Qep Resources (QEP) 10-Q 29 Apr 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015
Document And Entity Information [Abstract]
Entity Registrant Name	QEP RESOURCES, INC.
Entity Central Index Key	1108827
Current Fiscal Year End Date	-19
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	176,661,336
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
REVENUES
Gas sales	$122	$222.50
Oil sales	178.8	288.7
NGL sales	19.1	63.2
Other revenue	4.4	2.5
Purchased gas and oil sales	167.3	240.6
Total Revenues	491.6	817.5
OPERATING EXPENSES
Purchased gas and oil expense	169.4	237.9
Lease operating expense	61.8	56.4
Gas, oil and NGL transportation and other handling costs	65.1	59.9
Gathering and other expense	1.7	1.6
General and administrative	47.4	45.3
Production and property taxes	27.8	47.9
Depreciation, depletion and amortization	195.4	225.9
Exploration expenses	1.1	2.2
Impairment	20	2
Total operating expenses	589.7	679.1
Net gain (loss) from asset sales	-30.5	2.4
OPERATING INCOME	-128.6	140.8
Realized and unrealized gains (losses) on derivative contracts (Note 8)	80.9	-80.9
Interest and other income (expense)	-2.6	2.9
Interest expense	-36.8	-41.9
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	-87.1	20.9
Income tax (provision) benefit	31.5	-8.2
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	-55.6	12.7
Net income from discontinued operations, net of income tax	0	27
NET INCOME (LOSS)	-55.6	39.7
Earnings Per Common Share Attributable to QEP
Earnings Per Share, Basic	($0.32)	$0.22
Earnings Per Share, Diluted	($0.32)	$0.22
Weighted-average common shares outstanding
Used in basic calculation (in shares)	176.2	179.7
Used in diluted calculation (in shares)	176.2	180
Dividends per common share (in dollars per share)	$0.02	$0.02
Continuing Operations [Member]
Earnings Per Common Share Attributable to QEP
Earnings Per Share, Basic	($0.32)	$0.07
Earnings Per Share, Diluted	($0.32)	$0.07
Discontinued Operations [Member]
REVENUES
NGL sales		38
Other revenue		41.9
Purchased gas and oil sales		-13.4	[1]
Total Revenues		66.5
OPERATING EXPENSES
Purchased gas and oil expense		-13.8	[1]
Lease operating expense		-1.1	[1]
Gas, oil and NGL transportation and other handling costs		-16.4	[1]
Gathering and other expense		24.3
General and administrative		11.3
Production and property taxes		1.5
Depreciation, depletion and amortization		14.3
Total operating expenses		20.1
OPERATING INCOME		46.4
Interest expense		-0.6
Net income from discontinued operations, net of income tax		$27
Earnings Per Common Share Attributable to QEP
Earnings Per Share, Basic	$0	$0.15
Earnings Per Share, Diluted	$0	$0.15
[1]	Includes discontinued intercompany eliminations

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Statement of Comprehensive Income [Abstract]
Net income (loss)	($55.60)		$39.70
Pension and other postretirement plans adjustments:
Amortization of net actuarial loss	0.2	[1]	0.1	[1]
Amortization of prior service cost	0.5	[2]	0.9	[2]
Total pension and other postretirement plans adjustments	0.7		1
Other comprehensive income	0.7		1
Comprehensive income (loss)	($54.90)		$40.70
[1]	Presented net of income tax expense of $0.1 million and $0.1 million during the three months ended March 31, 2015, and 2014, respectively.
[2]	Presented net of income tax expense of $0.3 million and $0.4 million during the three months ended March 31, 2015, and 2014, respectively.

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Pension and other postretirement plans adjustments:
Tax expense (benefit) on net unamortized gain (loss) incurred	$0.10	$0.10
Tax expense (benefit) on prior service cost incurred	$0.30	$0.40

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Current Assets
Cash and cash equivalents	$500.40	$1,160.10
Accounts receivable, net	319.4	441.9
Fair value of derivative contracts	311.7	339
Gas, oil and NGL inventories at lower of average cost or market	7.6	13.7
Prepaid expenses and other	37.8	46.8
Total Current Assets	1,176.90	2,001.50
Property, Plant and Equipment (successful efforts method for gas and oil properties)
Proved properties	12,558.90	12,278.70
Unproved properties	821.9	825.2
Marketing and resources	296.3	293.8
Material and supplies	50.4	54.3
Total Property, Plant and Equipment	13,727.50	13,452
Less Accumulated Depreciation, Depletion and Amortization
Exploration and production	6,357.70	6,153
Marketing and other	72.8	67.8
Total Accumulated Depreciation, Depletion and Amortization	6,430.50	6,220.80
Net Property, Plant and Equipment	7,297	7,231.20
Fair value of derivative contracts	13.7	9.9
Other noncurrent assets	36.8	44.2
TOTAL ASSETS	8,524.40	9,286.80
Current Liabilities
Checks outstanding in excess of cash balances	15.8	54.7
Accounts payable and accrued expenses	453.5	575.4
Income taxes payable	0	532.1
Production and property taxes	45.9	61.7
Interest payable	33.7	36.4
Deferred income taxes	94	84.5
Total Current Liabilities	642.9	1,344.80
Long-term debt	2,218.30	2,218.10
Deferred income taxes	1,348.90	1,362.70
Asset retirement obligations	196.3	193.8
Other long-term liabilities	98.1	92.1
Commitments and contingencies (Note 11)
EQUITY
Common stock - par value $0.01 per share; 500.0 million shares authorized; 177.0 million and 176.2 million shares issued, respectively	1.8	1.8
Treasury stock - 0.3 million and 0.8 million shares, respectively	-11	-25.4
Additional paid-in capital	530.1	535.3
Retained earnings	3,522.60	3,587.90
Accumulated other comprehensive loss	-23.6	-24.3
Total Common Shareholders' Equity	4,019.90	4,075.30
TOTAL LIABILITIES AND EQUITY	$8,524.40	$9,286.80

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, except Per Share data, unless otherwise specified
EQUITY
Common stock, par value (in dollars per share)	$0.01	$0.01
Common stock, shares authorized (in shares)	500	500
Common stock, shares issued (in shares)	177	176.2
Treasury stock (in shares)	0.3	0.8

CONDENSED_CONSOLIDATED_STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
OPERATING ACTIVITIES
Net income (loss)	($55.60)	$39.70
Net income attributable to noncontrolling interest	0	5.8
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	195.4	240.2
Deferred income taxes	-4.8	20.7
Impairment	20	2
Share-based compensation	9.1	7.5
Amortization of debt issuance costs and discounts	1.9	1.7
Net (gain) loss from asset sales	30.5	-2.4
Income from unconsolidated affiliates	0	-2.2
Distributions from unconsolidated affiliates and other	0	2.7
Unrealized (gains) loss on derivative contracts	23.5	45.5
Changes in operating assets and liabilities	-492.7	-38.8
Net Cash (Used In) Provided by Operating Activities	-272.7	322.4
INVESTING ACTIVITIES
Property acquisitions	0	-946.6
Property, plant and equipment, including dry exploratory well expense	-342.1	-330.2
Proceeds from disposition of assets	1.6	2.9
Acquisition deposit held in escrow	0	50
Net Cash Used in Investing Activities	-340.5	-1,223.90
FINANCING ACTIVITIES
Checks outstanding in excess of cash balances	-38.9	-12.5
Long-term debt issued	0	300
Long-term debt issuance costs paid	0	-1.1
Proceeds from credit facility	0	1,643
Repayments of credit facility	0	-1,021.50
Treasury stock repurchases	-1.9	-5.5
Other capital contributions	-0.4	2.9
Dividends paid	-3.5	-3.6
Excess tax (provision) benefit on equity-based compensation	-1.8	-0.6
Distribution to noncontrolling interest	0	-7.6
Net Cash (Used In) Provided by Financing Activities	-46.5	893.5
Change in cash and cash equivalents	-659.7	-8
Beginning cash and cash equivalents	1,160.10	11.9
Ending cash and cash equivalents	500.4	3.9
Supplemental Disclosures:
Cash paid for interest, net of capitalized interest	37.6	43.8
Cash paid for income taxes	509.8	0
Non-cash investing activities
Change in capital expenditure accrual balance	($59.20)	$11.60

Nature_of_Business

Nature of Business	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Business	Nature of Business
	QEP Resources, Inc. (QEP or the Company) is a holding company with two principal subsidiaries, QEP Energy Company and QEP Marketing Company, which are engaged in two primary lines of business: (i) oil and gas exploration and production (QEP Energy) and (ii) oil and gas marketing, operation of the Haynesville Gathering System and an underground gas storage facility and corporate (QEP Marketing and Other).
	QEP's operations are focused in two geographic regions: the Northern Region (primarily in Wyoming, North Dakota and Utah) and the Southern Region (primarily in Texas and Louisiana) of the United States. QEP's corporate headquarters are located in Denver, Colorado.
	Shares of QEP’s common stock trade on the New York Stock Exchange (NYSE) under the ticker symbol “QEP”.

Basis_of_Presentation_of_Inter

Basis of Presentation of Interim Consolidated Financial Statements	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation of Interim Consolidated Financial Statements	Basis of Presentation of Interim Consolidated Financial Statements
	The interim Condensed Consolidated Financial Statements contain the accounts of QEP and its majority-owned or controlled subsidiaries. The Condensed Consolidated Financial Statements were prepared in accordance with United States Generally Accepted Accounting Principles (GAAP) and with the instructions for Quarterly Reports on Form 10-Q and Regulations S-X and S-K. All significant intercompany accounts and transactions have been eliminated in consolidation.
	The Condensed Consolidated Financial Statements reflect all normal recurring adjustments and accruals that are, in the opinion of management, necessary for a fair statement of financial position and results of operations for the interim periods presented. Interim condensed consolidated financial statements and the year-end balance sheet do not include all of the information and notes required by GAAP for audited annual consolidated financial statements. These Condensed Consolidated Financial Statements should be read in conjunction with the Consolidated Financial Statements and Notes thereto included in the Company’s Annual Report on Form 10-K/A for the year ended December 31, 2014.
	The preparation of the Condensed Consolidated Financial Statements and Notes in conformity with GAAP requires that management make estimates and assumptions that affect revenues, expenses, assets and liabilities, and disclosure of contingent assets and liabilities. Actual results could differ from estimates. The results of operations for the three months ended March 31, 2015, are not necessarily indicative of the results that may be expected for the year ending December 31, 2015.
	Impairment of Long-Lived Assets
	During the three months ended March 31, 2015, QEP Energy recorded impairment charges of $20.0 million, of which $19.4 million was related to proved properties due to lower future prices and $0.6 million was related to expiring leaseholds on unproved properties. Of the $19.4 million impairment on proved properties, $14.5 million related to oil and gas properties in the Southern Region and $4.9 million related to oil and gas properties in the Northern Region.
	New accounting pronouncements
	In February 2015, the Financial Accounting Standards Board (FASB) issued Accounting Standard Update (ASU) No. 2015-02, Consolidation (Topic 810), which amends the current consolidation guidance. The amendments affect both the variable interest entity and voting interest entity consolidation models. The amendments will be effective prospectively for reporting periods beginning on or after December 15, 2015, and early adoption is permitted. The Company is currently assessing the standard update and does not believe there will be a significant impact on the Company's consolidated financial statements.
	In January 2015, the FASB issued ASU No. 2015-01, Income Statement — Extraordinary and Unusual Items (Subtopic 225-20), which eliminates the concept of extraordinary items from GAAP. The amendments will be effective for reporting periods beginning on or after December 15, 2015, and early adoption is permitted. Additionally, a reporting entity also may apply the amendments retrospectively for all periods presented in the financial statements. The Company is currently assessing the standard update and does not believe there will be a significant impact on the Company's consolidated financial statements.

