Qep Resources (QEP) 10-Q 5 Nov 14 2014 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2014
Document and Entity Information [Abstract]	'
Entity Registrant Name	'QEP RESOURCES, INC.
Entity Central Index Key	'0001108827
Current Fiscal Year End Date	'--12-31
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	180,149,080
Document Fiscal Year Focus	'2014
Document Fiscal Period Focus	'Q3
Document Type	'10-Q
Amendment Flag	'false
Document Period End Date	30-Sep-14

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
REVENUES	'	'	'	'
Gas sales	$171.60	$194.80	$609.20	$610.50
Oil sales	393.5	253.8	1,041	656.3
NGL sales	51.1	47.7	179.3	144.4
Other revenue	3.4	2.8	5.1	8.7
Purchased gas, oil and NGL sales	290.4	220.4	780.1	644.9
Total Revenues	910	719.5	2,614.70	2,064.80
OPERATING EXPENSES	'	'	'	'
Purchased gas, oil and NGL expense	288.4	219.5	775.5	650.3
Lease operating expense	61.1	43.5	177	130.2
Gas, oil and NGL transportation and other handling costs	71.1	58.6	198.5	158.5
Gathering and other expense	1.4	2.1	4.8	6.4
General and administrative	49.4	40.7	147	116.8
Production and property taxes	59.4	40.6	160.8	113.7
Depreciation, depletion and amortization	251.4	238.4	712.5	719.3
Exploration expenses	0.8	1.8	4.7	9.5
Impairment	0.1	3.8	3.6	4
Total operating expenses	783.1	649	2,184.40	1,908.70
Net gain (loss) from asset sales	-11.8	12.8	-210.3	113.4
OPERATING INCOME	115.1	83.3	220	269.5
Realized and unrealized gains (losses) on derivative contracts (See Note 8)	155.7	-27.8	-13.2	51.6
Interest and other income	4.2	6.1	7.8	22.7
Income from unconsolidated affiliates	0.1	0	0.2	0
Interest expense	-41.5	-41.4	-128.4	-124.7
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	233.6	20.2	86.4	219.1
Income tax provision	-79.9	-8.1	-26.1	-82.5
NET INCOME FROM CONTINUING OPERATIONS	153.7	12.1	60.3	136.6
Discontinued operations, net of income tax	17.4	25.2	58.2	74.8
NET INCOME ATTRIBUTABLE TO QEP	$171.10	$37.30	$118.50	$211.40
Earnings Per Common Share Attributable to QEP	'	'	'	'
Earnings Per Share, Basic	$0.95	$0.21	$0.66	$1.18
Earnings Per Share, Diluted	$0.94	$0.21	$0.66	$1.18
Weighted-average common shares outstanding	'	'	'	'
Used in basic calculation (in shares)	180.1	179.3	180	179.2
Used in diluted calculation (in shares)	180.6	179.5	180.4	179.4
Dividends per common share (in dollars per share)	$0.02	$0.02	$0.06	$0.06
Continuing Operations [Member]	'	'	'	'
Earnings Per Common Share Attributable to QEP	'	'	'	'
Earnings Per Share, Basic	$0.85	$0.07	$0.34	$0.76
Earnings Per Share, Diluted	$0.84	$0.07	$0.34	$0.76
Discontinued Operations [Member]	'	'	'	'
Earnings Per Common Share Attributable to QEP	'	'	'	'
Earnings Per Share, Basic	$0.10	$0.14	$0.32	$0.42
Earnings Per Share, Diluted	$0.10	$0.14	$0.32	$0.42

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Statement of Comprehensive Income [Abstract]	'		'		'		'
Net income attributable to QEP	$171.10		$37.30		$118.50		$211.40
Other comprehensive (loss) income, net of tax:	'		'		'		'
Reclassification of previously deferred derivative gains(1)	0	[1]	-19.7	[1]	0	[1]	-60.4	[1]
Pension and other postretirement plans adjustments:	'		'		'		'
Amortization of net actuarial loss	0.2	[2]	0.4	[2]	0.4	[2]	1.1	[2]
Amortization of prior service cost	0.7	[3]	0.8	[3]	2.4	[3]	2.5	[3]
Total pension and other postretirement plans adjustments	0.9		1.2		2.8		3.6
Other comprehensive loss	0.9		-18.5		2.8		-56.8
Comprehensive (loss) income attributable to QEP	$172		$18.80		$121.30		$154.60
[1]	Presented net of income tax benefit of $11.7 million and $35.8 million during the three and nine months ended September 30, 2013
[2]	Presented net of income tax expense of $0.2 million during the nine months ended September 30, 2014 and $0.2 million and $0.7 million during the three and nine months ended September 30, 2013, respectively.
[3]	Presented net of income tax expense of $0.5 million and $1.5 million during the three and nine months ended September 30, 2014, respectively, and $0.5 million and $1.5 million during the three and nine months ended September 30, 2013, respectively.

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Other comprehensive income (loss), tax	'	'	'	'
Tax expense (benefit) on gains (losses) on changes in unrealized fair value of derivatives designated as cash flow hedges	'	($11.70)	'	($35.80)
Pension and other postretirement plans adjustments:	'	'	'	'
Tax expense (benefit) on net unamortized gain (loss) incurred	'	0.2	0.2	0.7
Tax expense (benefit) on prior service cost incurred	$0.50	$0.50	$1.50	$1.50

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current Assets	'	'
Cash and cash equivalents	$0	$11.90
Accounts receivable, net	599.4	316.3
Fair value of derivative contracts	32.6	0.2
Gas, oil and NGL inventories at lower of average cost or market	16.4	13.4
Deferred income taxes - current	0	27.9
Prepaid expenses and other	50.8	45.4
Current assets of discontinued operations held for sale	138.3	122
Total Current Assets	837.5	537.1
Property, Plant and Equipment (successful efforts method for gas and oil properties)	'	'
Proved properties	11,723	11,571.40
Unproved properties	1,120.50	665.1
Midstream	197.5	197.3
Marketing and resources	95.2	85.5
Material and supplies	55.3	54.3
Total Property, Plant and Equipment	13,191.50	12,573.60
Less Accumulated Depreciation, Depletion and Amortization	'	'
Exploration and production	4,915	4,930.90
Midstream	34.3	28.1
Marketing and resources	29.8	22.1
Total Accumulated Depreciation, Depletion and Amortization	4,979.10	4,981.10
Net Property, Plant and Equipment	8,212.40	7,592.50
Fair value of derivative contracts	12.7	1
Restricted cash	0	50
Other noncurrent assets	39.4	46.6
Noncurrent assets of discontinued operations held for sale	1,174.20	1,167.70
TOTAL ASSETS	10,276.20	9,394.90
Current Liabilities	'	'
Checks outstanding in excess of cash balances	36.8	109.1
Accounts payable and accrued expenses	691.4	361.9
Production and property taxes	73.5	49.4
Interest payable	34.1	37.2
Fair value of derivative contracts	4.5	26.7
Deferred income taxes	2.9	0
Current liabilities of discontinued operations held for sale	161.6	75.3
Total Current Liabilities	1,004.80	659.6
Long-term debt	3,115.50	2,997.50
Deferred income taxes	1,500.80	1,364.90
Asset retirement obligations	162.3	163.3
Fair value of derivative contracts	0.2	0
Other long-term liabilities	90.3	94.5
Noncurrent liabilities of discontinued operations held for sale	402	238.3
Commitments and contingencies	'	'
EQUITY	'	'
Common stock - par value $0.01 per share; 500.0 million shares authorized; 180.9 million and 179.7 million shares issued, respectively	1.8	1.8
Treasury stock - 0.8 million and 0.4 million shares, respectively	-25.1	-14.9
Additional paid-in capital	527.2	498.4
Retained earnings	3,025.40	2,917.80
Accumulated other comprehensive loss	-23.7	-26.5
Total Common Shareholders' Equity	3,505.60	3,376.60
Noncontrolling interest	494.7	500.2
Total Equity	4,000.30	3,876.80
TOTAL LIABILITIES AND EQUITY	$10,276.20	$9,394.90

