Per Share (Schedule Of

Earnings Per Share (Schedule Of Earnings Per Share) (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended		3 Months Ended		6 Months Ended
	Jul. 31, 2016	Jan. 31, 2015	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Earnings Per Share [Line Items]
Net loss			$ (593)	$ (788)	$ (1,725)	$ (710)
Mandatory convertible preferred stock dividend			27	27	54	52
Net Loss Attributable to Common Stock			$ (620)	$ (815)	$ (1,779)	$ (762)
Number of common shares, Weighted average outstanding			385,594,815	382,114,011	384,232,831	378,797,446
Number of common shares: Issued upon assumed exercise of outstanding stock options
Number of common shares: Effect of issuance of non-vested restricted common stock
Number of common shares: Effect of issuance of non-vested performance units
Number of common shares: Effect of issuance of mandatory convertible preferred stock
Number of common shares: Effect of declaration of preferred stock dividends
Number of common shares, Weighted average and potential dilutive outstanding			385,594,815	382,114,011	384,232,831	378,797,446
Basic			$ (1.61)	$ (2.13)	$ (4.63)	$ (2.01)
Diluted			$ (1.61)	$ (2.13)	$ (4.63)	$ (2.01)
Common stock, shares declared as stock dividend			2,100,119
Stock Options [Member]
Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, shares			4,028,819	3,832,533	4,781,109	3,768,666
Restricted Stock [Member]
Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, shares			3,353,371	1,507,788	2,844,365	1,787,257
Performance Units [Member]
Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, shares			780,920	129,202	577,624	116,185
Mandatory Convertible Preferred Stock [Member]
Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share, shares			74,999,895	72,723,440	74,999,895	64,687,701
Common Stock [Member]
Earnings Per Share [Line Items]
Issuance of stock, shares		30,000,000
Common Stock [Member] | Subsequent Event [Member]
Earnings Per Share [Line Items]
Issuance of stock, shares	98,900,000

Derivatives And Risk Manageme46

Derivatives And Risk Management (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Derivative [Line Items]
Gas sales	$ 251	$ 457	$ 566	$ 1,082
Interest Rate Swaps [Member]
Derivative [Line Items]
Derivative liabilities	8		8		$ 5
Fixed Price Swaps [Member]
Derivative [Line Items]
Derivative liabilities	41		41
Not Designated as Hedging Instrument [Member] | Interest Rate Swaps [Member]
Derivative [Line Items]
Derivative liabilities	8		8
Notional amount	170		$ 170
Derivative, expiration			Jun. 30, 2020
Designated as Hedging Instrument [Member] | Fixed Price Swaps [Member]
Derivative [Line Items]
Derivative gain (loss) in other comprehensive income		(3)		21
Gas sales		$ 53		$ 95
Natural Gas [Member] | Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Derivative liabilities	$ 123		$ 123

Derivatives And Risk Manageme47

Derivatives And Risk Management (Schedule Of Derivative Instruments, Notional Amount In BCF, Weighted Average Contract Prices And Fair Value) (Details) - Not Designated as Hedging Instrument [Member] $ in Millions, ft³ in Billions	6 Months Ended
	Jun. 30, 2016USD ($)$ / MMBTUft³
Fixed Price Swaps -2016 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	61
Average price per MMBtu	2.57
Fair value | $	$ (24)
Purchased Put Options - 2016 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	17
Floor price per MMBtu	2.34
Fair value | $
Two-way Costless-collars - 2016 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	12
Fair value | $	$ (1)
Two-way Costless-collars - 2016 Purchased Puts [Member]
Derivative [Line Items]
Floor price per MMBtu	2.76
Two-way Costless-collars - 2016 Sold Calls [Member]
Derivative [Line Items]
Cap price per MMBtu	3.35
Basis Swap - 2016 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	7
Average price per MMBtu	0.36
Fair value | $	$ 5
Financial protection on production - 2016 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	97
Fair value | $	$ (20)
Fixed Price Swaps - 2017 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	144
Average price per MMBtu	3.07
Fair value | $	$ (16)
Two-way Costless-collars - 2017 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	47
Fair value | $	$ (4)
Two-way Costless-collars - 2017 Purchased Puts [Member]
Derivative [Line Items]
Floor price per MMBtu	2.90
Two-way Costless-collars - 2017 Sold Calls [Member]
Derivative [Line Items]
Cap price per MMBtu	3.33
Three-way Costless-collars - 2017 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	18
Fair value | $	$ (2)
Three-way Costless-collars - 2017 Sold Puts [Member]
Derivative [Line Items]
Floor price per MMBtu	2.25
Three-way Costless-collars - 2017 Purchased Puts [Member]
Derivative [Line Items]
Floor price per MMBtu	2.75
Three-way Costless-collars - 2017 Sold Calls [Member]
Derivative [Line Items]
Cap price per MMBtu	3.56
Basis Swap - 2017 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	15
Average price per MMBtu	0.02
Fair value | $	$ (6)
Financial protection on production - 2017 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	224
Fair value | $	$ (28)
Sold Call Options - 2016 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	60
Cap price per MMBtu	5
Fair value | $
Sold Call Options - 2017 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	86
Cap price per MMBtu	3.25
Fair value | $	$ (30)
Sold Call Options - 2018 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	63
Cap price per MMBtu	3.50
Fair value | $	$ (18)
Sold Call Options - 2019 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	52
Cap price per MMBtu	3.50
Fair value | $	$ (17)
Sold Call Options - 2020 [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	32
Cap price per MMBtu	3.75
Fair value | $	$ (10)
Sold Call Options [Member]
Derivative [Line Items]
Volume (Bcf) | ft³	293
Fair value | $	$ (75)