Acquisitions_Divestitures

Acquisitions & Divestitures	3 Months Ended
	Mar. 31, 2015
Business Combinations [Abstract]
Acquisitions [Text Block]	Acquisitions and Divestitures
	Permian Basin Acquisition
	On February 25, 2014, QEP Energy acquired oil and gas properties in the Permian Basin of Texas for an aggregate purchase price of $941.8 million (the Permian Basin Acquisition). The acquired properties consist of approximately 26,500 net acres of producing and undeveloped oil and gas properties and approximately 270 vertical producing wells in the Permian Basin, which created a new core area of operation for QEP Energy. The acquisition was funded with $50.0 million of restricted cash, $300.0 million from the Company's expanded term loan and the remainder was funded from its revolving credit facility.
	The Permian Basin Acquisition meets the definition of a business combination under ASC 805, Business Combinations, as it included significant proved properties. QEP allocated the cost of the Permian Basin Acquisition to assets acquired and liabilities assumed based on fair values as of the acquisition date. Revenues of $29.5 million and a net loss of $1.5 million were generated from the acquired properties during the three months ended March 31, 2015. Revenues of $14.9 million and net income of $3.7 million were generated from the acquired properties from February 25, 2014, to March 31, 2014, and are included in QEP's Condensed Consolidated Statements of Operations.
	The following table presents a summary of the Company's purchase accounting entries (in millions):
	Consideration:
	Total consideration	$	941.8
	Amounts recognized for fair value of assets acquired and liabilities assumed:
	Proved properties	$	472.1
	Unproved properties	480.6
	Asset retirement obligations	(9.7		)
	Liabilities assumed	(1.2		)
	Total fair value	$	941.8
	The following unaudited, pro forma results of operations are provided for the three months ended March 31, 2014. Pro forma results are not provided for the three months ended March 31, 2015, because the Permian Basin Acquisition occurred during the first quarter of 2014, and therefore there is no pro forma impact on the first quarter of 2015. These supplemental pro forma results of operations are provided for illustrative purposes only and may not be indicative of the actual results that would have been achieved by the acquired properties for the period presented, or that may be achieved by such properties in the future. Future results may vary significantly from the results reflected in this pro forma financial information because of future events and transactions, as well as other factors. The pro forma information is based on QEP's consolidated results of operations for the three months ended March 31, 2014, the acquired properties' historical results of operations, and estimates of the effect of the transaction on the combined results. The pro forma results of operations have been prepared by adjusting the historical results of QEP to include the historical results of the acquired properties based on information provided by the seller and the impact of the purchase price allocation. The pro forma results of operations do not include any cost savings or other synergies that may result from the Permian Basin Acquisition or any estimated costs that have been or will be incurred by the Company to integrate the acquired properties.
			Three Months Ended
			March 31,
			2014		2014
			Actual		Pro forma
		(in millions, except per share data)
	Revenues		$	817.5	$	843.6
	Net income		$	39.7	$	46.7
	Earnings per common share
	Basic		$	0.22	$	0.26
	Diluted		$	0.22	$	0.26
	Divestitures
	In December 2014, QEP Energy sold its interest in certain non-core properties in southern Oklahoma for aggregate proceeds of $96.3 million, subject to post-closing purchase price adjustments, and recorded a pre-tax gain on sale of $53.3 million for the year ended December 31, 2014. QEP Energy recorded a pre-tax loss on sale of $1.8 million for the three months ended March 31, 2015, due to post-closing purchase price adjustments.
	In June 2014, QEP Energy sold its interest in certain non-core properties in the Midcontinent area and other non-core assets in the Williston Basin for aggregate proceeds of $692.9 million, subject to post-closing purchase price adjustments, and recorded a pre-tax loss of $199.4 million for the year ended December 31, 2014. QEP recorded a pre-tax loss on sale of $26.8 million for the three months ended March 31, 2015, due to post-closing purchase price adjustments. These gains and losses are reported on the Condensed Consolidated Statements of Operations in "Net gain (loss) from asset sales".

Discontinued_Operations

Discontinued Operations	3 Months Ended
	Mar. 31, 2015
Discontinued Operations and Disposal Groups [Abstract]
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	Discontinued Operations
	In October 2014, the Company announced that its wholly owned subsidiary, QEP Field Services Company (QEP Field Services), had entered into a definitive agreement to sell substantially all of its midstream business, including the Company's ownership interest in QEP Midstream Partners, LP (QEP Midstream) to Tesoro Logistics LP (Tesoro). On December 2, 2014, QEP closed the sale of its midstream business to Tesoro (Midstream Sale) for total cash proceeds of approximately $2.5 billion, including $230.0 million to refinance debt at QEP Midstream, subject to post-closing adjustments, and QEP recorded a pre-tax gain of approximately $1.8 billion for the year ended December 31, 2014.
	The operating results of QEP Field Services, excluding the Haynesville Gathering System (the Discontinued Operations of QEP Field Services), have been classified as discontinued operations on the Condensed Consolidated Statements of Operations and Notes accompanying the Condensed Consolidated Financial Statements for the three months ended March 31, 2014. QEP will have continuing cash outflows to the entities sold as a part of the Midstream Sale for gathering, processing and water handling costs in Pinedale, the Uinta Basin and a portion of its Williston Basin operations. The contracts related to these cash flows vary in length from month-to-month to over a year and will be reviewed periodically in the normal course of business. Historically, these transactions were eliminated in consolidation, as they represented transactions between two related entities but are now reflected as part of the continuing operations for QEP. For the three months ended March 31, 2015 and 2014, cash outflows for these transactions that are included in continuing operations were $22.7 million and $34.9 million, respectively.
	In connection with the announcement of QEP's plan to separate its midstream business, the Board of Directors approved an employee retention plan to provide substantially all QEP Field Services' employees as of December 1, 2013, with a one-time lump-sum cash payment on the earlier of December 31, 2014, or whenever the separation of QEP Field Services occurred, conditioned on continued employment with QEP Field Services or a successor through the payment date unless the employee is terminated prior to such date. QEP recognized $10.4 million of costs under this retention plan in 2014, of which $2.3 million was included in "Discontinued operations, net of income tax" on the Condensed Consolidated Statements of Operations for the three months ended March 31, 2014.
	Condensed Consolidated Statement of Operations
	The Discontinued Operations of QEP Field Services are summarized below:
		Three Months Ended
		March 31,
		2014
	REVENUES
	NGL sales	$	38
	Other revenue	41.9
	Purchased gas and oil sales(1)	(13.4		)
	Total Revenues	66.5
	OPERATING EXPENSES
	Purchased gas and oil expense(1)	(13.8		)
	Lease operating expense(1)	(1.1		)
	Natural gas, oil and NGL transport and other handling costs(1)	(16.4		)
	Gathering, processing, and other	24.3
	General and administrative	11.3
	Production and property taxes	1.5
	Depreciation, depletion and amortization	14.3
	Total Operating Expenses	20.1
	OPERATING INCOME	46.4
	Income from unconsolidated affiliates	2.2
	Interest expense	(0.6		)
	INCOME FROM DISCONTINUED OPERATIONS BEFORE INCOME TAXES (2)	48
	Income taxes	(15.2		)
	NET INCOME FROM DISCONTINUED OPERATIONS	32.8
	Net income attributable to noncontrolling interest	(5.8		)
	NET INCOME FROM DISCONTINUED OPERATIONS, NET OF INCOME TAX	$	27
	(1)	Includes discontinued intercompany eliminations.
	(2)	Includes income from discontinued operations before income taxes attributable to QEP from QEP Midstream (of which QEP owned 57.8%) of $6.8 million for the three months ended March 31, 2014.
	Condensed Consolidated Statement of Cash Flows
	The impact of the Discontinued Operations of QEP Field Services on the Condensed Consolidated Statement of Cash Flows for "Depreciation, depletion and amortization" contained in "Cash flows from operating activities" was $14.3 million for the three months ended March 31, 2014. The impact on cash used for "Property, plant and equipment, including dry exploratory well expense" contained in "Cash flows from investing activities" was $12.7 million for the three months ended March 31, 2014.

Earnings_Per_Share

Earnings Per Share	3 Months Ended
	Mar. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Share	Earnings Per Share
	Basic earnings per share (EPS) are computed by dividing net income by the weighted-average number of common shares outstanding during the reporting period. Diluted EPS includes the potential increase in the number of outstanding shares that could result from the exercise of in-the-money stock options. QEP’s unvested restricted shares are included in weighted-average basic common shares outstanding because once the shares are granted, the restricted shares are considered issued and outstanding, the historical forfeiture rate is minimal and the restricted shares receive dividends.
	Unvested share-based payment awards that contain non-forfeitable rights to dividends or dividend equivalents are considered participating securities and are included in the computation of earnings per share pursuant to the two-class method. The Company’s unvested restricted stock awards contain non-forfeitable dividend rights and participate equally with common stock with respect to dividends issued or declared. However, the Company’s unvested restricted stock does not have a contractual obligation to share in losses of the Company. The Company’s unexercised stock options do not contain rights to dividends. Under the two-class method, the earnings used to determine basic earnings per common share are reduced by an amount allocated to participating securities. When the Company records a net loss, none of the loss is allocated to the participating securities since the securities are not obligated to share in Company losses. Use of the two-class method has an insignificant impact on the calculation of basic and diluted earnings per common share. During the three months ended March 31, 2015 and 2014, there were no anti-dilutive shares.
	A reconciliation of the components of basic and diluted shares used in the EPS calculation follows:
		Three Months Ended
		March 31,
		2015	2014
		(in millions)
	Weighted-average basic common shares outstanding	176.2	179.7
	Potential number of shares issuable upon exercise of in-the-money stock options under the Long-term Stock Incentive Plan	—	0.3
	Average diluted common shares outstanding	176.2	180

Asset_Retirement_Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations
	QEP records asset retirement obligations (ARO) when there are legal obligations associated with the retirement of tangible long-lived assets. The Company's ARO liability applies primarily to abandonment costs associated with oil and gas wells and certain other properties. The fair values of such costs are estimated by Company personnel based on abandonment costs of similar assets and depreciated over the life of the related assets. Revisions to the ARO estimates result from changes in expected cash flows or material changes in estimated asset retirement costs. The ARO liability is adjusted to present value each period through an accretion calculation using a credit-adjusted risk-free interest rate. Of the $197.2 million and $195.1 million ARO liability for continuing operations for the periods ended March 31, 2015 and December 31, 2014, $0.9 million and $1.3 million were included, respectively, as a current liability in "Accounts payable and accrued expenses" on the Condensed Consolidated Balance Sheets.
	The following is a reconciliation of the changes in the Company's ARO for the period specified below:
		Asset Retirement Obligations
		2015
		(in millions)
	ARO liability at January 1,	$	195.1
	Accretion	2.1
	Additions	0.6
	Liabilities settled	(0.6		)
	ARO liability at March 31,	$	197.2

Fair_Value_Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements
	QEP measures and discloses fair values in accordance with the provisions of ASC 820, Fair Value Measurements and Disclosures. This guidance defines fair value in applying GAAP, establishes a framework for measuring fair value and expands disclosures about fair-value measurements. ASC 820 also establishes a fair-value hierarchy. Level 1 inputs are quoted prices (unadjusted) for identical assets or liabilities in active markets that the Company has the ability to access at the measurement date. Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. Level 3 inputs are unobservable inputs for the asset or liability.
	QEP has determined that its commodity derivative instruments are Level 2. The Level 2 fair value of commodity derivative contracts (see Note 8 - Derivative Contracts) is based on market prices posted on the respective commodity exchange on the last trading day of the reporting period and industry standard discounted cash flow models. QEP primarily applies the market approach for recurring fair value measurements and maximizes its use of observable inputs and minimizes its use of unobservable inputs. QEP considers bid and ask prices for valuing the majority of its assets and liabilities measured and reported at fair value. In addition to using market data, QEP makes assumptions in valuing its assets and liabilities, including assumptions about risk and the risks inherent in the inputs to the valuation technique. The Company's policy is to recognize significant transfers between levels at the end of the reporting period.
	Certain of the Company's commodity derivative instruments are valued using industry standard models that consider various inputs, including quoted forward prices for commodities, time value, volatility, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these inputs are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable prices at which transactions are executed in the marketplace. The determination of fair value for derivative assets and liabilities also incorporates nonperformance risk for counterparties and for QEP. Derivative contract fair values are reported on a net basis to the extent a legal right of offset with the counterparty exists.
	The fair value of financial assets and liabilities at March 31, 2015 and December 31, 2014, is shown in the table below:
		Fair Value Measurements
		Gross Amounts of Assets and Liabilities						Netting			Net Amounts Presented on the Condensed Consolidated Balance Sheets
		Level 1		Level 2		Level 3		Adjustments(1)
		(in millions)
		31-Mar-15
	Financial Assets
	Commodity derivative instruments - short-term	$	—	$	312.5	$	—	$	(0.8	)	$	311.7
	Commodity derivative instruments - long-term	—		13.7		—		—			13.7
	Total financial assets	$	—	$	326.2	$	—	$	(0.8	)	$	325.4
	Financial Liabilities
	Commodity derivative instruments - short-term	$	—	$	0.8	$	—	$	(0.8	)	$	—
	Total financial liabilities	$	—	$	0.8	$	—	$	(0.8	)	$	—
		31-Dec-14
	Financial Assets
	Commodity derivative instruments - short-term	$	—	$	339.3	$	—	$	(0.3	)	$	339
	Commodity derivative instruments - long-term	—		9.9		—		—			9.9
	Total financial assets	$	—	$	349.2	$	—	$	(0.3	)	$	348.9
	Financial Liabilities
	Commodity derivative instruments - short-term	$	—	$	0.3	$	—	$	(0.3	)	$	—
	Total financial liabilities	$	—	$	0.3	$	—	$	(0.3	)	$	—
	_______________________
	(1)	The Company nets its derivative contract assets and liabilities outstanding with the same counterparty on the Condensed Consolidated Balance Sheets, as the contracts contain netting provisions. Refer to Note 8 - Derivative Contracts, for additional information regarding the Company's derivative contracts.
	The following table discloses the fair value and related carrying amount of certain financial instruments not disclosed in other Notes accompanying the Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q:
		Carrying		Level 1		Carrying		Level 1
		Amount		Fair Value		Amount		Fair Value
		March 31, 2015				December 31, 2014
		(in millions)
	Financial assets
	Cash and cash equivalents	$	500.4	$	500.4	$	1,160.10	$	1,160.10
	Financial liabilities
	Checks outstanding in excess of cash balances	$	15.8	$	15.8	$	54.7	$	54.7
	Long-term debt	$	2,218.30	$	2,248.50	$	2,218.10	$	2,171.60
	The carrying amounts of cash and cash equivalents and checks outstanding in excess of cash balances approximate fair value. The fair value of fixed-rate long-term debt is based on the trading levels and dollar prices for the Company’s debt at the end of the quarter. The carrying amount of variable-rate long-term debt approximates fair value because the floating interest rate paid on such debt was set for periods of one month.
	The initial measurement of ARO at fair value is calculated using discounted cash flow techniques and based on internal estimates of future retirement costs associated with property, plant and equipment. Significant Level 3 inputs used in the calculation of asset retirement obligations include plugging costs and reserve lives. A reconciliation of the Company’s ARO is presented in Note 6 – Asset Retirement Obligations.