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) (USD $)	Sep. 30, 2014	Dec. 31, 2013
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)	180.9	179.7
Treasury stock (in shares)	0.8	0.4

CONDENSED_CONSOLIDATED_STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
OPERATING ACTIVITIES	'	'
Net income attributable to QEP	$118.50	$211.40
Net income attributable to noncontrolling interest	17.6	5.8
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	755.8	757.1
Deferred income taxes	91.5	39.3
Impairment	3.6	4
Equity-based compensation	20.7	20
Amortization of debt issuance costs and discounts	5.1	4.7
Net loss (gain) from asset sales	210.3	-113
Income from unconsolidated affiliates	-4.6	-3.7
Distributions from unconsolidated affiliates and other	5.1	5.9
Unrealized (gain) loss on derivative contracts	-65.9	55.5
Changes in operating assets and liabilities	62	-8.1
Net Cash Provided by Operating Activities	1,219.70	978.9
INVESTING ACTIVITIES	'	'
Property acquisitions	-949.7	-39.3
Property, plant and equipment, including dry exploratory well expense	-1,270.40	-1,089.60
Proceeds from disposition of assets	706.2	208.3
Acquisition deposit held in escrow	50	0
Other investing activities	3.2	0
Net Cash Used in Investing Activities	-1,460.70	-920.6
FINANCING ACTIVITIES	'	'
Checks outstanding in excess of cash balances	-81.1	-38.1
Long-term debt issued	300	0
Long-term debt issuance costs paid	-1.1	-3
Proceeds from credit facility	4,509	2,132.50
Repayments of credit facility	-4,461.50	-2,457.50
Treasury stock repurchases	-6.6	-8.7
Net proceeds from the issuance of QEP Midstream common units	0	449.6
Other capital contributions	5.1	3.6
Dividends paid	-10.8	-10.8
Excess tax (provisions) benefit on equity-based compensation	-0.6	1.3
Distribution to noncontrolling interest	-23.3	-4.2
Net Cash Provided by Financing Activities	229.1	64.7
Change in cash and cash equivalents	-11.9	123
Beginning cash and cash equivalents	11.9	0
Ending cash and cash equivalents	0	123
Supplemental Disclosures:	'	'
Cash paid for interest, net of capitalized interest	128.9	120.1
Cash paid for income taxes	-1.1	49.4
Non-cash investing activities	'	'
Change in capital expenditure accrual balance	$66.50	$53.70

Nature_of_Business

Nature of Business	9 Months Ended
	Sep. 30, 2014
Nature Of Business [Abstract]	'
Nature of Business	'
	Nature of Business
	QEP Resources, Inc. (QEP or the Company) is a holding company with two major 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 a underground gas storage reservoir (QEP Marketing and Other).
	QEP's operations are focused in two geographic regions: the Northern Region (primarily in North Dakota, Wyoming and Utah) and the Southern Region (primarily in Texas and Louisiana) of the United States. QEP's corporate headquarters are located in Denver, Colorado.
	In December 2013, QEP's Board of Directors authorized the Company to develop a plan to separate its midstream business, QEP Field Services, including the Company's interest in QEP Midstream Partners, LP (“QEP Midstream”), from QEP. Between December 2013 and September 2014, the Company evaluated transaction alternatives, including selling or merging the midstream business or spinning the midstream business off to its shareholders. In June 2014, QEP filed a registration statement on Form 10 with the U.S. Securities and Exchange Commission (SEC) in preparation for a potential spinoff of QEP Field Services as a separate publicly traded company. Concurrently, the Company evaluated selling or merging its midstream business. In September 2014, based on the proposals received, the Company's Board of Directors authorized QEP's management to engage in the negotiation of terms of a definitive transaction with Tesoro Logistics LP ("Tesoro"). In October 2014, the Company announced that its wholly owned subsidiary, 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 to Tesoro in an all cash transaction valued at $2.5 billion, including $230.0 million to refinance debt at QEP Midstream. The transaction is subject to customary closing conditions and regulatory approvals, and is expected to close before year-end 2014. On October 31, 2014, the Federal Trade Commission granted early termination, ending the Hart Scott Rodino waiting period for the transaction. The decision to sell the midstream business is a result of the Company’s ongoing review of strategic alternatives to maximize shareholder value. QEP will retain ownership of QEP Field Services’ Haynesville Gathering System. As a result of the pending transaction, the QEP Field Services reporting segment, excluding the retained ownership of the Haynesville Gathering System, has been classified as assets and liabilities held for sale on the Condensed Consolidated Balance Sheet and as a discontinued operation on the Condensed Consolidated Statement of Operations and the notes accompanying the Condensed Consolidated Financial Statements. For reporting purposes, the retained Haynesville Gathering System has been combined with QEP Marketing and Other.
	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	9 Months Ended
	Sep. 30, 2014
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 for the year ended December 31, 2013.
	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 and nine months ended September 30, 2014, are not necessarily indicative of the results that may be expected for the year ending December 31, 2014.
	Reclassifications
	The 2013 financial information has been recast so that the basis of presentation is consistent with that of the 2014 financial information. This recast reflects the financial condition and results of operations, excluding the Haynesville Gathering System, of QEP Field Services as discontinued operations, for all periods presented. For a summary of discontinued operations see Note 4 - Discontinued Operations.
	During the first nine months of 2013, QEP presented certain credit facility payments and borrowings on a net basis on the Condensed Consolidated Statements of Cash Flow. These borrowings and payments were reclassified to be presented on a gross basis on the Condensed Consolidated Statements of Cash Flow in order to conform with the current period presentation. This reclassification is entirely within "Financing Activities" and has no effect on other categories or total cash on the Condensed Consolidated Statements of Cash Flows or net income or earnings per share on the Condensed Consolidated Statements of Operations.
	New accounting pronouncements
	In April 2014, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2014-08, Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity, which broadened the reporting of discontinued operations to a component of an entity that has operations and cash flows that can be clearly distinguished from the rest of the entity. Under this guidance, to be a discontinued operation, a component or group of components must represent a strategic shift that has (or will have) a major effect on an entity's operations and financial results. The amendments are effective prospectively for reporting periods beginning on or after December 15, 2014 and early adoption is permitted. The Company has chosen to early adopt ASU 2014-08 and implemented the amendments in the quarter ended September 30, 2014.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606), which seeks to provide a single, comprehensive revenue recognition model for all contracts with customers to improve comparability within industries, across industries, and across capital markets. The revenue standard contains principles that an entity will apply to determine the measurement of revenue and timing of when it is recognized. The underlying principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. The amendments are effective prospectively for reporting periods beginning after December 15, 2016 and early adoption is not permitted. The Company is currently assessing the impact on the Company's consolidated financial statements.
	In August 2014, the FASB issued ASU No. 2014-15, Presentation of Financial Statements-Going Concern (Topic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. This guidance provides additional information to guide management's evaluation of whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date that the financial statements are issued. The update is effective for annual periods beginning on or after December 15, 2016. The Company is currently evaluating the impact of this standard on its financial statements.