Derivatives And Risk Manageme48

Derivatives And Risk Management (Balance Sheet Classification Of Derivative Financial Instruments) (Details) - Not Designated as Hedging Instrument [Member] - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Derivative assets	$ 24	$ 3
Derivative liabilities	155	5
Fixed Price Swaps [Member] | Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	1
Fixed Price Swaps [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	36
Fixed Price Swaps [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	5
Two-way Costless-collars [Member] | Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	6
Two-way Costless-collars [Member] | Other Long-Term Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	6
Two-way Costless-collars [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	10
Two-way Costless-collars [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	7
Three-way Costless-collars [Member] | Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	2
Three-way Costless-collars [Member] | Other Long-Term Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	2
Three-way Costless-collars [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	3
Three-way Costless-collars [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	3
Basis Swaps [Member] | Derivative Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	7	3
Basis Swaps [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	8
Sold Call Options [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	16
Sold Call Options [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	59
Interest Rate Swaps [Member] | Derivative Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	3	3
Interest Rate Swaps [Member] | Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	$ 5	$ 2

Derivatives And Risk Manageme49

Derivatives And Risk Management (Summary Of Before Tax Effect Of Cash Flow Hedges On Consolidated Financial Statements) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instrument, Gain (Loss) on Derivatives, Unsettled	$ (108)	$ (50)	$ (129)	$ (71)
Derivative Instrument, Gain (Loss) on Derivatives, Settled	23	51	30	86
Total gain (loss) on derivatives	(85)	1	(99)	15
Fixed Price Swaps [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instrument, Gain (Loss) on Derivatives, Unsettled	(60)	(55)	(40)	(73)
Derivative Instrument, Gain (Loss) on Derivatives, Settled	12	52	16	94
Purchased Put Options [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instrument, Gain (Loss) on Derivatives, Unsettled	(15)
Derivative Instrument, Gain (Loss) on Derivatives, Settled	11		11
Two-way Costless-collars [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instrument, Gain (Loss) on Derivatives, Unsettled	(5)		(5)
Three-way Costless-collars [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instrument, Gain (Loss) on Derivatives, Unsettled	(2)		(2)
Basis Swaps [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instrument, Gain (Loss) on Derivatives, Unsettled	(1)	3	(4)	(5)
Derivative Instrument, Gain (Loss) on Derivatives, Settled			4	(6)
Sold Call Options [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instrument, Gain (Loss) on Derivatives, Unsettled	$ (25)		(75)	8
Interest Rate Swaps [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instrument, Gain (Loss) on Derivatives, Unsettled		2	(3)	(1)
Derivative Instrument, Gain (Loss) on Derivatives, Settled		$ (1)	$ (1)	$ (2)

Reclassifications From Accumu50

Reclassifications From Accumulated Other Comprehensive Income (Loss) (Components Of Accumulated Other Comprehensive Income (Loss)) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016USD ($)
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance, December 31, 2015	$ (48)
Other comprehensive income before reclassifications	7
Net current-period other comprehensive income (loss)	7
Ending balance, June 30, 2016	(41)
Pension And Other Postretirement [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance, December 31, 2015	(25)
Other comprehensive income before reclassifications	4
Amounts reclassified from/to other comprehensive income (loss)
Net current-period other comprehensive income (loss)	4
Ending balance, June 30, 2016	(21)
Foreign Currency [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning balance, December 31, 2015	(23)
Other comprehensive income before reclassifications	3
Amounts reclassified from/to other comprehensive income (loss)
Net current-period other comprehensive income (loss)	3
Ending balance, June 30, 2016	$ (20)

Reclassifications From Accumu51

Reclassifications From Accumulated Other Comprehensive Income (Loss) (Amounts Reclassified From Accumulated Other Comprehensive Income (Loss)) (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net actuarial loss	[1]	$ 4		$ 4
General and administrative expenses		56	$ 60	110	$ 128
Provision (benefit) for income taxes		(1)	(493)		(444)
Net Loss		$ (593)	$ (788)	(1,725)	$ (710)
Pension And Other Postretirement [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
General and administrative expenses				1
Provision (benefit) for income taxes				$ 1
[1]	Net of $1 million in taxes for the three and six months ended June 30, 2016.