Derivative_Contracts

Derivative Contracts	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities Disclosure [Text Block]	Derivative Contracts
	QEP has established policies and procedures for managing commodity price volatility through the use of derivative instruments. In the normal course of business, QEP uses commodity price derivative instruments to reduce the impact of potential downward movements in commodity prices on cash flow, returns on capital investment, and other financial results. However, these instruments typically limit gains from favorable price movements. The volume of production subject to commodity derivative instruments and the mix of the instruments are frequently evaluated and adjusted by management in response to changing market conditions. QEP may enter into commodity derivative contracts for up to 100% of forecasted production from proved reserves. In addition, QEP may enter into commodity derivative contracts on a portion of its gas sales and purchases for marketing transactions. QEP does not enter into commodity derivative instruments for speculative purposes.
	QEP uses commodity derivative instruments known as fixed-price swaps or collars to realize a known price or price range for a specific volume of production delivered into a regional sales point. QEP's commodity derivative instruments do not require the physical delivery of gas, oil, or NGL between the parties at settlement. Swap transactions are settled in cash with one party paying the other for the net difference in prices, multiplied by the contract volume, for the settlement period. Gas price derivative instruments are typically structured as fixed-price swaps at regional price indices. Oil price derivative instruments are typically structured as NYMEX fixed-price swaps based at Cushing, Oklahoma or oil price swaps that use IntercontinentalExchange, Inc. (ICE) Brent oil prices as the reference price. QEP also enters into crude oil and natural gas basis swaps to achieve a fixed price swap for a portion of its oil and gas that it sells at prices that reference specific index prices.
	QEP enters into commodity derivative transactions that do not have margin requirements or collateral provisions that would require payments prior to the scheduled settlement dates. Commodity derivative contract counterparties are normally financial institutions and energy trading firms with investment-grade credit ratings. QEP routinely monitors and manages its exposure to counterparty risk by requiring specific minimum credit standards for all counterparties and avoids concentration of credit exposure by transacting with multiple counterparties.
	During 2014, QEP also used interest rate swaps to mitigate a portion of its exposure to interest rate volatility associated with its $600.0 million term loan. For the $300.0 million term loan issued during 2012, QEP locked in a fixed interest rate of 1.07% in exchange for a variable interest rate indexed to the one-month LIBOR. For the incremental $300.0 million borrowed under the term loan during 2014, QEP locked in a fixed interest rate of 0.86%. These interest rate swaps were terminated in December 2014 in conjunction with the extinguishment of QEP's term loan.
	QEP Energy Derivative Contracts
	The following table sets forth QEP Energy’s quantities and average prices for its commodity derivative contracts as of March 31, 2015:
	Year		Type of Contract		Index	Total			Average Swap price per unit
						Volumes
						(in millions)
	Gas sales					(MMBtu)
	2015		SWAP		NYMEX HH	52.3			$	3.48
	2015		SWAP		IFNPCR	35.8			$	3.55
	2016		SWAP		NYMEX HH	14.6			$	3.29
	2016		SWAP		IFNPCR	11			$	2.97
	Oil sales					(bbls)
	2015		SWAP		NYMEX WTI	6.6			$	85.89
	2015		SWAP		ICE Brent	0.3			$	104.95
	2016		SWAP		NYMEX WTI	1.1			$	70.85
	The following table sets forth QEP Energy's crude oil collars as of March 31, 2015:
					Total Volume		Average Price				Average Price
	Year		Index				Floor				Ceiling
					(in millions)		($/bbl)				($/bbl)
					(bbls)
	2015		NYMEX WTI		0.3		$	50			$	64.35
	The following table sets forth QEP Energy's gas basis swaps as of March 31, 2015:
	Year		Index		Index Less Differential	Total Volumes			Weighted Average Differential
						(in millions)			($/MMBtu)
	Gas basis swaps					(MMBtu)
	2015		NYMEX HH		IFNPCR	27.5			$	(0.30	)
	QEP Marketing Derivative Contracts
	QEP Marketing enters into commodity derivative transactions to lock in a margin on gas volumes placed into storage and for marketing transactions in which QEP Marketing sells gas volumes at a fixed price. The following table sets forth QEP Marketing’s volumes and swap prices for its commodity derivative contracts as of March 31, 2015:
	Year		Type of Contract		Index	Total			Average Swap price
						Volumes			per MMBtu
						(in millions)
	Gas sales					(MMBtu)
	2015		SWAP		IFNPCR	1.7			$	3.29
	2016		SWAP		IFNPCR	1.4			$	3.34
	Gas purchases					(MMBtu)
	2015		SWAP		IFNPCR	1.3			$	2.88
	QEP Derivative Financial Statement Presentation
	The following table identifies the condensed consolidated balance sheet location of QEP’s outstanding derivative contracts on a gross contract basis as opposed to the net contract basis presentation in the Condensed Consolidated Balance Sheets and the related fair values at the balance sheet dates:
				Gross asset derivative							Gross liability derivative
				instruments fair value							instruments fair value
		Balance Sheet		March 31,			31-Dec-14				March 31,		31-Dec-14
		line item		2015							2015
				(in millions)
	Current:
	Commodity	Fair value of derivative contracts		$	312.5		$	339.3			$	0.8	$	0.3
	Long-term:
	Commodity	Fair value of derivative contracts		13.7			9.9				—		—
	Total derivative instruments			$	326.2		$	349.2			$	0.8	$	0.3
	The effects of the change in fair value and settlement of QEP's derivative contracts recorded in "Realized and unrealized gains (losses) on derivative contracts" on the Condensed Consolidated Statements of Operations are summarized in the following tables:
			Three Months Ended
	Derivative instruments not designated as cash flow hedges		March 31,
			2015			2014
	Realized gains (losses) on commodity derivative contracts		(in millions)
	QEP Energy
	Gas derivative contracts		$	17.9		$	(20.4	)
	Oil derivative contracts		84			(12.9		)
	QEP Marketing
	Gas derivative contracts		2.5			(1.4		)
	Total realized gains (losses) on commodity derivative contracts		104.4			(34.7		)
	Unrealized gains (losses) on commodity derivative contracts
QEP Energy
Gas derivative contracts		11.4			(24.3		)
Oil derivative contracts		(33.1		)	(20.9		)
QEP Marketing
Gas derivative contracts		(1.8		)	(0.3		)
Total unrealized gains (losses) on commodity derivative contracts		(23.5		)	(45.5		)
Total realized and unrealized gains (losses) on commodity derivative contracts		$	80.9		$	(80.2	)
Realized gains (losses) on interest rate swaps
Realized losses on interest rate swaps		$	—		$	(0.7	)
Total realized gains (losses) on interest rate swaps		$	—		$	(0.7	)
Total net realized gains (losses) on derivative contracts		$	104.4		$	(35.4	)
Total net unrealized gains (losses) on derivative contracts		(23.5		)	(45.5		)
Grand Total		$	80.9		$	(80.9	)

Debt

Debt	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Debt	Debt
	As of the indicated dates, the principal amount of QEP’s debt, including amounts outstanding under QEP's revolving credit facility and senior notes, consisted of the following:
		March 31,			December 31,
		2015			2014
		(in millions)
	Revolving Credit Facility due 2019	$	—		$	—
	6.05% Senior Notes due 2016	176.8			176.8
	6.80% Senior Notes due 2018	134			134
	6.80% Senior Notes due 2020	136			136
	6.875% Senior Notes due 2021	625			625
	5.375% Senior Notes due 2022	500			500
	5.25% Senior Notes due 2023	650			650
	Total principal amount of debt	2,221.80			2,221.80
	Less unamortized discount	(3.5		)	(3.7		)
	Total long-term debt outstanding	$	2,218.30		$	2,218.10
	Of the total debt outstanding on March 31, 2015, the 6.05% Senior Notes due September 1, 2016, the 6.80% Senior Notes due April 1, 2018 and the 6.80% Senior Notes due March 1, 2020, will mature within the next five years. The revolving credit facility matures on December 2, 2019.
	Credit Facilities
	QEP's Credit Facility
	QEP’s revolving credit facility, which matures in December 2019, provides for loan commitments of $1.8 billion from a group of financial institutions. The credit facility provides for borrowings at short-term interest rates and contains customary covenants and restrictions.
	On December 2, 2014, QEP entered into the Fourth Amendment to its Credit Agreement, which increased the aggregate principal amount of commitments to $1.8 billion, extended the maturity date to December 2, 2019, and made minor adjustments to other provisions and covenants.
	During the three months ended March 31, 2014, QEP’s weighted-average interest rate on borrowings from its credit facility was 2.19%. At March 31, 2015 and December 31, 2014, QEP had no borrowings outstanding, had $3.7 million in letters of credit outstanding under the credit facility and was in compliance with the covenants under the credit facility.
	Senior Notes
	At March 31, 2015, the Company had $2,221.8 million principal amount of senior notes outstanding with maturities ranging from September 2016 to May 2023 and coupons ranging from 5.25% to 6.875%. The senior notes pay interest semi-annually, are unsecured senior obligations and rank equally with all of our other existing and future unsecured and senior obligations. QEP may redeem some or all of its senior notes at any time before their maturity at a redemption price based on a make-whole amount plus accrued and unpaid interest to the date of redemption. The indentures governing QEP’s senior notes contain customary events of default and covenants that may limit QEP’s ability to, among other things, place liens on its property or assets.

Contingencies

Contingencies	3 Months Ended
	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Contingencies	Contingencies
	QEP is involved in various commercial and regulatory claims, litigation and other legal proceedings that arise in the ordinary course of its business. QEP assesses these claims in an effort to determine the degree of probability and range of possible loss for potential accrual in its Consolidated Financial Statements. In accordance with ASC 450, Contingencies, an accrual is recorded for a loss contingency when its occurrence is probable and damages are reasonably estimable based on the anticipated most likely outcome or the minimum amount within a range of possible outcomes. Because legal proceedings are inherently unpredictable, and unfavorable resolutions can occur, assessing contingencies is highly subjective and requires judgments about uncertain future events. When evaluating contingencies, QEP may be unable to provide a meaningful estimate due to a number of factors, including the procedural status of the matter in question, the presence of complex or novel legal theories, the ongoing discovery and/or development of information important to the matter. QEP is unable to estimate reasonably possible losses (in excess of recorded accruals, if any) for its loss contingencies for the reasons set forth above. QEP believes, however, that the resolution of pending proceedings (after accruals, insurance coverage, and indemnification arrangements) will not be material to QEP's financial position but could be material to results of operations in a particular quarter or year.
	Litigation
	Rocky Mountain Resources, LLC v. QEP Energy Company, Wexpro Company, Ultra Resources, Inc. and Lance Oil & Gas Company, Inc., Civil No. 2011-7816, District Court of Sublette County, Wyoming. Rocky Mountain Resources, LLC (Rocky Mountain) filed its complaint on March 30, 2011, seeking determination of the existence of a 4% overriding royalty interest in State of Wyoming oil and gas Lease No. 79-0645 covering Section 16, T32-N R-109-W, Sublette County, Wyoming. QEP and the other defendants are current lessees of Lease 79-0645. Rocky Mountain alleges that the defendants have received benefits from Lease 79-0645 and have failed to pay Rocky Mountain monies associated with the claimed 4% overriding royalty interest since the issuance of the lease by the State of Wyoming in 1980. Rocky Mountain asserts claims for quiet title, declaratory judgment, breach of contract, breach of duty of good faith, conversion, constructive trust and prejudgment interest. On May 7, 2014, the trial court entered its order granting plaintiff's motion for summary judgment on the issue of whether the overriding royalty interest burdens QEP's lease. On June 17, 2014, the Supreme Court of Wyoming denied QEP's Petition for Writ of Review. On August 21, 2014, the trial court denied QEP’s Motion to Certify Questions of Law to the Wyoming Supreme Court. At the conclusion of a trial in February 2015, and after being instructed by the Court that the overriding royalty interest burdened QEP’s lease, a jury rendered a verdict against QEP and awarded Rocky Mountain damages in the amount of $16.7 million, including interest. QEP believes that the Court’s ruling on summary judgment and the resulting jury instructions are in error and will appeal to the Wyoming Supreme Court. While the appeal is pending, post-judgment interest accrues at the statutory rate of 10%. QEP estimates that, notwithstanding the verdict, the range of reasonably possible losses is still zero to $20.0 million.
	Yannick Gagné and others similarly situated v. QEP Resources, Inc., No. 480-06-1-132, Superior Court, Province of Quebec, Canada. Plaintiffs seek to represent a class of all persons who sustained damages as a result of the July 6, 2013 train derailment in Lac-Mégantic, Quebec, which resulted in substantial loss of life and property. The fourth amended motion to authorize the bringing of a class action was filed on February 19, 2014, and names numerous defendants, including the rail company that transported the crude oil (which filed for bankruptcy protection in August 2013). The plaintiffs contend that QEP, and other producer defendants, sold Bakken crude oil to third-party purchasers in North Dakota, who resold the oil and transported it on the derailed train. Plaintiffs alleged that QEP and the producer defendants, among other things, failed to ensure that the oil was adequately processed to remove volatile gases and vapors, knowingly added volatile light end petroleum liquids and/or vapors or blended the crude with condensate, failed to conduct adequate well site testing to determine the proper hazard classification of the oil, failed to properly classify the shipping requirements for the oil, failed to take reasonable care to ensure that the oil was properly labeled and shipped, failed to identify the risk of the train derailment and take action to prevent it, and failed to adopt, implement and enforce rules and procedures pertaining to the safe shipment of the oil. The plaintiffs seek damages, but specific monetary damages are not asserted. Class certification hearings took place in June 2014, and a court order regarding class certification is pending. Many of the defendants, including QEP, and their insurers have reached an agreement with Trustees in both Canadian and U.S. Bankruptcy Courts to resolve all of these claims. The terms of the agreement are confidential and are contingent upon the approval of the courts.