Acquisitions_Divestitures

Acquisitions & Divestitures	9 Months Ended
	Sep. 30, 2014
Acquisitions [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, subject to post-closing purchase price adjustments (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 $114.2 million and net income of $23.1 million were generated from the acquired properties from February 25, 2014, to September 30, 2014, and are included in QEP's Condensed Consolidated Statements of Operations. During the nine months ended September 30, 2014, QEP Energy incurred acquisition-related costs of $0.6 million, which are included in "General and administrative" on the Condensed Consolidated Statement of Operations for the nine months ended September 30, 2014. QEP incurred $1.1 million of debt issuance costs associated with increasing the size of term loan borrowings to fund a portion of the acquisition, which are included in "Other noncurrent assets" on the Condensed Consolidated Balance Sheet as of September 30, 2014.
	QEP Energy recorded the Permian Basin Acquisition on its Condensed Consolidated Balance Sheet as of September 30, 2014. The following table presents a summary of the Company's purchase accounting entries:
		As of September 30, 2014
		(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 nine months ended September 30, 2014, and the three and nine months ended September 30, 2013. Pro forma results are not provided for the three months ended September 30, 2014, because the Permian Basin Acquisition occurred during the first quarter of 2014, and therefore there is no pro forma impact on the third quarter of 2014. 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 and nine months ended September 30, 2014 and 2013, 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 preliminary 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				Nine Months Ended
			September 30,				September 30,
			2013		2013		2014		2014		2013		2013
			Actual		Pro forma		Actual		Pro forma		Actual		Pro forma
							(in millions, except per share data)
	Revenues		$	719.5	$	776.5	$	2,614.70	$	2,640.80	$	2,064.80	$	2,195.40
	Net income (loss) attributable to QEP		37.3		54.2		118.5		125.5		211.4		240.4
	Earnings per common share attributable to QEP
	Basic		$	0.21	$	0.3	$	0.66	$	0.7	$	1.18	$	1.34
	Diluted		0.21		0.3		0.66		0.7		1.18		1.34
	Divestitures
	In June 2014, QEP Energy sold its interests in certain non-core properties in the Midcontinent area and other non-core assets in the Williston Basin for total cash proceeds of $702.3 million, subject to post-closing purchase price adjustments, and recorded a pre-tax loss of $210.4 million on QEP's Statements of Operations and Condensed Consolidated Statement of Operations in "Net loss from asset sales" for the nine months ended September 30, 2014. An additional $28.7 million of consideration is currently being held in escrow related to unresolved title defects.

Discontinued_Operations

Discontinued Operations	9 Months Ended
	Sep. 30, 2014
Discontinued Operations and Disposal Groups [Abstract]	'
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	'
	Discontinued Operations
	In December 2013, QEP's Board of Directors authorized the Company to develop a plan to separate its midstream business, QEP Field Services, including the Company's interest in QEP Midstream, from QEP. Between December 2013 and September 2014, the Company evaluated transaction alternatives, including selling or merging the midstream business or spinning the midstream business off to its shareholders. In June 2014, QEP filed a registration statement on Form 10 with the SEC in preparation for a potential spinoff of QEP Field Services as a separate publicly traded company. Concurrently, the Company evaluated selling or merging its midstream business. In September 2014, based on the proposals received, the Company's Board of Directors authorized QEP's management to engage in the negotiation of terms of a definitive transaction with Tesoro. In October 2014, the Company announced that its wholly owned subsidiary, 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 to Tesoro in an all cash transaction valued at $2.5 billion, including $230.0 million to refinance debt at QEP Midstream. The transaction is subject to customary closing conditions and regulatory approvals, and is expected to close before year-end 2014. On October 31, 2014, the Federal Trade Commission granted early termination, ending the Hart Scott Rodino waiting period for the transaction. The decision to sell the midstream business is a result of the Company’s ongoing review of strategic alternatives to maximize shareholder value and represents a significant milestone in the strategic repositioning of the Company. As of September 30, 2014, the operating results and financial position of QEP Field Services, excluding its retained ownership of the Haynesville Gathering System, were classified as discontinued operations as well as assets and liabilities held for sale on its balance sheet. After the transaction closes, QEP will have continuing cash outflows to our discontinued midstream business for gathering, processing and water handling costs in Pinedale, the Uinta Basin and a portion of its Williston Basin operations. These contracts 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 and are now reflected as part of the continuing operations for QEP. For the three months ended September 30, 2014 and 2013, cash outflows for these transactions that are included in continuing operations were $19.0 million and $25.9 million, respectively. For the nine months ended September 30, 2014 and 2013, cash outflows for these transactions that are included in continuing operations were $64.1 million and $67.2 million, respectively.
	Condensed Consolidated Income Statement
	The discontinued operations of QEP Field Services (excluding results of the Haynesville Gathering System) are summarized below:
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in millions, except per share amounts)
	REVENUES
	NGL sales	$	28.8		$	23.6		$	94.6		$	70.6
	Other revenue	43.1			44.2			119.9			126.4
	Purchased gas, oil and NGL sales(1)	(11.9		)	(14.4		)	(38.5		)	(41.5		)
	Total Revenues	60			53.4			176			155.5
	OPERATING EXPENSES
	Purchased gas, oil and NGL expense(1)	(12.4		)	(14.4		)	(39.5		)	(41.4		)
	Lease operating expense(1)	(1.7		)	(0.8		)	(4.8		)	(2.6		)
	Natural gas, oil and NGL transport & other handling costs(1)	(10.6		)	(21.7		)	(40.1		)	(53.0		)
	Gathering, processing, and other	22.7			20.3			69.8			60.1
	General and administrative	11.1			8.6			34.3			19.4
	Production and property taxes	2.1			1.8			6.1			4
	Depreciation, depletion and amortization	14.3			14.7			43.1			37.8
	Total Operating Expenses	25.5			8.5			68.9			24.3
	Net loss from asset sales	—			(0.1		)	(0.1		)	(0.5		)
	OPERATING INCOME	34.5			44.8			107			130.7
	Interest income and other loss	—			(2.1		)	—			(13.7		)
	Income from unconsolidated affiliates	1.1			0.8			4.4			3.7
	Interest expense	(1.5		)	(0.3		)	(2.8		)	2.3
	INCOME FROM DISCONTINUED OPERATIONS BEFORE INCOME TAXES (2)	34.1			43.2			108.6			123
	Income taxes	(9.9		)	(14.2		)	(32.8		)	(42.4		)
	NET INCOME FROM DISCONTINUED OPERATIONS	24.2			29			75.8			80.6
	Net income attributable to noncontrolling interest	(6.8		)	(3.8		)	(17.6		)	(5.8		)
	NET INCOME FROM DISCONTINUED OPERATIONS, NET OF INCOME TAX	$	17.4		$	25.2		$	58.2		$	74.8
	(1) Includes discontinued intercompany eliminations
	(2) Includes income from discontinued operations before income taxes attributable to QEP from QEP Midstream (of which QEP owns 57.8%) of $7.9 million and $20.4 million for the three and nine months ended September 30, 2014, respectively, and $7.9 million and $26.2 million for the three and nine months ended September 30, 2013, respectively.
	Condensed Consolidated Balance Sheet
	The current and noncurrent assets and liabilities of QEP Field Services, excluding the retained Haynesville Gathering System, are as follows:
		September 30,			December 31,
		2014			2013
	Cash and cash equivalents	$	27.1		$	18.1
	Accounts receivable, net	71.8			53.9
	Income taxes receivable	—			38.4
	Deferred income taxes - current	7			2.7
	Prepaid expenses and other	32.4			8.9
	Current assets of discontinued operations held for sale	$	138.3		$	122
	Property, Plant and Equipment
	Midstream field services	$	1,550.50		$	1,500.80
	Material and supplies	6.5			4.8
	Total Property, Plant and Equipment	1,557.00			1,505.60
	Less Accumulated Depreciation, Depletion and Amortization
	Midstream field services	(422.2		)	(381.6		)
	Net Property, Plant and Equipment	1,134.80			1,124.00
	Investment in unconsolidated affiliates	35.9			39
	Other noncurrent assets	3.5			4.7
	Noncurrent assets of discontinued operations held for sale	$	1,174.20		$	1,167.70
	Accounts payable and accrued expenses	$	85.6		$	74.1
	Accrued income taxes	70.2			—
	Production and property taxes	5.4			1.2
	Interest payable	0.4			—
	Current liabilities of discontinued operations held for sale	$	161.6		$	75.3
	Long-term debt	$	230		$	—
	Deferred income taxes	126.5			195.7
	Asset retirement obligations	29.9			28.5
	Other long-term liabilities	15.6			14.1
Noncurrent liabilities of discontinued operations held for sale	$	402		$	238.3
Condensed Consolidated Statement of Cash Flows
The impact of the QEP Field Services discontinued operations, excluding the Haynesville Gathering System, on the Condensed Consolidated Statement of Cash Flows for "Depreciation, depletion and amortization" contained in "Cash flows from operating activities" was $43.1 million and $37.8 million for the nine months ended September 30, 2014 and 2013, respectively. The impact on cash used for "Property, plant and equipment, including dry exploratory well expense" contained in "Cash flows from investing activities" was $45.6 million and $57.4 million for the nine months ended September 30, 2014 and 2013, respectively.