Fair Value Measurements (Carryi

Fair Value Measurements (Carrying Amount And Estimated Fair Values Of Financial Instruments) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative instruments, net	$ (131)	$ (2)
Carrying Amount [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	998	15
Credit facility		116
Senior notes	3,844	3,842
Derivative instruments, net	(131)	(2)
Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	998	15
Credit facility		116
Senior notes	3,580	2,651
Derivative instruments, net	(131)	(2)
Long-term Debt [Member] | Carrying Amount [Member] | Term Loan due November 2018 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loans	744	747
Long-term Debt [Member] | Carrying Amount [Member] | Term Loan due December 2020 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loans	1,180
Long-term Debt [Member] | Fair Value [Member] | Term Loan due November 2018 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loans	744	$ 747
Long-term Debt [Member] | Fair Value [Member] | Term Loan due December 2020 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loans	$ 1,180

Fair Value Measurements (Summar

Fair Value Measurements (Summary Of Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	$ (131)	$ (2)
Quoted Prices in Active Markets (Level 1) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total
Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	(48)	(5)
Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	(83)	3
Fixed Price Swaps [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1
Derivative liabilities	(41)
Fixed Price Swaps [Member] | Quoted Prices in Active Markets (Level 1) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets
Derivative liabilities
Fixed Price Swaps [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1
Derivative liabilities	(41)
Two-way Costless-collars [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	12
Derivative liabilities	(17)
Two-way Costless-collars [Member] | Quoted Prices in Active Markets (Level 1) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets
Derivative liabilities
Two-way Costless-collars [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	12
Derivative liabilities	(17)
Three-way Costless-collars [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	4
Derivative liabilities	(6)
Three-way Costless-collars [Member] | Quoted Prices in Active Markets (Level 1) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets
Derivative liabilities
Three-way Costless-collars [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	4
Derivative liabilities	(6)
Basis Swaps [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	7	3
Derivative liabilities	(8)
Basis Swaps [Member] | Quoted Prices in Active Markets (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	7	3
Derivative liabilities	(8)
Sold Call Options [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	(75)
Sold Call Options [Member] | Quoted Prices in Active Markets (Level 1) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities
Sold Call Options [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	(75)
Interest Rate Swaps [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	(8)	(5)
Interest Rate Swaps [Member] | Quoted Prices in Active Markets (Level 1) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities
Interest Rate Swaps [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	$ (8)	$ (5)

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 ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Fair Value Measurements [Abstract]
Balance at beginning of period	$ (35)	$ (8)	$ 3	$ (8)
Included in earnings	(37)	3	(71)	(3)
Purchases, issuances, and settlements:
Settlements	(11)		(15)	6
Transfers into/out of Level 3
Balance at end of period	(83)	(5)	(83)	(5)
Change in gains (losses) included in earnings relating to derivatives still held as of June 30	$ (48)	$ 3	$ (86)	$ 3

Debt (Narrative) (Details)