ShareBased_Compensation

Share-Based Compensation	3 Months Ended
	Mar. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Disclosure of Compensation Related Costs, Share-based Payments [Text Block]	Share-Based Compensation
	QEP issues stock options and restricted shares under its Long-Term Stock Incentive Plan (LTSIP) and awards performance share units under its Cash Incentive Plan (CIP) to certain officers, employees, and non-employee directors. QEP recognizes expense over the vesting periods for the stock options, restricted shares, and performance share units. Deferred share-based compensation is included in additional paid-in capital in the Condensed Consolidated Balance Sheets. There were 9.2 million shares available for future grants under the LTSIP at March 31, 2015. Share-based compensation expense related to continuing operations is recognized in “General and administrative” on the Condensed Consolidated Statements of Operations, and expenses related to discontinued operations (including compensation expense related to the QEP Midstream's Long Term Incentive Plan) are reflected in "Net income from discontinued operations, net of income tax". During the three months ended March 31, 2015, QEP recognized $9.1 million in total compensation expense related to share-based compensation for continuing operations, compared to $6.4 million during the three months ended March 31, 2014. During the three months ended March 31, 2014, QEP recognized $1.1 million in total compensation expense related to share-based compensation for discontinued operations.
	Stock Options
	QEP uses the Black-Scholes-Merton mathematical model to estimate the fair value of stock option awards at the date of the grant. Fair-value calculations rely upon subjective assumptions used in the mathematical model and may not be representative of future results. The Black-Scholes-Merton model is intended for measuring the value of options traded on an exchange. The Company utilizes the "simplified" method to estimate the expected term of the stock options granted as there is limited historical exercise data available in estimating the expected term of the stock options. QEP uses a historical volatility method to estimate the fair value of stock options awards and the risk-free interest rate is based on the yield on U.S. Treasury strips with maturities similar to those of the expected term of the stock options. The stock options typically vest in equal installments over a three-year period from the grant date and are exercisable immediately upon vesting through the seventh anniversary of the grant date. To fulfill options exercised, QEP either reissues treasury stock or issues new shares.
	The calculated fair value of options granted and major assumptions used in the model at the date of grant are listed below for the three months ended March 31, 2015:
		Stock Option Assumptions
	Weighted-average grant-date fair value of awards granted during the period	$	6.82
	Weighted-average risk-free interest rate	1.38		%
	Weighted-average expected price volatility	36.8		%
	Expected dividend yield	0.37		%
	Expected term in years at the date of grant	4.5
	Stock option transactions under the terms of the LTSIP are summarized below:
		Options			Weighted-		Weighted-Average	Aggregate
		Outstanding			Average Exercise Price		Remaining	Intrinsic Value
							Contractual Term
					(per share)		(in years)	(in millions)
	Outstanding at December 31, 2014	1,996,215			$	28.6
	Granted	425,877			21.69
	Forfeited	(2,817	)		31.31
	Canceled	(60,000	)		27.84
	Outstanding at March 31, 2015	2,359,275			$	27.37	3.72	$	0.2
	Options Exercisable at March 31, 2015	1,673,563			$	28.24	2.63	$	0.2
	Unvested Options at March 31, 2015	685,712			$	25.23	6.37	$	—
	During the three months ended March 31, 2015, there were no exercises of stock options. The total intrinsic value (the difference between the market price at the exercise date and the exercise price) of options exercised during the three months ended March 31, 2014 was $0.2 million. As of March 31, 2015, $4.0 million of unrecognized compensation cost related to stock options granted under the LTSIP is expected to be recognized over a weighted-average period of 2.57 years.
	Restricted Shares
	Restricted share grants typically vest in equal installments over a three-year period from the grant date. The grant date fair value is determined based on the closing bid price of the Company's common stock on the grant date. The total fair value of restricted stock that vested during the three months ended March 31, 2015 and 2014, was $18.0 million and $15.1 million, respectively. The weighted average grant-date fair value of restricted stock was $21.67 per share and $31.69 per share for the three months ended March 31, 2015 and 2014, respectively. As of March 31, 2015, $39.7 million of unrecognized compensation cost related to restricted shares granted under the LTSIP is expected to be recognized over a weighted-average vesting period of 2.64 years.
	Transactions involving restricted shares under the terms of the LTSIP are summarized below:
		Restricted Shares			Weighted-
		Outstanding			Average Grant-Date Fair Value
					(per share)
	Unvested balance at December 31, 2014	1,426,453			$	31.02
	Granted	1,359,488			21.67
	Vested	(584,111	)		30.88
	Forfeited	(61,144	)		28.48
	Unvested balance at March 31, 2015	2,140,686			$	25.19
	Performance Share Units
	The performance share units' cash payouts are dependent upon the Company’s total shareholder return compared to a group of its peers over a three-year period. The awards are denominated in share units but have historically been delivered in cash at the end of the performance period. Beginning with awards granted in 2015, the Company has the option to settle earned awards in cash or shares of common stock under the Company's LTSIP; however, as of March 31, 2015, the Company expects to settle all awards in cash. The weighted average grant-date fair value of the performance share units was $21.69 per share and $31.69 per share for the three months ended March 31, 2015 and 2014, respectively. As of March 31, 2015, $3.1 million of unrecognized compensation cost, representing the fair market value of performance shares granted, is expected to be recognized over a weighted-average vesting period of 2.29 years.
	Transactions involving performance share units under the terms of the CIP are summarized below:
		Performance Share			Weighted-
		Units Outstanding			Average Grant-Date Fair Value
	Unvested balance at December 31, 2014	552,209			$	30.85
	Granted	234,085			21.69
	Vested and paid out	(131,665	)		30.77
	Canceled (1)	(14,612	)		30.77
	Forfeited	(6,792	)		28.29
	Unvested balance at March 31, 2015	633,225			$	27.52
	____________________________
	(1)	Represents units that were not paid out due to performance under the plan.

Employee_Benefits

Employee Benefits	3 Months Ended
	Mar. 31, 2015
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension and Other Postretirement Benefits Disclosure [Text Block]	Employee Benefits
	The Company maintains the QEP Resources, Inc. Retirement Plan, a closed, defined-benefit pension plan (the Pension Plan) and a postretirement medical plan. The Company's postretirement medical plan is unfunded and provides certain health care and life insurance benefits for certain retired employees. The Pension Plan includes a qualified and a nonqualified retirement plan. The nonqualified retirement plan is the Supplemental Executive Retirement Plan (SERP). During the three months ended March 31, 2015, the Company made contributions of $1.0 million to its funded qualified pension plan. Contributions to funded qualified plans increase plan assets. During the three months ended March 31, 2015, the Company made contributions of $0.4 million to its SERP. Payments to the SERP are used to fund current benefit payments. During the remainder of 2015, the Company expects to contribute $3.0 million to its funded qualified pension plan, $4.0 million to its SERP and $0.3 million for retiree health care and life insurance benefits. During the three months ended March 31, 2015, for continuing operations, QEP recognized $1.7 million in recurring employee benefit expense, compared to $2.0 million during the three months ended March 31, 2014. During the three months ended March 31, 2014, for discontinued operations, QEP recognized $0.5 million in recurring employee benefit expense.
	The following table sets forth the Company’s pension and postretirement benefits net periodic benefit costs:
		Pension
		Three Months Ended
		March 31,
		2015			2014
		(in millions)
	Service cost	$	0.6		$	0.7
	Interest cost	1.3			1.4
	Expected return on plan assets	(1.4		)	(1.2		)
	Amortization of prior service costs (1)	0.8			1.2
	Amortization of actuarial losses (1)	0.3			0.2
	Periodic expense	$	1.6		$	2.3
	____________________________
	(1)	Amortization of prior service costs and actuarial losses out of AOCI are recognized in the Condensed Consolidated Statements of Operations in "General and administrative."
		Postretirement Benefits
		Three Months Ended
		March 31,
		2015			2014
		(in millions)
	Interest cost	$	0.1		$	0.1
	Amortization of prior service costs (1)	—			0.1
	Periodic expense	$	0.1		$	0.2
	____________________________
	(1)	Amortization of prior service costs out of AOCI are recognized in the Condensed Consolidated Statements of Operations in "General and administrative."

Operations_by_Line_of_Business

Operations by Line of Business	3 Months Ended
	Mar. 31, 2015
Segment Reporting [Abstract]
Operations by Line of Business	Operations by Line of Business
	QEP’s lines of business include oil and gas exploration and production (QEP Energy); and oil and gas marketing, operation of the Haynesville Gathering System and an underground storage facility, and corporate (QEP Marketing and Other). The lines of business are managed separately and therefore the financial information is presented separately due to the distinct differences in the nature of operations of each line of business, among other factors.
	Our financial results for the three months ended March 31, 2014, have been revised, in accordance with GAAP, to reflect the impact of the Midstream Sale. See Note 4 - Discontinued Operations for detailed information on the Midstream Sale.
	The following table is a summary of operating results for the three months ended March 31, 2015, by line of business:
		QEP Energy			QEP Marketing			Eliminations			QEP
					and Other						Consolidated
		(in millions)
	REVENUES
	From unaffiliated customers	$	353.3		$	138.3		$	—		$	491.6
	From affiliated customers	—			207.5			(207.5		)	—
	Total Revenues	353.3			345.8			(207.5		)	491.6
	OPERATING EXPENSES
	Purchased gas and oil expense	31.2			342.8			(204.6		)	169.4
	Lease operating expense	61.8			—			—			61.8
	Gas, oil and NGL transportation and other handling costs	67.4			—			(2.3		)	65.1
	Gathering and other expense	—			1.7			—			1.7
	General and administrative	46.2			1.8			(0.6		)	47.4
	Production and property taxes	27.5			0.3			—			27.8
	Depreciation, depletion and amortization	192.7			2.7			—			195.4
	Impairment and exploration expense	21.1			—			—			21.1
	Total Operating Expenses	447.9			349.3			(207.5		)	589.7
	Net gain (loss) from asset sales	(27.8		)	(2.7		)	—			(30.5		)
	OPERATING INCOME (LOSS)	(122.4		)	(6.2		)	—			(128.6		)
	Realized and unrealized gains (losses) on derivative contracts	80.2			0.7			—			80.9
	Interest and other income (expense)	(3.5		)	48			(47.1		)	(2.6		)
	Interest expense	(47.2		)	(36.7		)	47.1			(36.8		)
	INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	(92.9		)	5.8			—			(87.1		)
	Income tax (provision) benefit	33.6			(2.1		)	—			31.5
	NET INCOME (LOSS)	$	(59.3	)	$	3.7		$	—		$	(55.6	)
	The following table is a summary of operating results for the three months ended March 31, 2014, by line of business:
		QEP Energy			QEP Marketing			Eliminations			Discontinued Operations			QEP
					and Other									Consolidated
		(in millions)
	REVENUES
	From unaffiliated customers	$	613.2		$	204.3		$	—		$	—		$	817.5
	From affiliated customers	—			303.5			(303.5		)	—			—
	Total Revenues	613.2			507.8			(303.5		)	—			817.5
	OPERATING EXPENSES
	Purchased gas and oil expense	38			497.9			(298.0		)	—			237.9
	Lease operating expense	56.4			—			—			—			56.4
	Gas, oil and NGL transportation and other handling costs	64.5			—			(4.6		)	—			59.9
	Gathering and other expense	—			1.6			—			—			1.6
	General and administrative	45			1.2			(0.9		)	—			45.3
	Production and property taxes	47.4			0.5			—			—			47.9
	Depreciation, depletion and amortization	223.4			2.5			—			—			225.9
	Impairment and exploration expense	4.2			—			—			—			4.2
	Total Operating Expenses	478.9			503.7			(303.5		)	—			679.1
	Net gain (loss) from assets sales	2.4			—			—			—			2.4
	OPERATING INCOME (LOSS)	136.7			4.1			—			—			140.8
	Realized and unrealized gains (losses) on derivative contracts	(78.5		)	(2.4		)	—			—			(80.9		)
	Interest and other income (expense)	2.9			48.8			(48.8		)	—			2.9
	Interest expense	(48.9		)	(41.8		)	48.8			—			(41.9		)
	INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	12.2			8.7			—			—			20.9
	Income tax (provision) benefit	(7.1		)	(1.1		)	—			—			(8.2		)
	INCOME (LOSS) FROM CONTINUING OPERATIONS	5.1			7.6			—			—			12.7
	Net income from discontinued operations, net of income tax	—			—			—			27			27
	NET INCOME (LOSS)	$	5.1		$	7.6		$	—		$	27		$	39.7
	Identifiable total assets	$	9,004.10		$	225.3		$	—		1,306.20			$	10,535.60