Earnings_Per_Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2014
Earnings Per Share [Abstract]	'
Earnings Per Share	'
	Earnings Per Share
	Basic earnings per share (EPS) are computed by dividing net income attributable to QEP 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 equity-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 and nine months ended September 30, 2014 and 2013, 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		Nine Months Ended
		September 30,		September 30,
		2014	2013	2014	2013
		(in millions)
	Weighted-average basic common shares outstanding	180.1	179.3	180	179.2
	Potential number of shares issuable upon exercise of in-the-money stock options under the Long-term Stock Incentive Plan	0.5	0.2	0.4	0.2
	Average diluted common shares outstanding	180.6	179.5	180.4	179.4

Asset_Retirement_Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2014
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, production facilities, 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 $163.2 million and $165.1 million ARO liability for continuing operations for the periods ended September 30, 2014 and December 31, 2013, $0.9 million and $1.8 million was 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 continuing operations for the periods specified below:
		Asset Retirement Obligations
		2014
		(in millions)
	ARO liability at January 1, (1)	$	165.1
	Accretion	4.9
	Additions(2)	15.5
	Revisions	(0.3		)
	Liabilities settled(3)	(22.0		)
	ARO liability at September 30,(4)	$	163.2
	____________________________
	(1) Excludes $28.5 million of ARO classified as liabilities held for sale on the Condensed Consolidated Balance Sheet.
	(2) Additions include $9.7 million related to the Permian Basin Acquisition (see Note 3 - Acquisitions and Divestitures).
	(3) Settlements include $20.2 million related to the property sales in the second quarter of 2014 (see Note 3 - Acquisitions and Divestitures).
	(4) Excludes $29.9 million of ARO classified as liabilities held for sale on the Condensed Consolidated Balance Sheet.

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2014
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.
	In addition, QEP has interest rate swaps that it has determined are Level 2 financial instruments. The fair values of the interest rate swaps are determined using the market standard methodology of discounting the future expected cash flows that would occur under the contractual terms of the swap. The variable interest rates used in the calculation of projected cash flows are based on an expectation of future interest rates derived from observable market interest rate curves. QEP incorporates credit valuation adjustments to reflect both its nonperformance risk and the respective counterparty's nonperformance risk in the fair value measurements. While the credit valuation adjustments are not observable inputs, they are not significant to the overall valuation and the other inputs used to value the interest rate swaps are observable Level 2 inputs.
	The fair value measurements of financial assets and liabilities at September 30, 2014, are shown in the table below:
		Fair Value Measurements
		September 30, 2014
		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)
	Financial Assets
	Commodity derivative instruments - short-term	$	—	$	36.6	$	—	$	(4.0	)	$	32.6
	Commodity derivative instruments - long-term	—		9.6		—		(0.4		)	9.2
	Interest rate swaps - long-term	—		3.5		—		—			3.5
	Total financial assets	$	—	$	49.7	$	—	$	(4.4	)	$	45.3
	Financial Liabilities
	Commodity derivative instruments - short-term	$	—	$	4.2	$	—	$	(4.0	)	$	0.2
	Interest rate swaps - short-term	—		4.3		—		—			4.3
	Commodity derivative instruments - long-term	—		0.6		—		(0.4		)	0.2
	Total financial liabilities	$	—	$	9.1	$	—	$	(4.4	)	$	4.7
	____________________________
	(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 fair value of financial assets and liabilities at December 31, 2013, is shown in the table below:
		Fair Value Measurements
		31-Dec-13
		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)
	Financial Assets
	Commodity derivative instruments - short-term	$	—	$	5.5	$	—	$	(5.3	)	$	0.2
	Commodity derivative instruments - long-term	—		0.4		—		—			0.4
	Interest rate swaps - long-term	—		0.6		—		—			0.6
	Total financial assets	$	—	$	6.5	$	—	$	(5.3	)	$	1.2
	Financial Liabilities
	Commodity derivative instruments - short-term	$	—	$	29.4	$	—	$	(5.3	)	$	24.1
	Interest rate swaps - short-term	—		2.6		—		—			2.6
	Total financial liabilities	$	—	$	32	$	—	$	(5.3	)	$	26.7
	_______________________
	(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
		September 30, 2014				December 31, 2013
		(in millions)
	Financial assets
	Cash and cash equivalents	$	—	$	—	$	11.9	$	11.9
	Financial liabilities
	Checks outstanding in excess of cash balances	$	36.8	$	36.8	$	109.1	$	109.1
	Long-term debt	$	3,115.50	$	3,209.30	$	2,997.50	$	3,034.90
	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 remaining reserve lives. A reconciliation of the Company’s ARO is presented in Note 6 – Asset Retirement Obligations.