Debt (Narrative) (Details)	1 Months Ended						6 Months Ended		12 Months Ended
	Jul. 31, 2016USD ($)	Jun. 30, 2016USD ($)	Feb. 29, 2016	Nov. 30, 2015USD ($)	Jan. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2015USD ($)	Dec. 31, 2013USD ($)
Debt Instrument [Line Items]
Debt instrument		$ 5,807,000,000					$ 5,807,000,000				$ 4,733,000,000
Payments on long-term debt								$ 500,000,000
Long-term Debt [Member]
Debt Instrument [Line Items]
Debt instrument		5,806,000,000					5,806,000,000				4,732,000,000
Long-term Debt [Member] | 2013 Credit Facility [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity		66,000,000					66,000,000					$ 2,000,000,000
Repayment of line of credit		285,000,000
Borrowings		$ 0					$ 0
Debt percentage of adjusted book capital structure covenant		60.00%					60.00%
Credit facility, maturity date							Dec. 1, 2018
Long-term Debt [Member] | 2016 Credit Facility [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity		$ 743,000,000					$ 743,000,000
Long-term Debt [Member] | 2013 & 2016 Credit Facilities [Member]
Debt Instrument [Line Items]
Borrowings		0					0
Long-term Debt [Member] | Credit Facility [Member]
Debt Instrument [Line Items]
Debt instrument											$ 116,000,000
Credit facility, maturity date											Dec. 1, 2018
Long-term Debt [Member] | Letter of Credit [Member]
Debt Instrument [Line Items]
Borrowings		169,000,000					$ 169,000,000
Senior Notes [Member]
Debt Instrument [Line Items]
Proceeds from issuance of debt					$ 2,200,000,000
Senior Notes [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Purchase of note principal	$ 700,000,000
Senior Notes [Member] | Over LIBOR [Member]
Debt Instrument [Line Items]
Incremental increase on basis points							0.25%
Increase in basis spread			1.75%
Bridge Loan [Member]
Debt Instrument [Line Items]
Debt instrument, term					364 days	364 days					364 days
Bridge loan					$ 4,500,000,000	$ 4,500,000,000					$ 4,500,000,000
Debt issuance costs					47,000,000
Revolving Credit Facility And Term Loan Facility [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity		$ 1,934,000,000					$ 1,934,000,000
Maturity date, month and year		2020-12
Incremental increase, EBITDA to Interest Expense Ratio		0.25
Revolving Credit Facility And Term Loan Facility [Member] | Long-term Debt [Member] | Minimum [Member]
Debt Instrument [Line Items]
EBITDA to Interest Expense Ratio		0.75
Liquidity requirement		$ 300,000,000					300,000,000
Anti-hoarding provision, required unrestricted cash		$ 100,000,000					100,000,000
Collateral coverage ratio		1.50
Revolving Credit Facility And Term Loan Facility [Member] | Long-term Debt [Member] | Minimum [Member] | Scenario, Forecast [Member]
Debt Instrument [Line Items]
EBITDA to Interest Expense Ratio									1.50	1.50
Revolving Credit Facility And Term Loan Facility [Member] | Long-term Debt [Member] | Maximum [Member]
Debt Instrument [Line Items]
Liquidity requirement		$ 500,000,000					500,000,000
Revolving Credit Facility And Term Loan Facility [Member] | Long-term Debt [Member] | Eurodollar [Member] | Minimum [Member]
Debt Instrument [Line Items]
Basis points		1.75%
Revolving Credit Facility And Term Loan Facility [Member] | Long-term Debt [Member] | Eurodollar [Member] | Maximum [Member]
Debt Instrument [Line Items]
Basis points		2.50%
Revolving Credit Facility And Term Loan Facility [Member] | Long-term Debt [Member] | Base Rate [Member] | Minimum [Member]
Debt Instrument [Line Items]
Basis points		0.75%
Revolving Credit Facility And Term Loan Facility [Member] | Long-term Debt [Member] | Base Rate [Member] | Maximum [Member]
Debt Instrument [Line Items]
Basis points		1.50%
Revolving Credit Facility And Term Loan Facility [Member] | Long-term Debt [Member] | Over LIBOR [Member]
Debt Instrument [Line Items]
Basis points		2.50%
Term Loan due December 2020 [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Debt instrument		$ 1,191,000,000					$ 1,191,000,000
Maturity date, month and year							2020-12
Term Loan due December 2020 [Member] | Long-term Debt [Member] | Credit Facility [Member]
Debt Instrument [Line Items]
Maximum borrowing capacity		1,191,000,000					$ 1,191,000,000
Term Loan due December 2016 [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Maturity date, month and year							2016-12
Loans payable		500,000,000				$ 500,000,000	$ 500,000,000
Debt instrument, term						2 years
3.3% Senior Notes due January 2018 [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Debt instrument		$ 350,000,000					$ 350,000,000				$ 350,000,000
Maturity date, month and year							2018-01				2018-01
Senior notes					$ 350,000,000
Stated interest rate		3.30%			3.30%		3.30%				3.30%
Maturity date, year					2,018
Percentage of face amount, sold to public					99.949%
3.3% Senior Notes due January 2018 [Member] | Long-term Debt [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Payments on long-term debt	312,000,000
4.05% Senior Notes due January 2020 [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Debt instrument		$ 850,000,000					$ 850,000,000				$ 850,000,000
Maturity date, month and year							2020-01				2020-01
Senior notes					$ 850,000,000
Stated interest rate		4.05%			4.05%		4.05%				4.05%
Maturity date, year					2,020
Percentage of face amount, sold to public					99.897%
4.95% Senior Notes due January 2025 [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Debt instrument		$ 1,000,000,000					$ 1,000,000,000				$ 1,000,000,000
Maturity date, month and year							2025-01				2025-01
Senior notes					$ 1,000,000,000
Stated interest rate		4.95%			4.95%		4.95%				4.95%
Maturity date, year					2,025
Percentage of face amount, sold to public					99.782%
Term Loan due November 2018 [Member] | Long-term Debt [Member]
Debt Instrument [Line Items]
Debt instrument		$ 750,000,000					$ 750,000,000				$ 750,000,000
Maturity date, month and year							2018-11				2018-11
Loans payable				$ 750,000,000
Debt instrument, term				3 years
Term Loan due November 2018 [Member] | Long-term Debt [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Payments on long-term debt	375,000,000
Term Loan due November 2018 [Member] | Long-term Debt [Member] | Over LIBOR [Member]
Debt Instrument [Line Items]
Basis points				2.50%
Common Stock [Member]
Debt Instrument [Line Items]
Proceeds from issuance of shares					$ 669,000,000
Common Stock [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Proceeds from issuance of shares	$ 1,247,000,000
Depositary Shares [Member]
Debt Instrument [Line Items]
Proceeds from issuance of shares					$ 1,700,000,000