Basis_of_Presentation_of_Inter1

Basis of Presentation of Interim Consolidated Financial Statements (Policies)	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
New accounting pronouncements	New accounting pronouncements
	In February 2015, the Financial Accounting Standards Board (FASB) issued Accounting Standard Update (ASU) No. 2015-02, Consolidation (Topic 810), which amends the current consolidation guidance. The amendments affect both the variable interest entity and voting interest entity consolidation models. The amendments will be effective prospectively for reporting periods beginning on or after December 15, 2015, and early adoption is permitted. The Company is currently assessing the standard update and does not believe there will be a significant impact on the Company's consolidated financial statements.
	In January 2015, the FASB issued ASU No. 2015-01, Income Statement — Extraordinary and Unusual Items (Subtopic 225-20), which eliminates the concept of extraordinary items from GAAP. The amendments will be effective for reporting periods beginning on or after December 15, 2015, and early adoption is permitted. Additionally, a reporting entity also may apply the amendments retrospectively for all periods presented in the financial statements. The Company is currently assessing the standard update and does not believe there will be a significant impact on the Company's consolidated financial statements.

Acquisitions_Divestitures_Tabl

Acquisitions & Divestitures (Tables)	3 Months Ended
	Mar. 31, 2015
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]
Business Combination, Separately Recognized Transactions [Table Text Block]
	Consideration:
	Total consideration	$	941.8
	Amounts recognized for fair value of assets acquired and liabilities assumed:
	Proved properties	$	472.1
	Unproved properties	480.6
	Asset retirement obligations	(9.7		)
	Liabilities assumed	(1.2		)
	Total fair value	$	941.8
Business Acquisition, Pro Forma Information [Table Text Block]
			Three Months Ended
			March 31,
			2014		2014
			Actual		Pro forma
		(in millions, except per share data)
	Revenues		$	817.5	$	843.6
	Net income		$	39.7	$	46.7
	Earnings per common share
	Basic		$	0.22	$	0.26
	Diluted		$	0.22	$	0.26

Discontinued_Operations_Tables

Discontinued Operations (Tables)	3 Months Ended
	Mar. 31, 2015
Discontinued Operations and Disposal Groups [Abstract]
Income Statement Impact Of Discontinued Operations [Table Text Block]
		Three Months Ended
		March 31,
		2014
	REVENUES
	NGL sales	$	38
	Other revenue	41.9
	Purchased gas and oil sales(1)	(13.4		)
	Total Revenues	66.5
	OPERATING EXPENSES
	Purchased gas and oil expense(1)	(13.8		)
	Lease operating expense(1)	(1.1		)
	Natural gas, oil and NGL transport and other handling costs(1)	(16.4		)
	Gathering, processing, and other	24.3
	General and administrative	11.3
	Production and property taxes	1.5
	Depreciation, depletion and amortization	14.3
	Total Operating Expenses	20.1
	OPERATING INCOME	46.4
	Income from unconsolidated affiliates	2.2
	Interest expense	(0.6		)
	INCOME FROM DISCONTINUED OPERATIONS BEFORE INCOME TAXES (2)	48
	Income taxes	(15.2		)
	NET INCOME FROM DISCONTINUED OPERATIONS	32.8
	Net income attributable to noncontrolling interest	(5.8		)
	NET INCOME FROM DISCONTINUED OPERATIONS, NET OF INCOME TAX	$	27

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	3 Months Ended
	Mar. 31, 2015
Earnings Per Share [Abstract]
Components of basic and diluted shares used in EPS	A reconciliation of the components of basic and diluted shares used in the EPS calculation follows:
		Three Months Ended
		March 31,
		2015	2014
		(in millions)
	Weighted-average basic common shares outstanding	176.2	179.7
	Potential number of shares issuable upon exercise of in-the-money stock options under the Long-term Stock Incentive Plan	—	0.3
	Average diluted common shares outstanding	176.2	180

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation [Abstract]
Asset retirement obligations roll forward
		Asset Retirement Obligations
		2015
		(in millions)
	ARO liability at January 1,	$	195.1
	Accretion	2.1
	Additions	0.6
	Liabilities settled	(0.6		)
	ARO liability at March 31,	$	197.2

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Fair value of financial assets and liabilities	The fair value of financial assets and liabilities at March 31, 2015 and December 31, 2014, is shown in the table below:
		Fair Value Measurements
		Gross Amounts of Assets and Liabilities						Netting			Net Amounts Presented on the Condensed Consolidated Balance Sheets
		Level 1		Level 2		Level 3		Adjustments(1)
		(in millions)
		31-Mar-15
	Financial Assets
	Commodity derivative instruments - short-term	$	—	$	312.5	$	—	$	(0.8	)	$	311.7
	Commodity derivative instruments - long-term	—		13.7		—		—			13.7
	Total financial assets	$	—	$	326.2	$	—	$	(0.8	)	$	325.4
	Financial Liabilities
	Commodity derivative instruments - short-term	$	—	$	0.8	$	—	$	(0.8	)	$	—
	Total financial liabilities	$	—	$	0.8	$	—	$	(0.8	)	$	—
		31-Dec-14
	Financial Assets
	Commodity derivative instruments - short-term	$	—	$	339.3	$	—	$	(0.3	)	$	339
	Commodity derivative instruments - long-term	—		9.9		—		—			9.9
	Total financial assets	$	—	$	349.2	$	—	$	(0.3	)	$	348.9
	Financial Liabilities
	Commodity derivative instruments - short-term	$	—	$	0.3	$	—	$	(0.3	)	$	—
	Total financial liabilities	$	—	$	0.3	$	—	$	(0.3	)	$	—
Fair value and related carrying amount of certain financial instruments	The following table discloses the fair value and related carrying amount of certain financial instruments not disclosed in other Notes accompanying the Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q:
		Carrying		Level 1		Carrying		Level 1
		Amount		Fair Value		Amount		Fair Value
		March 31, 2015				December 31, 2014
		(in millions)
	Financial assets
	Cash and cash equivalents	$	500.4	$	500.4	$	1,160.10	$	1,160.10
	Financial liabilities
	Checks outstanding in excess of cash balances	$	15.8	$	15.8	$	54.7	$	54.7
	Long-term debt	$	2,218.30	$	2,248.50	$	2,218.10	$	2,171.60

Derivative_Contracts_Tables

Derivative Contracts (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block]	The following table sets forth QEP Energy’s quantities and average prices for its commodity derivative contracts as of March 31, 2015:
	Year		Type of Contract		Index	Total			Average Swap price per unit
						Volumes
						(in millions)
	Gas sales					(MMBtu)
	2015		SWAP		NYMEX HH	52.3			$	3.48
	2015		SWAP		IFNPCR	35.8			$	3.55
	2016		SWAP		NYMEX HH	14.6			$	3.29
	2016		SWAP		IFNPCR	11			$	2.97
	Oil sales					(bbls)
	2015		SWAP		NYMEX WTI	6.6			$	85.89
	2015		SWAP		ICE Brent	0.3			$	104.95
	2016		SWAP		NYMEX WTI	1.1			$	70.85
	The following table sets forth QEP Energy's crude oil collars as of March 31, 2015:
					Total Volume		Average Price				Average Price
	Year		Index				Floor				Ceiling
					(in millions)		($/bbl)				($/bbl)
					(bbls)
	2015		NYMEX WTI		0.3		$	50			$	64.35
	The following table sets forth QEP Energy's gas basis swaps as of March 31, 2015:
	Year		Index		Index Less Differential	Total Volumes			Weighted Average Differential
						(in millions)			($/MMBtu)
	Gas basis swaps					(MMBtu)
	2015		NYMEX HH		IFNPCR	27.5			$	(0.30	)
	QEP Marketing Derivative Contracts
	QEP Marketing enters into commodity derivative transactions to lock in a margin on gas volumes placed into storage and for marketing transactions in which QEP Marketing sells gas volumes at a fixed price. The following table sets forth QEP Marketing’s volumes and swap prices for its commodity derivative contracts as of March 31, 2015:
	Year		Type of Contract		Index	Total			Average Swap price
						Volumes			per MMBtu
						(in millions)
	Gas sales					(MMBtu)
	2015		SWAP		IFNPCR	1.7			$	3.29
	2016		SWAP		IFNPCR	1.4			$	3.34
	Gas purchases					(MMBtu)
	2015		SWAP		IFNPCR	1.3			$	2.88
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]
				Gross asset derivative							Gross liability derivative
				instruments fair value							instruments fair value
		Balance Sheet		March 31,			31-Dec-14				March 31,		31-Dec-14
		line item		2015							2015
				(in millions)
	Current:
	Commodity	Fair value of derivative contracts		$	312.5		$	339.3			$	0.8	$	0.3
	Long-term:
	Commodity	Fair value of derivative contracts		13.7			9.9				—		—
	Total derivative instruments			$	326.2		$	349.2			$	0.8	$	0.3
Derivative Instruments, Gain (Loss) [Table Text Block]
			Three Months Ended
	Derivative instruments not designated as cash flow hedges		March 31,
			2015			2014
	Realized gains (losses) on commodity derivative contracts		(in millions)
	QEP Energy
	Gas derivative contracts		$	17.9		$	(20.4	)
	Oil derivative contracts		84			(12.9		)
	QEP Marketing
	Gas derivative contracts		2.5			(1.4		)
	Total realized gains (losses) on commodity derivative contracts		104.4			(34.7		)
	Unrealized gains (losses) on commodity derivative contracts
	QEP Energy
	Gas derivative contracts		11.4			(24.3		)
	Oil derivative contracts		(33.1		)	(20.9		)
	QEP Marketing
	Gas derivative contracts		(1.8		)	(0.3		)
	Total unrealized gains (losses) on commodity derivative contracts		(23.5		)	(45.5		)
	Total realized and unrealized gains (losses) on commodity derivative contracts		$	80.9		$	(80.2	)
	Realized gains (losses) on interest rate swaps
	Realized losses on interest rate swaps		$	—		$	(0.7	)
	Total realized gains (losses) on interest rate swaps		$	—		$	(0.7	)
	Total net realized gains (losses) on derivative contracts		$	104.4		$	(35.4	)
	Total net unrealized gains (losses) on derivative contracts		(23.5		)	(45.5		)
	Grand Total		$	80.9		$	(80.9	)

Debt_Tables

Debt (Tables)	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Debt Outstanding	As of the indicated dates, the principal amount of QEP’s debt, including amounts outstanding under QEP's revolving credit facility and senior notes, consisted of the following:
		March 31,			December 31,
		2015			2014
		(in millions)
	Revolving Credit Facility due 2019	$	—		$	—
	6.05% Senior Notes due 2016	176.8			176.8
	6.80% Senior Notes due 2018	134			134
	6.80% Senior Notes due 2020	136			136
	6.875% Senior Notes due 2021	625			625
	5.375% Senior Notes due 2022	500			500
	5.25% Senior Notes due 2023	650			650
	Total principal amount of debt	2,221.80			2,221.80
	Less unamortized discount	(3.5		)	(3.7		)
	Total long-term debt outstanding	$	2,218.30		$	2,218.10