Derivative_Contracts

Derivative Contracts	9 Months Ended
	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Contracts	'
	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 to realize a known price 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 basis swaps to achieve a fixed price swap for a portion of its oil that it sells at prices that reference ICE Brent and Light Louisiana Sweet (LLS).
	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.
	Effective January 1, 2012, QEP elected to de-designate all of its gas, oil and NGL derivative contracts that were previously designated as cash flow hedges and discontinue hedge accounting prospectively. As a result of discontinuing hedge accounting, the mark-to-market values at December 31, 2011, were fixed in Accumulated Other Comprehensive Income (AOCI) as of the de-designation date and are being reclassified into the Condensed Consolidated Statements of Operations as the transactions settle and affect earnings. During the nine months ended September 30, 2013, $60.4 million of unrealized gains, after tax, were reclassified from AOCI into the Condensed Consolidated Statements of Operations in "Realized and unrealized losses on derivative contracts" as the transactions settled. All realized and unrealized gains and losses from derivative instruments incurred after January 1, 2012, are presented in the Condensed Consolidated Statements of Operations in "Realized and unrealized losses on derivative contracts" below operating income.
	QEP also uses interest rate swaps to mitigate a portion of its exposure to interest rate volatility risk 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%. The average effective interest rate on the $600.0 million term loan when combined with the fixed interest rate swaps for the nine months ended September 30, 2014 was 3.21%. The interest rate swaps settle monthly and will mature in March 2017.
	QEP Energy Derivative Contracts
	The following table sets forth QEP Energy’s quantities and average prices for its commodity derivative contracts as of September 30, 2014:
	Year		Type of Contract		Index	Total			Average Swap price per unit
						Volumes
						(in millions)
	Gas sales					(MMBtu)
	2014		SWAP		NYMEX	7.4			$	4.22
	2014		SWAP		IFNPCR	20.2			$	4.08
	2015		SWAP		NYMEX	25.6			$	4.14
	2015		SWAP		IFNPCR	11			$	4.06
	Oil sales					(Bbls)
	2014		SWAP		NYMEX WTI	3.1			$	93.54
	2015		SWAP		NYMEX WTI	7.7			$	90.04
	2015		SWAP		BRENT ICE	0.4			$	104.95
	2016		SWAP		NYMEX WTI	0.4			$	90
	The following table sets forth QEP Energy's oil basis swaps as of September 30, 2014:
	Year		Index		Index Less Differential	Total Volumes			Weighted Average Differential
						(in millions)
	Oil basis swaps					(Bbls)
	2014		NYMEX WTI		ICE Brent	0.2			$	13.78
	2014		NYMEX WTI		LLS	0.2			$	4.03
	2015		NYMEX WTI		LLS	0.1			$	4.03
	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 September 30, 2014:
	Year		Type of Contract		Index	Total			Average Swap price
						Volumes			per MMBtu
						(in millions)
	Gas sales					(MMBtu)
	2014		SWAP		IFNPCR	1.4			$	4.03
	2015		SWAP		IFNPCR	2.5			4.07
	Gas purchases					(MMBtu)
	2014		SWAP		IFNPCR	0.6			$	3.86
	QEP's Derivative Contracts
	The following table sets forth QEP’s notional amount and interest rate for its interest rate swaps outstanding as of September 30, 2014:
	Notional amount		Type of Contract		Maturity	Fixed Rate Paid		Variable Rate Received
	(in millions)
	$300.00		Swap		Mar-17	1.07%		One-month LIBOR
	$300.00		Swap		Mar-17	0.86%		One-month LIBOR
	$600.00					0.96%
	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		September 30,			31-Dec-13				September 30,			31-Dec-13
		line item		2014							2014
				(in millions)							(in millions)
	Current:
	Commodity	Fair value of derivative contracts		$	36.6		$	5.5			$	4.2		$	29.4
	Interest rate swaps	Fair value of derivative contracts		—			—				4.3			2.6
	Long-term:
	Commodity	Fair value of derivative contracts		9.6			0.4				0.6			—
	Interest rate swaps	Fair value of derivative contracts		3.5			0.6				—			—
	Total derivative instruments			$	49.7		$	6.5			$	9.1		$	32
	The effects of the change in fair value and settlement of QEP's derivative contracts recorded in "Realized and unrealized losses on derivative contracts" on the Condensed Consolidated Statements of Operations are summarized in the following tables:
			Three Months Ended							Nine Months Ended
	Derivative instruments not designated as cash flow hedges		September 30,							September 30,
			2014			2013				2014			2013
Realized gains (losses) on commodity derivative contracts		(in millions)
QEP Energy
Gas derivative contracts		$	5.5		$	42.5			$	(23.3	)	$	112
Oil derivative contracts		(12.2		)	(15.3		)		(50.2		)	(3.7		)
QEP Marketing
Gas derivative contracts		(0.4		)	(0.3		)		(2.4		)	0.7
Total realized gains (losses) on commodity derivative contracts		(7.1		)	26.9				(75.9		)	109
Unrealized gains (losses) on commodity derivative contracts
QEP Energy
Gas derivative contracts		27.6			(6.6		)		9.5			(9.6		)
Oil derivative contracts		133.2			(46.2		)		54.3			(49.1		)
QEP Marketing
Gas derivative contracts		0.7			0.1				1			(0.3		)
Total unrealized gains (losses) on commodity derivative contracts		161.5			(52.7		)		64.8			(59.0		)
Total realized and unrealized gains (losses) on commodity derivative contracts		$	154.4		$	(25.8	)		$	(11.1	)	$	50
Realized gains (losses) on interest rate swaps
Realized losses on interest rate swaps		$	(1.3	)	$	(0.6	)		$	(3.2	)	$	(1.9	)
Unrealized gains (losses) on interest rate swaps
Unrealized gains (losses) on interest rate swaps		2.6			(1.4		)		1.1			3.5
Total realized and unrealized gains (losses) on interest rate swaps		$	1.3		$	(2.0	)		$	(2.1	)	$	1.6
Total net realized gains (losses) on derivative contracts		$	(8.4	)	$	26.3			$	(79.1	)	$	107.1
Total net unrealized gains (losses) on derivative contracts		164.1			(54.1		)		65.9			(55.5		)
Grand Total		$	155.7		$	(27.8	)		$	(13.2	)	$	51.6

Restructuring_Costs

Restructuring Costs	9 Months Ended
	Sep. 30, 2014
Restructuring Costs [Abstract]	'
Restructuring Costs	'
	Restructuring Costs
	In December 2013, QEP announced its plan to pursue a separation of its midstream business, QEP Field Services. In connection with this announcement, 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 occurs, 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 expects to recognize $10.3 million of costs under this retention plan and has $7.9 million accrued since inception as of September 30, 2014. During the three and nine months ended September 30, 2014, $2.3 million and $7.1 million, respectively, was accrued under this retention plan, and are included in "Discontinued operations, net of income tax" on the Condensed Consolidated Statements of Operations.
	During 2012, QEP began incurring costs related to the closure of its Oklahoma City office and the subsequent consolidation of its Southern Region operations into a single regional office located in Tulsa. Additionally, during 2012, QEP began incurring additional restructuring and reorganization costs related to consolidating various corporate and accounting functions to the Denver corporate headquarters. The creation of one office for QEP’s Southern Region as well as the consolidation of corporate and accounting functions increased efficiency, team-based collaboration and organizational productivity. As part of the reorganization, QEP incurred costs associated with the severance, retention and relocation of employees, additional pension expenses, exit costs associated with the termination of operating leases arising from office space that will no longer be utilized by the Company and other expenses. All restructuring costs related to the 2012 office consolidations and continued operations were incurred and settled by December 31, 2013.
	The following table summarizes, by line of business, each major type of restructuring cost expected to be incurred and the total amounts recorded in "General and administrative" expense on the Condensed Consolidated Statements of Operations for the respective periods indicated:
		Total Restructuring Costs
		Total Expected to be Incurred		Recognized in Income
				Period from Inception to September 30, 2014		Three Months Ended September 30,				Nine Months Ended September 30,
						2014		2013		2014		2013
	Continuing Operations:	(in millions)
	QEP Energy
	One-time termination benefits	$	3.3	$	3.3	$	—	$	0.1	$	—	$	0.4
	Retention & relocation expense	3.7		3.7		—		0.1		—		0.3
	Lease termination costs	0.6		0.6		—		—		—		—
	Total restructuring costs	$	7.6	$	7.6	$	—	$	0.2	—		0.7
	QEP Marketing & Other
	One-time termination benefits	$	0.3	$	0.3	$	—	$	0.1	$	—	$	0.1
	Total restructuring costs	$	0.3	$	0.3	$	—	$	0.1	$	—	$	0.1
	Total QEP
	One-time termination benefits	$	3.6	$	3.6	$	—	$	0.2	$	—	$	0.5
	Retention & relocation expense	3.7		3.7		—		0.1		—		0.3
	Lease termination costs	0.6		0.6		—		—		—		—
	Total restructuring costs	$	7.9	$	7.9	$	—	$	0.3	$	—	$	0.8