Debt (Components Of Debt) (Deta

Debt (Components Of Debt) (Details) - USD ($)	1 Months Ended	6 Months Ended		12 Months Ended
	Jul. 31, 2016	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015	Jan. 31, 2015
Debt Instrument [Line Items]
Debt Instrument		$ 5,807,000,000		$ 4,733,000,000
Unamortized Issuance Cost		(36,000,000)		(24,000,000)
Unamortized Debt Discount		(3,000,000)		(4,000,000)
Total		5,768,000,000		4,705,000,000
Payments on long-term debt			$ 500,000,000
Short-term Debt [Member]
Debt Instrument [Line Items]
Debt Instrument		1,000,000		1,000,000
Unamortized Issuance Cost
Unamortized Debt Discount
Total		1,000,000		1,000,000
Short-term Debt [Member] | 7.15% Senior Notes due June 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument		1,000,000		1,000,000
Unamortized Issuance Cost
Unamortized Debt Discount
Total		$ 1,000,000		$ 1,000,000
Stated interest rate		7.15%		7.15%
Maturity date, month and year		2018-06		2018-06
Long-term Debt [Member]
Debt Instrument [Line Items]
Debt Instrument		$ 5,806,000,000		$ 4,732,000,000
Unamortized Issuance Cost		(36,000,000)		(24,000,000)
Unamortized Debt Discount		(3,000,000)		(4,000,000)
Total		5,767,000,000		4,704,000,000
Long-term Debt [Member] | Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument				116,000,000
Total				$ 116,000,000
Credit facility, variable interest rate				1.886%
Credit facility, maturity date				Dec. 1, 2018
Long-term Debt [Member] | 7.35% Senior Notes due October 2017 [Member]
Debt Instrument [Line Items]
Debt Instrument		15,000,000		$ 15,000,000
Unamortized Issuance Cost
Unamortized Debt Discount
Total		$ 15,000,000		$ 15,000,000
Stated interest rate		7.35%		7.35%
Maturity date, month and year		2017-10		2017-10
Long-term Debt [Member] | 7.125% Senior Notes due October 2017 [Member]
Debt Instrument [Line Items]
Debt Instrument		$ 25,000,000		$ 25,000,000
Unamortized Issuance Cost
Unamortized Debt Discount
Total		$ 25,000,000		$ 25,000,000
Stated interest rate		7.125%		7.125%
Maturity date, month and year		2017-10		2017-10
Long-term Debt [Member] | 3.3% Senior Notes due January 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument		$ 350,000,000		$ 350,000,000
Unamortized Issuance Cost		(1,000,000)		(2,000,000)
Unamortized Debt Discount
Total		$ 349,000,000		$ 348,000,000
Stated interest rate		3.30%		3.30%	3.30%
Maturity date, month and year		2018-01		2018-01
Long-term Debt [Member] | 7.5% Senior Notes due February 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument		$ 600,000,000		$ 600,000,000
Unamortized Issuance Cost		(1,000,000)		(2,000,000)
Unamortized Debt Discount
Total		$ 599,000,000		$ 598,000,000
Stated interest rate		7.50%		7.50%
Maturity date, month and year		2018-02		2018-02
Long-term Debt [Member] | 7.15% Senior Notes due June 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument		$ 25,000,000		$ 26,000,000
Unamortized Issuance Cost
Unamortized Debt Discount
Total		$ 25,000,000		$ 26,000,000
Stated interest rate		7.15%		7.15%
Maturity date, month and year		2018-06		2018-06
Long-term Debt [Member] | 4.05% Senior Notes due January 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument		$ 850,000,000		$ 850,000,000
Unamortized Issuance Cost		(5,000,000)		(5,000,000)
Unamortized Debt Discount				(1,000,000)
Total		$ 845,000,000		$ 844,000,000
Stated interest rate		4.05%		4.05%	4.05%
Maturity date, month and year		2020-01		2020-01
Long-term Debt [Member] | 4.10% Senior Notes due March 2022 [Member]
Debt Instrument [Line Items]
Debt Instrument		$ 1,000,000,000		$ 1,000,000,000
Unamortized Issuance Cost		(5,000,000)		(5,000,000)
Unamortized Debt Discount		(1,000,000)		(1,000,000)
Total		$ 994,000,000		$ 994,000,000
Stated interest rate		4.10%		4.10%
Maturity date, month and year		2022-03		2022-03
Long-term Debt [Member] | 4.95% Senior Notes due January 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument		$ 1,000,000,000		$ 1,000,000,000
Unamortized Issuance Cost		(7,000,000)		(7,000,000)
Unamortized Debt Discount		(2,000,000)		(2,000,000)
Total		$ 991,000,000		$ 991,000,000
Stated interest rate		4.95%		4.95%	4.95%
Maturity date, month and year		2025-01		2025-01
Long-term Debt [Member] | Term Loan due November 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument		$ 750,000,000		$ 750,000,000
Unamortized Issuance Cost		(6,000,000)		(3,000,000)
Unamortized Debt Discount
Total		$ 744,000,000		$ 747,000,000
Variable interest rate		2.93%		1.775%
Maturity date, month and year		2018-11		2018-11
Long-term Debt [Member] | Term Loan due December 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument		$ 1,191,000,000
Unamortized Issuance Cost		(11,000,000)
Unamortized Debt Discount
Total		$ 1,180,000,000
Variable interest rate		2.94%
Maturity date, month and year		2020-12
Subsequent Event [Member] | Long-term Debt [Member] | 3.3% Senior Notes due January 2018 [Member]
Debt Instrument [Line Items]
Payments on long-term debt	$ 312,000,000
Subsequent Event [Member] | Long-term Debt [Member] | 7.5% Senior Notes due February 2018 [Member]
Debt Instrument [Line Items]
Payments on long-term debt	388,000,000
Subsequent Event [Member] | Long-term Debt [Member] | Term Loan due November 2018 [Member]
Debt Instrument [Line Items]
Payments on long-term debt	$ 375,000,000