ShareBased_Compensation_Tables

Share-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions [Table Text Block]	The calculated fair value of options granted and major assumptions used in the model at the date of grant are listed below for the three months ended March 31, 2015:
		Stock Option Assumptions
	Weighted-average grant-date fair value of awards granted during the period	$	6.82
	Weighted-average risk-free interest rate	1.38		%
	Weighted-average expected price volatility	36.8		%
	Expected dividend yield	0.37		%
	Expected term in years at the date of grant	4.5
Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]	Stock option transactions under the terms of the LTSIP are summarized below:
		Options			Weighted-		Weighted-Average	Aggregate
		Outstanding			Average Exercise Price		Remaining	Intrinsic Value
							Contractual Term
					(per share)		(in years)	(in millions)
	Outstanding at December 31, 2014	1,996,215			$	28.6
	Granted	425,877			21.69
	Forfeited	(2,817	)		31.31
	Canceled	(60,000	)		27.84
	Outstanding at March 31, 2015	2,359,275			$	27.37	3.72	$	0.2
	Options Exercisable at March 31, 2015	1,673,563			$	28.24	2.63	$	0.2
	Unvested Options at March 31, 2015	685,712			$	25.23	6.37	$	—
Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block]	Transactions involving restricted shares under the terms of the LTSIP are summarized below:
		Restricted Shares			Weighted-
		Outstanding			Average Grant-Date Fair Value
					(per share)
	Unvested balance at December 31, 2014	1,426,453			$	31.02
	Granted	1,359,488			21.67
	Vested	(584,111	)		30.88
	Forfeited	(61,144	)		28.48
	Unvested balance at March 31, 2015	2,140,686			$	25.19
	Performance Share Units
	The performance share units' cash payouts are dependent upon the Company’s total shareholder return compared to a group of its peers over a three-year period. The awards are denominated in share units but have historically been delivered in cash at the end of the performance period. Beginning with awards granted in 2015, the Company has the option to settle earned awards in cash or shares of common stock under the Company's LTSIP; however, as of March 31, 2015, the Company expects to settle all awards in cash. The weighted average grant-date fair value of the performance share units was $21.69 per share and $31.69 per share for the three months ended March 31, 2015 and 2014, respectively. As of March 31, 2015, $3.1 million of unrecognized compensation cost, representing the fair market value of performance shares granted, is expected to be recognized over a weighted-average vesting period of 2.29 years.
	Transactions involving performance share units under the terms of the CIP are summarized below:
		Performance Share			Weighted-
		Units Outstanding			Average Grant-Date Fair Value
	Unvested balance at December 31, 2014	552,209			$	30.85
	Granted	234,085			21.69
	Vested and paid out	(131,665	)		30.77
	Canceled (1)	(14,612	)		30.77
	Forfeited	(6,792	)		28.29
	Unvested balance at March 31, 2015	633,225			$	27.52

Employee_Benefits_Tables

Employee Benefits (Tables)	3 Months Ended
	Mar. 31, 2015
Compensation and Retirement Disclosure [Abstract]
Schedule of Net Benefit Costs [Table Text Block]
		Pension
		Three Months Ended
		March 31,
		2015			2014
		(in millions)
	Service cost	$	0.6		$	0.7
	Interest cost	1.3			1.4
	Expected return on plan assets	(1.4		)	(1.2		)
	Amortization of prior service costs (1)	0.8			1.2
	Amortization of actuarial losses (1)	0.3			0.2
	Periodic expense	$	1.6		$	2.3
	____________________________
	(1)	Amortization of prior service costs and actuarial losses out of AOCI are recognized in the Condensed Consolidated Statements of Operations in "General and administrative."
		Postretirement Benefits
		Three Months Ended
		March 31,
		2015			2014
		(in millions)
	Interest cost	$	0.1		$	0.1
	Amortization of prior service costs (1)	—			0.1
	Periodic expense	$	0.1		$	0.2
	____________________________
	(1)	Amortization of prior service costs out of AOCI are recognized in the Condensed Consolidated Statements of Operations in "General and administrative."

Operations_by_Line_of_Business1

Operations by Line of Business (Tables)	3 Months Ended
	Mar. 31, 2015
Segment Reporting [Abstract]
Summary of operating results by line of business	Operations by Line of Business
	QEP’s lines of business include oil and gas exploration and production (QEP Energy); and oil and gas marketing, operation of the Haynesville Gathering System and an underground storage facility, and corporate (QEP Marketing and Other). The lines of business are managed separately and therefore the financial information is presented separately due to the distinct differences in the nature of operations of each line of business, among other factors.
	Our financial results for the three months ended March 31, 2014, have been revised, in accordance with GAAP, to reflect the impact of the Midstream Sale. See Note 4 - Discontinued Operations for detailed information on the Midstream Sale.
	The following table is a summary of operating results for the three months ended March 31, 2015, by line of business:
		QEP Energy			QEP Marketing			Eliminations			QEP
					and Other						Consolidated
		(in millions)
	REVENUES
	From unaffiliated customers	$	353.3		$	138.3		$	—		$	491.6
	From affiliated customers	—			207.5			(207.5		)	—
	Total Revenues	353.3			345.8			(207.5		)	491.6
	OPERATING EXPENSES
	Purchased gas and oil expense	31.2			342.8			(204.6		)	169.4
	Lease operating expense	61.8			—			—			61.8
	Gas, oil and NGL transportation and other handling costs	67.4			—			(2.3		)	65.1
	Gathering and other expense	—			1.7			—			1.7
	General and administrative	46.2			1.8			(0.6		)	47.4
	Production and property taxes	27.5			0.3			—			27.8
	Depreciation, depletion and amortization	192.7			2.7			—			195.4
	Impairment and exploration expense	21.1			—			—			21.1
	Total Operating Expenses	447.9			349.3			(207.5		)	589.7
	Net gain (loss) from asset sales	(27.8		)	(2.7		)	—			(30.5		)
	OPERATING INCOME (LOSS)	(122.4		)	(6.2		)	—			(128.6		)
	Realized and unrealized gains (losses) on derivative contracts	80.2			0.7			—			80.9
	Interest and other income (expense)	(3.5		)	48			(47.1		)	(2.6		)
	Interest expense	(47.2		)	(36.7		)	47.1			(36.8		)
	INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	(92.9		)	5.8			—			(87.1		)
	Income tax (provision) benefit	33.6			(2.1		)	—			31.5
	NET INCOME (LOSS)	$	(59.3	)	$	3.7		$	—		$	(55.6	)
	The following table is a summary of operating results for the three months ended March 31, 2014, by line of business:
		QEP Energy			QEP Marketing			Eliminations			Discontinued Operations			QEP
					and Other									Consolidated
		(in millions)
	REVENUES
	From unaffiliated customers	$	613.2		$	204.3		$	—		$	—		$	817.5
	From affiliated customers	—			303.5			(303.5		)	—			—
	Total Revenues	613.2			507.8			(303.5		)	—			817.5
	OPERATING EXPENSES
	Purchased gas and oil expense	38			497.9			(298.0		)	—			237.9
	Lease operating expense	56.4			—			—			—			56.4
	Gas, oil and NGL transportation and other handling costs	64.5			—			(4.6		)	—			59.9
	Gathering and other expense	—			1.6			—			—			1.6
	General and administrative	45			1.2			(0.9		)	—			45.3
	Production and property taxes	47.4			0.5			—			—			47.9
	Depreciation, depletion and amortization	223.4			2.5			—			—			225.9
	Impairment and exploration expense	4.2			—			—			—			4.2
	Total Operating Expenses	478.9			503.7			(303.5		)	—			679.1
	Net gain (loss) from assets sales	2.4			—			—			—			2.4
	OPERATING INCOME (LOSS)	136.7			4.1			—			—			140.8
	Realized and unrealized gains (losses) on derivative contracts	(78.5		)	(2.4		)	—			—			(80.9		)
	Interest and other income (expense)	2.9			48.8			(48.8		)	—			2.9
	Interest expense	(48.9		)	(41.8		)	48.8			—			(41.9		)
	INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	12.2			8.7			—			—			20.9
	Income tax (provision) benefit	(7.1		)	(1.1		)	—			—			(8.2		)
	INCOME (LOSS) FROM CONTINUING OPERATIONS	5.1			7.6			—			—			12.7
	Net income from discontinued operations, net of income tax	—			—			—			27			27
	NET INCOME (LOSS)	$	5.1		$	7.6		$	—		$	27		$	39.7
	Identifiable total assets	$	9,004.10		$	225.3		$	—		1,306.20			$	10,535.60

Acquisitions_Divestitures_Narr

Acquisitions & Divestitures (Narrative) (Details) (USD $)	1 Months Ended	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2015	Dec. 31, 2014
			acre
Business Acquisition [Line Items]
Payments to Acquire Businesses Net			$941.80
Net acres of producing and undeveloped oil and gas properties			26,500
Number of vertical producing wells			270
Escrow Deposit			50
Business Combination, Pro Forma Information, Revenue of Acquiree since Acquisition Date, Actual	14.9	29.5
Business Combination, Pro Forma Information, Earnings or Loss of Acquiree since Acquisition Date, Actual	3.7	-1.5
Term Loan due 2017 [Member]
Business Acquisition [Line Items]
Borrowings to Fund Acquisition			300
Midcontinent Divestitures [Member]
Business Acquisition [Line Items]
Gain (Loss) on Disposition of Oil and Gas and Timber Property		-26.8	-199.4
Proceeds from Sale of Property, Plant, and Equipment			692.9
Southern Region Divestitures [Member]
Business Acquisition [Line Items]
Gain (Loss) on Disposition of Oil and Gas and Timber Property		-1.8	53.3
Proceeds from Sale of Property, Plant, and Equipment			96.3
Permian Basin [Member]
Business Acquisition [Line Items]
Payments to Acquire Businesses, Gross			$941.80

Acquisitions_Divestitures_Sche

Acquisitions & Divestitures (Schedule Of Purchase Accounting Entries) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Significant Acquisitions and Disposals [Line Items]
Payments to Acquire Businesses Net	$941.80
Fair value of assets acquired (liabilities assumed)	941.8
Proved Property [Member]
Significant Acquisitions and Disposals [Line Items]
Fair value of assets acquired (liabilities assumed)	472.1
Unproved Property [Member]
Significant Acquisitions and Disposals [Line Items]
Fair value of assets acquired (liabilities assumed)	480.6
Asset Retirement Obligation [Member]
Significant Acquisitions and Disposals [Line Items]
Fair value of assets acquired (liabilities assumed)	-9.7
Other Liabilities [Member]
Significant Acquisitions and Disposals [Line Items]
Fair value of assets acquired (liabilities assumed)	-1.2
Permian Basin [Member]
Significant Acquisitions and Disposals [Line Items]
Payments to Acquire Businesses, Gross	$941.80

Acquisitions_Divestitures_Supp

Acquisitions & Divestitures Supplemental Proforma Results of Operations (Details) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Business Acquisition [Line Items]
Total Revenues	$491.60	$817.50
Net income	-55.6	39.7
Earnings Per Share, Basic	($0.32)	$0.22
Earnings Per Share, Diluted	($0.32)	$0.22
Business Acquisition, Pro Forma Revenue		843.6
Business Acquisition, Pro Forma Net Income (Loss)		$46.70
Business Acquisition, Pro Forma Earnings Per Share, Basic		$0.26
Business Acquisition, Pro Forma Earnings Per Share, Diluted		$0.26

Discontinued_Operations_Narrat

Discontinued Operations (Narrative) (Details) (USD $)	3 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Value of midstream business sold			$2,500
Debt Refinanced In Business Sale			230
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax			1,800
Discontinued Operation, Amount of Continuing Cash Flows after Disposal	22.7	34.9
Depreciation, depletion and amortization	195.4	225.9
Employee Retention Bonus Cost			10.4
Discontinued Operations [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Depreciation, depletion and amortization		14.3
Payments to Acquire Oil and Gas Property and Equipment		12.7
Employee Retention Bonus Cost		$2.30

Discontinued_Operations_Income

Discontinued Operations - Income Statement Impact of Discontinued Operations (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
NGL sales	$19.10	$63.20
Other revenue	4.4	2.5
Purchased gas and oil sales	167.3	240.6
Total Revenues	491.6	817.5
Purchased gas and oil expense	169.4	237.9
Lease operating expense	61.8	56.4
Natural gas, oil and NGL transportation and other handling costs	65.1	59.9
Gathering, processing and other	1.7	1.6
General and administrative	47.4	45.3
Production and property taxes	27.8	47.9
Depreciation, depletion and amortization	195.4	225.9
Total operating expenses	589.7	679.1
OPERATING INCOME	-128.6	140.8
Income from unconsolidated affiliates	0	2.2
Interest expense	-36.8	-41.9
Net income attributable to noncontrolling interest	0	-5.8
NET INCOME FROM DISCONTINUED OPERATIONS, NET OF INCOME TAX	0	27
Discontinued Operations [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
NGL sales		38
Other revenue		41.9
Purchased gas and oil sales		-13.4	[1]
Total Revenues		66.5
Purchased gas and oil expense		-13.8	[1]
Lease operating expense		-1.1	[1]
Natural gas, oil and NGL transportation and other handling costs		-16.4	[1]
Gathering, processing and other		24.3
General and administrative		11.3
Production and property taxes		1.5
Depreciation, depletion and amortization		14.3
Total operating expenses		20.1
OPERATING INCOME		46.4
Income from unconsolidated affiliates		2.2
Interest expense		-0.6
INCOME FROM DISCONTINUED OPERATIONS BEFORE INCOME TAXES		48	[2]
Income taxes		-15.2
NET INCOME FROM DISCONTINUED OPERATIONS		32.8
Net income attributable to noncontrolling interest		-5.8
NET INCOME FROM DISCONTINUED OPERATIONS, NET OF INCOME TAX		27
Income from discontinued operations before income taxes attributable to QEP from QEP Midstream		$6.80
Ownership percentage		57.80%
[1]	Includes discontinued intercompany eliminations
[2]	Includes income from discontinued operations before income taxes attributable to QEP from QEP Midstream (of which QEP owned 57.8%) of $6.8 million for the three months ended MarchB 31, 2014