Debt

Debt	9 Months Ended
	Sep. 30, 2014
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, term loan and senior notes, consisted of the following:
		September 30,			December 31,
		2014			2013
		(in millions)
	QEP's revolving credit facility due 2016	$	297.5		$	480
	Term loan due 2017	600			300
	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	3,119.30			3,001.80
	Less unamortized discount	(3.8		)	(4.3		)
	Total long-term debt outstanding	$	3,115.50		$	2,997.50
	Of the total debt outstanding on September 30, 2014, amounts outstanding under QEP's revolving credit facility due August 25, 2016, QEP's term loan due April 18, 2017, the 6.05% Senior Notes due September 1, 2016, and the 6.80% Senior Notes due April 1, 2018, will mature within the next five years.
	Credit Facilities
	QEP's Credit Facility
	QEP’s unsecured revolving credit facility, which matures in August 2016, provides for loan commitments of $1.5 billion from a group of financial institutions. The credit facility provides for borrowings at short-term interest rates and contains customary covenants and restrictions. The credit facility also contains an accordion provision that would allow for the amount of the facility to be increased to $2.0 billion and a provision whereby the maturity can be extended for up to two additional one-year periods, with the agreement of the lenders.
	During the nine months ended September 30, 2014 and 2013, QEP’s weighted-average interest rate on borrowings from its credit facility was 2.22% and 2.56%, respectively. At September 30, 2014 and December 31, 2013, QEP was in compliance with the covenants under the credit agreement. At September 30, 2014, there was $297.5 million outstanding and $3.8 million of letters of credit issued under the credit facility.
	Term Loan
	QEP's $600.0 million unsecured term loan facility provides for borrowings at short-term interest rates and contains covenants, restrictions, and interest rates that are substantially the same as QEP’s revolving credit facility. The term loan matures in April 2017, and the maturity date may be extended one year with the agreement of the lenders. In conjunction with the Permian Basin Acquisition, QEP borrowed an incremental $300.0 million available under the facility and increased total borrowings under the term loan to $600.0 million. There were no changes to the maturity date, pricing or covenants in the credit agreement. QEP incurred $1.1 million of debt issuance costs associated with the new term loan issuance.
	During the nine months ended September 30, 2014 and 2013, QEP’s weighted-average interest rate on borrowings from the term loan was 2.26% and 2.23%, respectively. At September 30, 2014 and December 31, 2013, QEP was in compliance with the covenants under the term loan credit agreement.
	Senior Notes
	At September 30, 2014, 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	9 Months Ended
	Sep. 30, 2014
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 can be reasonably estimated 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 could 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, and/or the ongoing discovery and development of information important to the matter. QEP's litigation loss contingencies are discussed below. Except for the Rocky Mountain Resources, the Questar Gas Company, and the XTO Energy Inc. matters discussed below, QEP is unable to estimate reasonably possible losses (in excess of recorded accruals, if any) for these 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.
	Environmental Claims
	In October 2009, QEP received a cease and desist order from the U.S. Army Corps of Engineers (COE) to refrain from unpermitted work resulting in the discharge of dredged and/or fill material into waters of the United States at three sites located in Caddo and Red River Parishes, Louisiana. Region 6 of the U.S. Environmental Protection Agency (EPA) has assumed lead responsibility for enforcement of the cease and desist order and any possible future orders for the removal of unauthorized fills and/or civil penalties under the Clean Water Act. On June 28, 2013, the EPA issued to QEP an Administrative Complaint for the alleged violations. QEP and the EPA reached an agreement to settle the alleged violations through an Administrative Order, under the terms of which QEP paid an administrative penalty of $0.2 million. The Administrative Order is final. In 2012, QEP completed a field audit, which identified 112 additional instances affecting approximately 90 acres where work may have been conducted in violation of the Clean Water Act. QEP has disclosed each of these instances to the EPA under the EPA's Audit Policy (to reduce penalties) and to the COE. QEP is working with the EPA and the COE to resolve these matters, which will require the Company to undertake certain mitigation and permitting activities, and may require QEP to pay a monetary penalty.
	In July 2010, QEP received a Notice of Potential Penalty (NOPP) from the Louisiana Department of Environmental Quality (LDEQ) regarding the assumption of ownership and operatorship of a single facility in Louisiana prior to transferring the facility's air quality permit. In 2011, QEP completed an internal audit, which identified 424 facilities in Louisiana for which QEP both failed to submit a complete permit application and to receive approval from the department prior to construction, modification, or operation. QEP has corrected and disclosed all instances of non-compliance to the LDEQ and is working with the department to resolve the NOPP. The LDEQ has assumed lead responsibility for enforcement of the NOPP, and may require the Company to pay a monetary penalty.
	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 attaches to 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. On October 8, 2014, Rocky Mountain, Ultra Resources, Inc. (Ultra) and Lance Oil and Gas Company (Lance) reached a confidential agreement resolving the application of the 4% override as to production by Ultra and Lance and filed a stipulation to dismiss the lawsuit with respect to Ultra and Lance. The stipulation has no effect on the claims asserted against QEP or Wexpro. There are several affirmative defenses that remain to be tried and QEP continues to vigorously defend the case. A trial date is scheduled for February 2015. QEP estimates, based in part on damages asserted by the plaintiff, that the range of reasonably possible outcomes is no loss to a loss of approximately $20.0 million.
	Gatti et al v. State of Louisiana et al, 589,350, 19th JDC, Parish of East Baton Rouge, Louisiana. In this putative class action arising out of the unitization practices and orders of the Louisiana Commissioner of Conservation (Commissioner), plaintiffs seek to represent a class of all Haynesville Shale mineral owners (alleged to be over 50,000 in number) against the Commissioner and all Haynesville Shale unit operators. Plaintiffs filed their complaint on April 8, 2010, and claim that the Commissioner exceeded his statutory authority in creating and perpetuating units larger than the area that can be efficiently and economically drained by a single well. They seek declaratory relief that would nullify all such improper orders, along with an unspecified amount of monetary damages from the unit operators sufficient to compensate the putative class members for the alleged dilution of their true interest in unit production as a result of "oversized" units and the "cloud on title" caused by having excessive and improperly sized units purport to hold their mineral leases via unit operations. All defendants filed exceptions to the plaintiffs' petition on the primary ground that plaintiffs had failed to comply with the exclusive statutory judicial review procedure (Louisiana Revised Statutes 30:12), which the trial court granted, dismissing the action in its entirety. On January 15, 2014, the Louisiana First Circuit Court of Appeal reversed and reinstated plaintiffs' claims. Defendants asked for review by the Louisiana Supreme Court and on August 25, 2014, the Supreme Court reversed the Court of Appeals and dismissed the plaintiffs’ claim without prejudice as originally ordered by the District Court.
	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. 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 are ongoing.
	Litigation related to discontinued operations:
	In accordance with the terms of the Membership Interest Purchase Agreement, dated as of October 19, 2014, by and between QEP Field Services and Tesoro, Tesoro has agreed to indemnify QEP Field Services and its affiliates for any liabilities or claims associated with Questar Gas Company and XTO Energy litigation. Therefore, following the closing of the Tesoro transaction, QEP believes it will have no significant exposure to liability for the following litigation matters.
	Questar Gas Company v. QEP Field Services Company, Civil No. 120902969, Third Judicial District Court, State of Utah. QEP Field Services' former affiliate, Questar Gas Company (QGC), filed this complaint in state court in Utah on May 1, 2012, asserting claims for breach of contract, breach of implied covenant of good faith and fair dealing, and an accounting and declaratory judgment related to a 1993 gathering agreement (the 1993 Agreement) executed when the parties were affiliates. Specific monetary damages are not asserted. Under the 1993 Agreement, certain of QEP Field Services' systems provide gathering services to QGC charging an annual gathering rate which is based on the cost of service. QGC is disputing the annual calculation of the gathering rate. The annual gathering rate has been calculated in the same manner under the 1993 Agreement since it was amended in 1998, without any prior objection or challenge by QGC. At the closing of the QEP Midstream initial public offering (IPO), the assets and agreement discussed above were assigned to QEP Midstream. QGC amended its complaint to add QEP Midstream as a defendant in the litigation. QEP agreed to indemnify QEP Midstream for costs, expenses and other losses incurred by QEP Midstream in connection with the QGC dispute, subject to certain limitations, as set forth in the Omnibus Agreement entered into between QEP Midstream and QEP in connection with the IPO. QGC netted the disputed amount from its monthly payments of the gathering fees to QEP Field Services and has continued to net such amounts from its monthly payment to QEP Midstream. As of September 30, 2014, QEP Midstream has deferred revenue of $13.2 million, which was included in "Current liabilities of discontinued operations held for sale" on the Condensed Consolidated Balance Sheet, related to the QGC disputed amount. QEP Field Services has filed counterclaims seeking damages and a declaratory judgment relating to its gathering services under the 1993 Agreement.
	XTO Energy Inc. v. QEP Field Services Company, Civil No. 140900709, Third Judicial District Court, State of Utah. XTO Energy Inc. (XTO), filed this complaint in Utah state court on January 30, 2014, asserting claims for breach of contract, breach of implied covenant of good faith and fair dealing, unjust enrichment and an accounting related to a 2010 gas processing agreement (the Agreement). QEP Field Services processes XTO’s natural gas on a firm basis under the Agreement. The Agreement requires QEP Field Services to transport, fractionate and market XTO’s natural gas liquids derived from XTO’s processed gas. XTO is seeking monetary damages related to QEP Field Services allocation of charges related to XTO’s share of natural gas liquid transportation, fractionation and marketing costs associated with shortfalls in contractual firm processing volumes.