Commitments And Contingencies57

Commitments And Contingencies (Narrative) (Details)	1 Months Ended		3 Months Ended
	Sep. 30, 2015plaintiffitem	Jul. 31, 2013USD ($)	Jun. 30, 2016USD ($)item	Mar. 31, 2010a
Commitments And Contingencies [Line Items]
Obligation under transportation agreements			$ 8,581,000,000
Guarantee obligations relative to the firms transportation agreements and gathering project and services			861,000,000
Actual damages recoverable by plaintiff to be reversed		$ 11,000,000
Disgorgement recoverable by plaintiff to be reversed		$ 24,000,000
Indemnification liability			0
Access Capacity on Future Projects Concentration Risk [Member]
Commitments And Contingencies [Line Items]
Obligation under transportation agreements			3,300,000,000
New Brunswick [Member]
Commitments And Contingencies [Line Items]
Unrecorded capital investments obligation, Exploration program acres coverage (acres) | a				2,518,518
Impairment			$ 39,000,000
Arkansas Royalty Litigation [Member]
Commitments And Contingencies [Line Items]
Number of cases | item			3
Arkansas Royalty Litigation [Member] | Arkansas State Court 2010 and 2013 [Member]
Commitments And Contingencies [Line Items]
Number of cases | item			2
Arkansas Royalty Litigation [Member] | Federal Court 2014 [Member]
Commitments And Contingencies [Line Items]
Number of cases | item			1
Arkansas Royalty Litigation [Member] | Arkansas State Court 2015 [Member]
Commitments And Contingencies [Line Items]
Number of cases | item	3
Number of plaintiffs | plaintiff	248
Minimum [Member] | Arkansas Royalty Litigation [Member] | Federal Court 2014 [Member]
Commitments And Contingencies [Line Items]
Loss contingency, range of possible loss, minimum			$ 100,000,000

Commitments And Contingencies58

Commitments And Contingencies (Schedule Of Future Obligation Under Transportation Agreements) (Details) $ in Millions	Jun. 30, 2016USD ($)
Other Commitments [Line Items]
Less than 1 year	$ 574
1 to 3 years	1,367
3 to 5 years	1,335
5 to 8 years	1,524
More than 8 years	3,781
Total Transportation Charges	8,581
Infrastructure Currently in Service [Member]
Other Commitments [Line Items]
Less than 1 year	561
1 to 3 years	1,136
3 to 5 years	883
5 to 8 years	852
More than 8 years	1,811
Total Transportation Charges	5,243
Pending Regulatory Approval and/or Construction [Member]
Other Commitments [Line Items]
Less than 1 year	13
1 to 3 years	231
3 to 5 years	452
5 to 8 years	672
More than 8 years	1,970
Total Transportation Charges	$ 3,338