Earnings_Per_Share_Details

Earnings Per Share (Details)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Earnings Per Share [Abstract]
Weighted-average basic common shares outstanding (in shares)	176.2	179.7
Potential number of shares issuable upon excerise of in-the-money stock options under the Long-term Stock Incentive Plan	0	0.3
Average diluted common shares outstanding (in shares)	176.2	180

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation, Current	$0.90	$1.30
ARO Liability [Roll Forward]
ARO liability, Beginning Balance	195.1
Accretion	2.1
Additions	0.6
Liabilities settled	-0.6
ARO liability, Ending Balance	$197.20

Fair_Value_Measurements_Fair_V

Fair Value Measurements - Fair Value of Financial Assets and Liabilities (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Millions, unless otherwise specified
Financial Assets
Derivative Asset, Fair Value, Gross	$326.20		$349.20
Financial liabilities
Derivative Liability, Fair Value, Gross	0.8		0.3
Fair Value, Measurements, Recurring [Member]
Financial Assets
Net amount of derivative assets presented on condensed consolidated balance sheets	325.4		348.9
Financial liabilities
Net amount of derivative liabilities presented on condensed consolidated balance sheets	0		0
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Financial Assets
Derivative Asset, Fair Value, Gross	0		0
Financial liabilities
Derivative Liability, Fair Value, Gross	0		0
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Financial Assets
Derivative Asset, Fair Value, Gross	326.2		349.2
Financial liabilities
Derivative Liability, Fair Value, Gross	0.8		0.3
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Financial Assets
Derivative Asset, Fair Value, Gross	0		0
Financial liabilities
Derivative Liability, Fair Value, Gross	0		0
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member]
Financial Assets
Derivative Asset, Fair Value, Gross	-0.8	[1]	-0.3	[1]
Financial liabilities
Derivative Liability, Fair Value, Gross	-0.8	[1]	-0.3	[1]
Long-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member]
Financial Assets
Net amount of derivative assets presented on condensed consolidated balance sheets	13.7		9.9
Long-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Financial Assets
Derivative Asset, Fair Value, Gross	0		0
Long-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Financial Assets
Derivative Asset, Fair Value, Gross	13.7		9.9
Financial liabilities
Derivative Liability, Fair Value, Gross	0		0
Long-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Financial Assets
Derivative Asset, Fair Value, Gross	0		0
Long-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member]
Financial Assets
Derivative Asset, Fair Value, Gross	0	[1]	0	[1]
Short-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member]
Financial Assets
Net amount of derivative assets presented on condensed consolidated balance sheets	311.7		339
Financial liabilities
Net amount of derivative liabilities presented on condensed consolidated balance sheets	0		0
Short-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Financial Assets
Derivative Asset, Fair Value, Gross	0		0
Financial liabilities
Derivative Liability, Fair Value, Gross	0		0
Short-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Financial Assets
Derivative Asset, Fair Value, Gross	312.5		339.3
Financial liabilities
Derivative Liability, Fair Value, Gross	0.8		0.3
Short-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Financial Assets
Derivative Asset, Fair Value, Gross	0		0
Financial liabilities
Derivative Liability, Fair Value, Gross	0		0
Short-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member]
Financial Assets
Derivative Asset, Fair Value, Gross	-0.8	[1]	-0.3	[1]
Financial liabilities
Derivative Liability, Fair Value, Gross	($0.80)	[1]	($0.30)	[1]
[1]	The Company nets its derivative contract assets and liabilities outstanding with the same counterparty on the Condensed Consolidated Balance Sheets, as the contracts contain netting provisions. Refer to Note 8 - Derivative Contracts, for additional information regarding the Company's derivative contracts.

Fair_Value_Measurements_Fair_V1

Fair Value Measurements Fair Value Measurements - Fair Value and Related Carrying Amount of Certain Financial Instruments (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and Cash Equivalents, at Carrying Value	$500.40	$1,160.10	$3.90	$11.90
Checks outstanding in excess of cash balances	15.8	54.7
Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	2,248.50	2,171.60
Cash and Cash Equivalents, at Carrying Value	500.4	1,160.10
Checks outstanding in excess of cash balances	15.8	54.7
Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt, Fair Value	2,218.30	2,218.10
Cash and Cash Equivalents, at Carrying Value	500.4	1,160.10
Checks outstanding in excess of cash balances	$15.80	$54.70

Derivative_Contracts_Narrative

Derivative Contracts (Narrative) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2014
Derivative [Line Items]
Maximum Forecasted Production Covered By Derivatives	100.00%
Term Loan due 2017 [Member]
Derivative [Line Items]
Line of Credit Maximum Borrowing Capacity		$600
First Term Loan Tranche [Member] | Interest Rate Swap [Member]
Derivative [Line Items]
Derivative Liability, Notional Amount			300
Derivative, Fixed Interest Rate			1.07%
Second Term Loan Tranche [Member] | Interest Rate Swap [Member]
Derivative [Line Items]
Derivative Liability, Notional Amount				$300
Derivative, Fixed Interest Rate				0.86%

Derivative_Contracts_Schedule_

Derivative Contracts Schedule Of Commodity Derivative Contracts (Details) (USD $)	3 Months Ended
	Mar. 31, 2015
	MMBTU
Natural Gas Sales [Member] | QEP Energy [Member] | Year 2015 [Member] | NYMEX HH [Member]
Derivative [Line Items]
Derivative Contract Year	2015
Derivative, Underlying Basis	NYMEX HH
Derivative, Nonmonetary Notional Amount	52,300,000
Underlying, Derivative Asset	3.48
Natural Gas Sales [Member] | QEP Energy [Member] | Year 2015 [Member] | IFNPCR [Member]
Derivative [Line Items]
Derivative Contract Year	2015
Derivative, Underlying Basis	IFNPCR
Derivative, Nonmonetary Notional Amount	35,800,000
Underlying, Derivative Asset	3.55
Natural Gas Sales [Member] | QEP Energy [Member] | Year 2016 [Member] | NYMEX HH [Member]
Derivative [Line Items]
Derivative Contract Year	2016
Derivative, Underlying Basis	NYMEX HH
Derivative, Nonmonetary Notional Amount	14,600,000
Underlying, Derivative Asset	3.29
Natural Gas Sales [Member] | QEP Energy [Member] | Year 2016 [Member] | IFNPCR [Member]
Derivative [Line Items]
Derivative Contract Year	2016
Derivative, Underlying Basis	IFNPCR
Derivative, Nonmonetary Notional Amount	11,000,000
Underlying, Derivative Asset	2.97
Natural Gas Sales [Member] | QEP Marketing [Member] | Year 2015 [Member] | IFNPCR [Member]
Derivative [Line Items]
Derivative Contract Year	2015
Derivative, Underlying Basis	IFNPCR
Derivative, Nonmonetary Notional Amount	1,700,000
Underlying, Derivative Asset	3.29
Natural Gas Sales [Member] | QEP Marketing [Member] | Year 2016 [Member] | IFNPCR [Member]
Derivative [Line Items]
Derivative Contract Year	2016
Derivative, Underlying Basis	IFNPCR
Derivative, Nonmonetary Notional Amount	1,400,000
Underlying, Derivative Asset	3.34
Purchased Gas and Oil Expense [Member] | QEP Marketing [Member] | Year 2015 [Member] | IFNPCR [Member]
Derivative [Line Items]
Derivative Contract Year	2015
Derivative, Underlying Basis	IFNPCR
Derivative, Nonmonetary Notional Amount	1,300,000
Underlying, Derivative Asset	2.88
Crude Oil Sales Costless Collars [Member] | QEP Energy [Member] | Year 2015 [Member] | NYMEX WTI [Member]
Derivative [Line Items]
Derivative Contract Year	2015
Derivative, Underlying Basis	NYMEX WTI
Derivative, Nonmonetary Notional Amount	300,000
Derivative Average Price Floor	$50
Derivative Average Price Ceiling	$64.35
Oil Sales [Member] | QEP Energy [Member] | Year 2015 [Member] | NYMEX WTI [Member]
Derivative [Line Items]
Derivative Contract Year	2015
Derivative, Underlying Basis	NYMEX WTI
Derivative, Nonmonetary Notional Amount	6,600,000
Underlying, Derivative Asset	85.89
Oil Sales [Member] | QEP Energy [Member] | Year 2015 [Member] | BRENT ICE [Member]
Derivative [Line Items]
Derivative Contract Year	2015
Derivative, Underlying Basis	ICE Brent
Derivative, Nonmonetary Notional Amount	300,000
Underlying, Derivative Asset	104.95
Oil Sales [Member] | QEP Energy [Member] | Year 2016 [Member] | NYMEX WTI [Member]
Derivative [Line Items]
Derivative Contract Year	2016
Derivative, Underlying Basis	NYMEX WTI
Derivative, Nonmonetary Notional Amount	1,100,000
Underlying, Derivative Asset	70.85
Gas Basis Swaps [Member] | QEP Energy [Member] | Year 2015 [Member] | NYMEX HH LESS IFNPCR [Member]
Derivative [Line Items]
Derivative Contract Year	2015
Derivative, Underlying Basis	IFNPCR
Derivative, Nonmonetary Notional Amount	27,500,000
Underlying, Derivative Asset	-0.3

Derivative_Contracts_Schedule_1

Derivative Contracts Schedule of Derivatives Financial Statement Presentation (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset	$326.20	$349.20
Derivative Liability, Fair Value, Gross	0.8	0.3
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset	326.2	349.2
Derivative Liability, Fair Value, Gross	0.8	0.3
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Contract [Member] | Short-term [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset	312.5	339.3
Derivative Liability, Fair Value, Gross	0.8	0.3
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Contract [Member] | Long-term [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset	13.7	9.9
Derivative Liability, Fair Value, Gross	$0	$0

Derivative_Contracts_Gain_Loss

Derivative Contracts Gain (Loss) in Statement of Financial Performance (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Derivative [Line Items]
Realized gain (loss) derivative contracts not designated as hedging instruments	$104.40	($35.40)
Unrealized gain (loss) derivative contracts not designated as hedging instruments	-23.5	-45.5
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	80.9	-80.9
Realized and unrealized gains on commodity derivative instruments [Member]
Derivative [Line Items]
Realized gain (loss) on commodity derivative contracts not designated as hedging instruments	104.4	-34.7
Unrealized gain (loss) on commodity derivative contracts not designated as hedging instruments	-23.5	-45.5
Realized and Unrealized Gain (Loss) on Commodity Derivative Contracts Not Designated as Hedging Instruments	80.9	-80.2
Natural gas derivative contracts [Member] | Realized and unrealized gains on commodity derivative instruments [Member] | QEP Energy [Member]
Derivative [Line Items]
Realized gain (loss) on commodity derivative contracts not designated as hedging instruments	17.9	-20.4
Unrealized gain (loss) on commodity derivative contracts not designated as hedging instruments	11.4	-24.3
Natural gas derivative contracts [Member] | Realized and unrealized gains on commodity derivative instruments [Member] | QEP Marketing [Member]
Derivative [Line Items]
Realized gain (loss) on commodity derivative contracts not designated as hedging instruments	2.5	-1.4
Unrealized gain (loss) on commodity derivative contracts not designated as hedging instruments	-1.8	-0.3
Oil derivative contracts [Member] | Realized and unrealized gains on commodity derivative instruments [Member] | QEP Energy [Member]
Derivative [Line Items]
Realized gain (loss) on commodity derivative contracts not designated as hedging instruments	84	-12.9
Unrealized gain (loss) on commodity derivative contracts not designated as hedging instruments	-33.1	-20.9
Interest Rate Swap [Member] | Realized And Unrealized Gains Losses On Interest Rate Swaps [Member]
Derivative [Line Items]
Realized gain (loss) on commodity derivative contracts not designated as hedging instruments	0	-0.7
Realized and Unrealized Gain (Loss) on Commodity Derivative Contracts Not Designated as Hedging Instruments	$0	($0.70)