EquityBased_Compensation

Equity-Based Compensation	9 Months Ended
	Sep. 30, 2014
Share-based Compensation [Abstract]	'
Equity-Based Compensation	'
	Equity-Based Compensation
	QEP issues stock options and restricted shares under its Long-Term Stock Incentive Plan (LTSIP) and awards performance-based share units under its Cash Incentive Plan (CIP) to certain officers, employees, and non-employee directors. QEP recognizes expense over time as the stock options, restricted shares, and performance-based share units vest. Deferred equity-based compensation is included in additional paid-in capital in the Condensed Consolidated Balance Sheets. There were 10.9 million shares available for future grants under the LTSIP at September 30, 2014. Equity-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 Long Term Incentive Plan) are reflected in "Discontinued operations, net of income tax". During the three and nine months ended September 30, 2014 for continuing operations, QEP recognized $6.4 million and $17.7 million in total compensation expense related to equity-based compensation compared to $5.5 million and $17.9 million during the three and nine months ended September 30, 2013, respectively. During the three and nine months ended September 30, 2014 for discontinued operations, QEP recognized $0.9 million and $3.0 million in total compensation expense related to equity-based compensation compared to $1.3 million and $2.1 million during the three and nine months ended September 30, 2013, respectively.
	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:
		Stock Option Assumptions
		Nine Months Ended
		September 30, 2014
	Weighted-average grant-date fair value of awards granted during the period	$	10.11
	Weighted-average risk-free interest rate	1.31		%
	Weighted-average expected price volatility	37.1		%
	Expected dividend yield	0.25		%
	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, 2013	1,794,187			$	27.9
	Granted	282,236			31.67
	Exercised	(65,366	)		22.24
	Forfeited	(14,842	)		30.53
	Outstanding at September 30, 2014	1,996,215			$	28.6	3.43	$	6.3
	Options Exercisable at September 30, 2014	1,452,138			$	27.71	2.56	$	6.2
	Unvested Options at September 30, 2014	544,077			$	30.97	5.75	$	0.2
	The total intrinsic value (the difference between the market price at the exercise date and the exercise price) of options exercised was $0.6 million and $4.2 million during the nine months ended September 30, 2014 and 2013, respectively. As of September 30, 2014, $2.7 million of unrecognized compensation cost related to stock options granted under the LTSIP is expected to be recognized over a weighted-average period of 2.05 years. During the nine months ended September 30, 2014, QEP received $1.5 million in cash upon the exercise of stock options during 2014.
	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 nine months ended September 30, 2014 and 2013 was $20.2 million and $18.4 million, respectively. The weighted average grant-date fair value of restricted stock was $31.82 per share and $30.03 per share for the nine months ended September 30, 2014 and 2013, respectively. As of September 30, 2014, $18.2 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 2.26 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, 2013	1,388,953			$	30.96
	Granted	968,118			31.82
	Vested	(637,677	)		31.63
	Forfeited	(116,238	)		30.96
	Unvested balance at September 30, 2014	1,603,156			$	31.22
	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 delivered in cash at the end of the performance period. The weighted average grant-date fair value of the performance share units was $31.71 per share and $30.12 per share for the nine months ended September 30, 2014 and 2013, respectively. As of September 30, 2014, $3.2 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 2.07 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, 2013	480,660			$	32.33
	Granted	252,161			31.71
	Vested and paid out	(55,659	)		39.07
	Canceled (1)	(51,361	)		39.07
	Forfeited	(22,416	)		30.47
	Unvested balance at September 30, 2014	603,385			$	30.92
	____________________________
	(1)	Represents units that were not paid out due to not meeting performance targets. Payout of the performance share units is dependent upon the Company’s total shareholder return compared to a group of its peers over a three-year period.