Pension Plan And Other Postre59

Pension Plan And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended		12 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015	Mar. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost (gain)		$ 12	$ 4	$ 16	$ 8
Net gain incurred in period	[1]	$ 4		4
Employer contributions				6
Company's expected additional annual contribution				$ 5
Common Stock in Treasury, Shares		31,269		31,269		47,149
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Non-cash curtailment gain (loss)		$ (1)		$ (1)
Settlement loss		(8)		(8)
Benefit obligation		$ 40		$ 40		$ 31
Discount rate		4.20%		4.20%			4.60%
Pension Benefits [Member] | One-time Termination Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Lump-sum payment		$ 28
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Non-cash curtailment gain (loss)		6
Net periodic benefit cost (gain)		(6)	$ 1	$ (5)	$ 2
Benefit obligation		$ 12		$ 12		$ 20
Discount rate		4.20%		4.20%			4.60%
Supplemental Employee Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Common stock purchased under the terms of the Non-Qualified Plan presented as treasury stock				31,269		47,149
[1]	Net of $1 million in taxes for the three and six months ended June 30, 2016.

Pension Plan And Other Postre60

Pension Plan And Other Postretirement Benefits (Pension And Other Postretirement Benefit Costs) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	$ 12	$ 4	$ 16	$ 8
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	2	4	6	8
Interest cost	1	2	3	3
Expected return on plan assets	(1)	(2)	(3)	(4)
Amortization of prior service cost
Amortization of net loss	1		1	$ 1
Curtailment loss	1		1
Settlement loss	$ 8		$ 8

Stock-Based Compensation (Narra

Stock-Based Compensation (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		6 Months Ended
	Jan. 31, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
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		$ 67		$ 67
Weighted average period over which cost is recognized, years				3 years
Stock-based compensation costs - expensed		14	$ 6	$ 37	$ 12
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock options, exercised, number of options
Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period for stock awards from grant date				3 years
Workforce Reduction [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Positions eliminated, percent	40.00%
Stock-based compensation costs - expensed		$ 2		$ 16

Stock-Based Compensation (Sched

Stock-Based Compensation (Schedule Of Stock-Based Compensation Costs) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Stock-based compensation costs - expensed	$ 14	$ 6	$ 37	$ 12
Stock-based compensation costs - capitalized	2	$ 6	5	$ 11
Workforce Reduction [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Stock-based compensation costs - expensed	2		$ 16
Executive Management [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Stock-based compensation costs - expensed	$ 3

Stock-Based Compensation (Summa

Stock-Based Compensation (Summary Of Stock Option Activity) (Details) - Stock Options [Member] $ / shares in Units, shares in Thousands, $ in Thousands	6 Months Ended
	Jun. 30, 2016USD ($)$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock options, Outstanding at December 31, Number of Options | shares	5,623
Stock options, Granted, Number of Options | shares	156
Stock options, Exercised, Number of Options | shares
Stock options, Forfeited or expired, Number of Options | shares	(29)
Stock options, Outstanding at June 30, Number of Options | shares	5,750
Stock options, Exercisable at June 30, Number of Options | $	$ 2,611
Stock options, Outstanding at December 31, Weighted Average Exercise Price	$ 24.57
Stock options, Granted, Weighted Average Exercise Price	8.60
Stock options, Exercised, Weighted Average Exercise Price
Stock options, Forfeited or expired, Weighted Average Exercise Price	37.71
Stock options, Outstanding at June 30, Weighted Average Exercise Price	24.07
Stock options, Exercisable at June 30, Weighted Average Exercise Price	$ 35.95

Stock-Based Compensation (Sum64

Stock-Based Compensation (Summary Of Restricted Stock Activity) (Details) - Restricted Stock [Member]	6 Months Ended
	Jun. 30, 2016$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unvested shares/units at December 31, Number of Shares	7,222,000
Granted, Number of Shares/Units	77,000
Vested, Number of Shares/Units	(2,462,000)
Forfeited, Number of Shares/Units	(89,000)
Unvested shares/units at June 30, Number of Shares	4,748,000
Unvested shares/units at December 31, Weighted Average Fair Value | $ / shares	$ 13.24
Granted, Weighted Average Fair Value | $ / shares	8.35
Vested, Weighted Average Fair Value | $ / shares	9.22
Forfeited, Weighted Average Fair Value | $ / shares	11.64
Unvested shares at June 30, Weighted Average Fair Value | $ / shares	$ 12.89
Workforce Reduction [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vested, Number of Shares/Units	(1,987,379)
Executive Management [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vested, Number of Shares/Units	(151,575)

Stock-Based Compensation (Sum65

Stock-Based Compensation (Summary Of Performance Unit Activity) (Details) - Performance Units [Member]	6 Months Ended
	Jun. 30, 2016$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unvested shares/units at December 31, Number of Shares	407,000
Granted, Number of Shares/Units	1,502,000
Vested, Number of Shares/Units	(412,000)
Forfeited, Number of Shares/Units	(267,000)
Unvested shares/units at June 30, Number of Shares	1,230,000
Unvested shares/units at December 31, Weighted Average Fair Value | $ / shares	$ 36.65
Granted, Weighted Average Fair Value | $ / shares	8.60
Vested, Weighted Average Fair Value | $ / shares	7.61
Forfeited, Weighted Average Fair Value | $ / shares	11.13
Unvested shares at June 30, Weighted Average Fair Value | $ / shares	$ 13.69
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
Workforce Reduction [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vested, Number of Shares/Units	(13,669)
Forfeited, Number of Shares/Units	(71,157)
Executive Management [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vested, Number of Shares/Units	(37,590)
Forfeited, Number of Shares/Units	(195,834)