Debt_Narrative_Details

Debt (Narrative) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014
Debt Instrument [Line Items]
Less unamortized discount	($3.50)	($3.70)
Debt Maturity Period	5 years 0 months 0 days
Long-term Debt, Gross	2,221.80	2,221.80
Principal amount of senior notes outstanding	2,221.80
Debt Instrument, Maturity Date Range, Start	1-Sep-16
Debt Instrument, Maturity Date Range, End	1-May-23
Senior Notes, stated interest rate, minimum (in hundredths)	5.25%
Senior Notes, stated interest rate, maximim (in hundredths)	6.88%
Revolving Credit Facility due 2019 [Member]
Debt Instrument [Line Items]
Maturity date of long-term debt	2-Dec-19
Borrowing capacity	1,800
Weighted-average interest rate (in hundredths)			2.19%
Letters of credit outstanding	3.7	3.7
Long-term Debt, Gross	0	0
6.05% Senior Notes due 2016 [Member]
Debt Instrument [Line Items]
Long-term debt, interest rate (in hundredths)	6.05%
Maturity date of long-term debt	1-Sep-16
Long-term Debt, Gross	176.8	176.8
6.80% Senior Notes due 2018 [Member]
Debt Instrument [Line Items]
Long-term debt, interest rate (in hundredths)	6.80%
Maturity date of long-term debt	1-Apr-18
Long-term Debt, Gross	134	134
6.80% Senior Notes Due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt, interest rate (in hundredths)	6.80%
Maturity date of long-term debt	1-Mar-20
Long-term Debt, Gross	$136	$136

Debt_Schedule_of_Debt_Instrume

Debt Schedule of Debt Instruments (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Debt Instrument [Line Items]
Long-term Debt, Gross	$2,221.80	$2,221.80
Less unamortized discount	-3.5	-3.7
Long-term Debt	2,218.30	2,218.10
Revolving Credit Facility due 2019 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	0	0
Senior Notes Due 2016 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	176.8	176.8
Senior Notes Due 2018 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	134	134
Senior Notes Due 2020 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	136	136
Senior Notes Due 2021 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	625	625
Senior Notes Due 2022 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	500	500
5.25% Senior Notes Due 2023 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	$650	$650

Contingencies_Narrative_Detail

Contingencies (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Loss Contingency, Range of Possible Loss, Minimum		$0
Litigation Settlement, Amount	16.7
Loss Contingency, Range of Possible Loss, Maximum		$20

ShareBased_Compensation_Narrat

Share-Based Compensation (Narrative) (Details) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares available for future grants	9.2
Share-based compensation	$9.10	$7.50
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Intrinsic value of options exercised		0.2
Unrecognized compensation costs	4
Weighted average period for recognition of equity-based compensation expense	2 years 6 months 24 days
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant date fair value, grants	$21.67	$31.69
Unrecognized compensation costs	39.7
Weighted average period for recognition of equity-based compensation expense	2 years 7 months 21 days
Award vesting period	3 years 0 months 0 days
Total fair value of stock that vested during the period	18	15.1
Performance Share Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant date fair value, grants	$21.69	$31.69
Unrecognized compensation costs	3.1
Weighted average period for recognition of equity-based compensation expense	2 years 3 months 16 days
Continuing Operations [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	9.1	6.4
Discontinued Operations [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation		$1.10

ShareBased_Compensation_Fair_V

Share-Based Compensation Fair Value Of Options Granted And Major Assumptions Used (Details) (USD $)	3 Months Ended
	Mar. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted-average grant-date fair value of awards granted during the period	$6.82
Weighted-average risk-free interest rate	1.38%
Weighted-average expected price volatility	36.80%
Expected dividend yield	0.37%
Expected term in years at the date of grant	4 years 6 months

ShareBased_Compensation_Schedu

Share-Based Compensation Schedule Of Stock Option Transactions (Details) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Outstanding at beginning of period	1,996,215
Options granted	425,877
Options forfeited	-2,817
Options cancelled	-60,000
Outstanding at end of period	2,359,275
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Weighted average exercise price, beginning of year	$28.60
Weighted average exercise price, granted in period	$21.69
Weighted average exercise price, forfeited in period	$31.31
Weighted average exercise price, canceled in period	$27.84
Weighted average exercise price, end of year	$27.37
Options exercisable, shares	1,673,563
Options exercisable, weighted average exercise price	$28.24
Unvested options, shares	685,712
Unvested options, weighted average exercise price	$25.23
Weighted average remaining contractual term, options outstanding	3 years 8 months 18 days
Weighted average remaining contractual term, options exercisable	2 years 7 months 18 days
Weighted average remaining contractual term, options unvested	6 years 4 months 12 days
Aggregate intrinsic value, options outstanding	$0.20
Aggregate intrinsic value, options exercisable	0.2
Aggregate intrinsic value, options unvested	$0

ShareBased_Compensation_Schedu1

Share-Based Compensation Schedule of Restricted Stock Transactions (Details) (Restricted Stock [Member], USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Unvested balance at beginning of period	1,426,453
Shares granted	1,359,488
Shares vested	-584,111
Shares forfeited	-61,144
Unvested balance at end of period	2,140,686
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures [Abstract]
Weighted average grant date fair value, beginning of period	$31.02
Weighted average grant date fair value, grants	$21.67	$31.69
Weighted average grant date fair value, vested	$30.88
Weighted average grant date fair value, forfeited	$28.48
Weighted average grant date fair value, end of period	$25.19

ShareBased_Compensation_Schedu2

Share-Based Compensation Schedule Of Performance Share Unit Transactions (Details) (Performance Share Units [Member], USD $)	3 Months Ended
	Mar. 31, 2015		Mar. 31, 2014
Performance Share Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Unvested balance at beginning of period	552,209
Shares granted	234,085
Shares vested	-131,665
Shares vested and canceled	-14,612	[1]
Shares forfeited	-6,792
Unvested balance at end of period	633,225
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures [Abstract]
Weighted average grant date fair value, beginning of period	$30.85
Weighted average grant date fair value, grants	$21.69		$31.69
Weighted average grant date fair value, vested	$30.77
Weighted average grant date fair value, vested and canceled	$30.77	[1]
Weighted average grant date fair value, forfeited	$28.29
Weighted average grant date fair value, end of period	$27.52
[1]	Represents units that were not paid out due to

Employee_Benefits_Narrative_De

Employee Benefits (Narrative) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Funded Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension Contributions	$1
Defined Benefit Plans, Estimated Future Employer Contributions in Current Fiscal Year	3
Unfunded Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Pension Contributions	0.4
Defined Benefit Plans, Estimated Future Employer Contributions in Current Fiscal Year	4
Other Postretirement Benefit Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Current Fiscal Year	0.3
Continuing Operations [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Other Postretirement Benefit Expense	1.7	2
Discontinued Operations [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Other Postretirement Benefit Expense		$0.50

Employee_Benefits_Schedule_of_

Employee Benefits Schedule of Net Periodic Benefit Cost (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Other Postretirement Benefit Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Interest cost	$0.10		$0.10
Amortization of prior service costs (1)	0	[1]	0.1	[1]
Periodic expense	0.1		0.2
Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	0.6		0.7
Interest cost	1.3		1.4
Expected return on plan assets	-1.4		-1.2
Amortization of prior service costs (1)	0.8	[1]	1.2	[1]
Amortization of actuarial losses (1)	0.3	[1]	0.2	[1]
Periodic expense	$1.60		$2.30
[1]	Amortization of prior service costs and actuarial losses out of AOCI are recognized in the Condensed Consolidated Statements of Operations in "General and administrative."

Operations_by_Line_of_Business2

Operations by Line of Business (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Revenues
Total Revenues	$491.60	$817.50
Operating expenses
Purchased gas and oil expense	169.4	237.9
Lease operating expense	61.8	56.4
Natural gas, oil and NGL transportation and other handling costs	65.1	59.9
Gathering, processing and other	1.7	1.6
General and administrative	47.4	45.3
Production and property taxes	27.8	47.9
Depreciation, depletion and amortization	195.4	225.9
Other operating expenses	21.1	4.2
Total operating expenses	589.7	679.1
Net gain (loss) from asset sales	-30.5	2.4
Operating income (loss)	-128.6	140.8
Realized and unrealized gains (losses) on derivative contracts	80.9	-80.9
Interest and other income (expense)	-2.6	2.9
Interest expense	-36.8	-41.9
Income (loss) before income taxes	-87.1	20.9
Income taxes	31.5	-8.2
Income from continuing operations	-55.6	12.7
NET INCOME (LOSS)	0	27
Net income (loss)	-55.6	39.7
Assets	8,524.40	10,535.60	9,286.80
Unaffiliated customers [Member]
Revenues
Total Revenues	491.6	817.5
Affiliated customers [Member]
Revenues
Total Revenues	0	0
QEP Energy [Member]
Revenues
Total Revenues	353.3	613.2
Operating expenses
Purchased gas and oil expense	31.2	38
Lease operating expense	61.8	56.4
Natural gas, oil and NGL transportation and other handling costs	67.4	64.5
Gathering, processing and other	0	0
General and administrative	46.2	45
Production and property taxes	27.5	47.4
Depreciation, depletion and amortization	192.7	223.4
Other operating expenses	21.1	4.2
Total operating expenses	447.9	478.9
Net gain (loss) from asset sales	-27.8	2.4
Operating income (loss)	-122.4	136.7
Realized and unrealized gains (losses) on derivative contracts	80.2	-78.5
Interest and other income (expense)	-3.5	2.9
Interest expense	-47.2	-48.9
Income (loss) before income taxes	-92.9	12.2
Income taxes	-33.6	-7.1
Income from continuing operations		5.1
NET INCOME (LOSS)		0
Net income (loss)	-59.3	5.1
Assets		9,004.10
QEP Energy [Member] | Unaffiliated customers [Member]
Revenues
Total Revenues	353.3	613.2
QEP Energy [Member] | Affiliated customers [Member]
Revenues
Total Revenues	0	0
QEP Marketing and Other [Member]
Revenues
Total Revenues	345.8	507.8
Operating expenses
Purchased gas and oil expense	342.8	497.9
Lease operating expense	0	0
Natural gas, oil and NGL transportation and other handling costs	0	0
Gathering, processing and other	1.7	1.6
General and administrative	1.8	1.2
Production and property taxes	0.3	0.5
Depreciation, depletion and amortization	2.7	2.5
Other operating expenses	0	0
Total operating expenses	349.3	503.7
Net gain (loss) from asset sales	-2.7	0
Operating income (loss)	-6.2	4.1
Realized and unrealized gains (losses) on derivative contracts	0.7	-2.4
Interest and other income (expense)	48	48.8
Interest expense	-36.7	-41.8
Income (loss) before income taxes	5.8	8.7
Income taxes	2.1	-1.1
Income from continuing operations		7.6
NET INCOME (LOSS)		0
Net income (loss)	3.7	7.6
Assets		225.3
QEP Marketing and Other [Member] | Unaffiliated customers [Member]
Revenues
Total Revenues	138.3	204.3
QEP Marketing and Other [Member] | Affiliated customers [Member]
Revenues
Total Revenues	207.5	303.5
Elimination [Member]
Revenues
Total Revenues	-207.5	-303.5
Operating expenses
Purchased gas and oil expense	-204.6	-298
Lease operating expense	0	0
Natural gas, oil and NGL transportation and other handling costs	-2.3	-4.6
Gathering, processing and other	0	0
General and administrative	-0.6	-0.9
Production and property taxes	0	0
Depreciation, depletion and amortization	0	0
Other operating expenses	0	0
Total operating expenses	-207.5	-303.5
Net gain (loss) from asset sales	0	0
Operating income (loss)	0	0
Realized and unrealized gains (losses) on derivative contracts	0	0
Interest and other income (expense)	-47.1	-48.8
Interest expense	47.1	48.8
Income (loss) before income taxes	0	0
Income taxes	0	0
Income from continuing operations		0
NET INCOME (LOSS)		0
Net income (loss)	0	0
Assets		0
Elimination [Member] | Unaffiliated customers [Member]
Revenues
Total Revenues	0	0
Elimination [Member] | Affiliated customers [Member]
Revenues
Total Revenues	-207.5	-303.5
Discontinued Operations [Member]
Revenues
Total Revenues		0
Operating expenses
Purchased gas and oil expense		0
Lease operating expense		0
Natural gas, oil and NGL transportation and other handling costs		0
Gathering, processing and other		0
General and administrative		0
Production and property taxes		0
Depreciation, depletion and amortization		0
Other operating expenses		0
Total operating expenses		0
Net gain (loss) from asset sales		0
Operating income (loss)		0
Realized and unrealized gains (losses) on derivative contracts		0
Interest and other income (expense)		0
Interest expense		0
Income (loss) before income taxes		0
Income taxes		0
Income from continuing operations		0
NET INCOME (LOSS)		27
Net income (loss)		27
Assets		1,306.20
Discontinued Operations [Member] | Unaffiliated customers [Member]
Revenues
Total Revenues		0
Discontinued Operations [Member] | Affiliated customers [Member]
Revenues
Total Revenues		$0