Segment Information (Details)

Segment Information (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Segment Reporting Information [Line Items]
Revenues	$ 522	$ 764	$ 1,101	$ 1,697
Depreciation, depletion and amortization expense	107	308	250	601
Impairment of natural gas and oil properties	470	1,535	1,504	1,535
Operating income (loss)	(492)	(1,284)	(1,592)	(1,119)
Interest expense	17	1	31	52
Other income (loss), net		3	(3)	2
Gain (loss) on derivatives	(85)	1	(99)	15
Provision (benefit) for income taxes	(1)	(493)		(444)
Assets	7,377	13,480	7,377	13,480	$ 8,086
Capital investments	74	415	196	1,586
Restructuring charges	11		75
Change in accrued expenditures	27	(11)	(51)	(11)
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	(321)	(492)	(699)	(1,153)
Exploration and Production [Member]
Segment Reporting Information [Line Items]
Revenues	291	496	634	1,156
Depreciation, depletion and amortization expense	90	291	217	569
Impairment of natural gas and oil properties	470	1,535	1,504	1,535
Operating income (loss)	(549)	(1,639)	(1,709)	(1,561)
Interest expense	16		30	45
Other income (loss), net	3	3	1	2
Gain (loss) on derivatives	(85)	2	(98)	17
Provision (benefit) for income taxes	(1)	(630)		(612)
Assets	5,000	11,882	5,000	11,882
Capital investments	73	389	193	1,419
Restructuring charges	11		72
Exploration and Production [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	7	6	14	11
Midstream Services [Member]
Segment Reporting Information [Line Items]
Revenues	231	267	467	540
Depreciation, depletion and amortization expense	17	17	33	32
Operating income (loss)	57	355	117	443
Interest expense	1		1	7
Other income (loss), net	(2)		(3)
Gain (loss) on derivatives			(1)
Provision (benefit) for income taxes		138		169
Assets	1,227	1,352	1,227	1,352
Capital investments		19	2	157
Restructuring charges			3
Midstream Services [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	(328)	(499)	(713)	(1,164)
Other [Member]
Segment Reporting Information [Line Items]
Revenues		1		1
Operating income (loss)				(1)
Interest expense		1
Other income (loss), net	(1)		(1)
Gain (loss) on derivatives		(1)		(2)
Provision (benefit) for income taxes		(1)		(1)
Assets	1,150	246	1,150	246
Capital investments	1	7	1	10
Marketable securities	986		986
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	$ (267)	(419)	$ (586)	(995)
WPX and Statoil Property Acquisitions [Member] | Exploration and Production [Member]
Segment Reporting Information [Line Items]
Capital investments		$ 516
WPX Property Acquisition [Member] | Midstream Services [Member]
Segment Reporting Information [Line Items]
Capital investments				$ 119

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2016
Income Taxes [Abstract]
Increase in valuation allowance	$ 216	$ 647
Projected cumulative loss period evaluated for objective negative evidence		3 years

New Accounting Pronouncements (

New Accounting Pronouncements (Narrative) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
New Accounting Pronouncements [Abstract]
Unamortized debt expense	$ 36	$ 24

Subsequent Events (Narrative) (

Subsequent Events (Narrative) (Details) - USD ($)	1 Months Ended		6 Months Ended
	Jul. 31, 2016	Jan. 31, 2015	Jun. 30, 2015	Jun. 30, 2016	Dec. 31, 2015
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Payments on long-term debt			$ 500,000,000
Debt instrument				$ 5,807,000,000	$ 4,733,000,000
Common Stock [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares issued		30,000,000
Price per share		$ 23
Proceeds from issuance of shares		$ 669,000,000
Long-term Debt [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Debt instrument				5,806,000,000	4,732,000,000
Long-term Debt [Member] | Term Loan due November 2018 [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Debt instrument				$ 750,000,000	$ 750,000,000
Subsequent Event [Member] | Common Stock [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Shares issued	98,900,000
Price per share	$ 13
Proceeds from issuance of shares	$ 1,247,000,000
Subsequent Event [Member] | Long-term Debt [Member] | Term Loan due November 2018 [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Payments on long-term debt	375,000,000
Subsequent Event [Member] | Senior Notes [Member]
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Purchase of note principal	$ 700,000,000