Employee_Benefits

Employee Benefits	9 Months Ended
	Sep. 30, 2014
Compensation and Retirement Disclosure [Abstract]	'
Employee Benefits	'
	Employee Benefits
	The Company maintains closed, defined-benefit pension and postretirement medical plans. QEP's pension plans include a qualified and a nonqualified retirement plan. The Company's postretirement medical plan is unfunded and provides certain health care and life insurance benefits for certain retired employees. During the nine months ended September 30, 2014, the Company made contributions of $8.1 million to its funded qualified pension plan and $4.4 million to its unfunded nonqualified retirement plan. Contributions to funded qualified plans increase plan assets while contributions to unfunded nonqualified plans are used to fund current benefit payments. During the remainder of 2014, the Company expects to contribute $0.6 million to its unfunded nonqualified pension plans and $0.1 million for retiree health care and life insurance benefits. No additional funding in 2014 is expected for its funded qualified pension plan. During the three and nine months ended September 30, 2014 for continuing operations, QEP recognized $1.4 million and $5.5 million, respectively, in recurring employee benefit expense compared to $2.3 million and $7.6 million, respectively, during the three and nine months ended September 30, 2013. During the three and nine months ended September 30, 2014 for discontinued operations, QEP recognized $0.4 million and $1.4 million, respectively, in recurring employee benefit expense compared to $0.7 million and $1.9 million, respectively, during the three and nine months ended September 30, 2013.
	During the nine months ended September 30, 2014, the Company recognized a $2.4 million expense on curtailment and a $0.3 million expense for special termination benefits in connection with the second quarter 2014 property sales in the Midcontinent area (see Note 3 - Acquisitions and Divestitures). A curtailment is recognized immediately when there is a significant reduction in, or an elimination of, defined benefit accruals for present employees' future services. These expenses are included within “Net gain (loss) from asset sales” on the Condensed Consolidated Statement of Operations for the nine months ended September 30, 2014.
	The following table sets forth the Company’s pension and postretirement benefits net periodic benefit costs:
		Pension
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in millions)
	Service cost	$	0.6		$	0.7		$	2		$	2.6
	Interest cost	1.2			1.2			4			3.7
	Expected return on plan assets	(1.4		)	(0.9		)	(3.8		)	(2.9		)
	Amortization of prior service costs (1)	1.1			1.2			3.6			3.7
	Amortization of actuarial losses (1)	0.2			0.5			0.6			1.7
	Curtailment cost	—			—			2			—
	Special termination benefits	—			—			0.3			—
	Periodic expense	$	1.7		$	2.7		$	8.7		$	8.8
	____________________________
	(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						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in millions)
	Service cost	$	—		$	0.1		$	—		$	0.1
	Interest cost	—			—			0.2			0.2
	Amortization of prior service costs (1)	0.1			0.1			0.3			0.3
	Recognized net actuarial loss	—			0.1			—			0.1
	Curtailment cost	—						0.4			—
	Periodic expense	$	0.1		$	0.3		$	0.9		$	0.7
	____________________________
	(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	9 Months Ended
	Sep. 30, 2014
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 marketing, the Haynesville Gathering System, an underground storage reservoir, and corporate (QEP Marketing & 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.
	The following table is a summary of operating results for the three months ended September 30, 2014, by line of business:
		QEP Energy			QEP Marketing			Eliminations			QEP
					& Other						Consolidated
		(in millions)
	Revenues
	From unaffiliated customers	$	652.9		$	257.1		$	—		$	910
	From affiliated customers	—			417.8			(417.8		)	—
	Total revenues	652.9			674.9			(417.8		)	910
	Operating expenses
	Purchased gas, oil and NGL expense	32.8			668.3			(412.7		)	288.4
	Lease operating expense	61.1			—			—			61.1
	Gas, oil and NGL transportation and other handling costs	75.2			—			(4.1		)	71.1
	Gathering and other expense	—			1.4			—			1.4
	General and administrative	44.3			6.1			(1.0		)	49.4
	Production and property taxes	59.3			0.1			—			59.4
	Depreciation, depletion and amortization	249			2.4			—			251.4
	Impairment and exploration expense	0.9			—			—			0.9
	Total operating expenses	522.6			678.3			(417.8		)	783.1
	Net (loss) gain from asset sales	(11.9		)	0.1						(11.8		)
	Operating income (loss)	118.4			(3.3		)	—			115.1
	Realized and unrealized gains on derivative contracts	154.1			1.6			—			155.7
	Interest and other income	3.9			56.6			(56.3		)	4.2
	Income from unconsolidated affiliates	0.1			—			—			0.1
	Interest expense	(57.0		)	(40.8		)	56.3			(41.5		)
	Income before income taxes	219.5			14.1			—			233.6
	Income tax provision	(72.7		)	(7.2		)	—			(79.9		)
	Income from continuing operations	146.8			6.9			—			153.7
	Net income from discontinued operations, net of income tax	—			—			—			17.4
	Net income attributable to QEP	$	146.8		$	6.9		$	—		$	171.1
	The following table is a summary of operating results for the three months ended September 30, 2013, by line of business:
		QEP Energy			QEP Marketing			Eliminations			QEP
					& Other						Consolidated
		(in millions)
	Revenues
	From unaffiliated customers	$	538.5		$	181		$	—		$	719.5
	From affiliated customers	—			265.6			(265.6		)	—
	Total revenues	538.5			446.6			(265.6		)	719.5
	Operating expenses
	Purchased gas, oil and NGL expense	39.2			438.2			(257.9		)	219.5
	Lease operating expense	43.5			—			—			43.5
	Gas, oil and NGL transportation and other handling costs	65.1			—			(6.5		)	58.6
	Gathering and other expense	—			2.1			—			2.1
	General and administrative	33.5			8.4			(1.2		)	40.7
	Production and property taxes	40.4			0.2			—			40.6
	Depreciation, depletion and amortization	236			2.4			—			238.4
	Impairment and exploration expense	5.6						—			5.6
	Total operating expenses	463.3			451.3			(265.6		)	649
	Net gain from assets sales	12.8			—			—			12.8
	Operating income (loss)	88			(4.7		)	—			83.3
	Realized and unrealized losses on derivative contracts	(25.6		)	(2.2		)	—			(27.8		)
	Interest and other income	2.6			52.2			(48.7		)	6.1
	Income from unconsolidated affiliates	—			—			—			—
	Interest expense	(49.2		)	(40.9		)	48.7			(41.4		)
	Income before income taxes	15.8			4.4			—			20.2
	Income tax (provision) benefit	(6.2		)	(1.9		)	—			(8.1		)
	Income from continuing operations	9.6			2.5			—			12.1
	Net income from discontinued operations, net of income tax	—			—			—			25.2
	Net income attributable to QEP	$	9.6		$	2.5		$	—		$	37.3
	The following table is a summary of operating results for the nine months ended September 30, 2014, by line of business:
		QEP Energy			QEP Marketing			Eliminations			QEP
					& Other						Consolidated
	(in millions)
Revenues
From unaffiliated customers	$	1,953.30		$	661.4		$	—		$	2,614.70
From affiliated customers	—			1,132.90			(1,132.9		)	—
Total revenues	1,953.30			1,794.30			(1,132.9		)	2,614.70
Operating expenses
Purchased gas, oil and NGL expense	120.9			1,771.60			(1,117.0		)	775.5
Lease operating expense	177			—			—			177
Gas, oil and NGL transportation and other handling costs	211.8			—			(13.3		)	198.5
Gathering and other expense	—			4.8			—			4.8
General and administrative	132			17.6			(2.6		)	147
Production and property taxes	159.8			1			—			160.8
Depreciation, depletion and amortization	704.7			7.8			—			712.5
Impairment and exploration expense	8.3			—			—			8.3
Total operating expenses	1,514.50			1,802.80			(1,132.9		)	2,184.40
Net loss from asset sales	(210.3		)	—			—			(210.3		)
Operating income (loss)	228.5			(8.5		)	—			220
Realized and unrealized losses on derivative contracts	(9.7		)	(3.5		)	—			(13.2		)
Interest and other income	7.4			162			(161.6		)	7.8
Income from unconsolidated affiliates	0.2			—			—			0.2
Interest expense	(162.5		)	(127.5		)	161.6			(128.4		)
Income before income taxes	63.9			22.5			—			86.4
Income tax provision	(14.6		)	(11.5		)	—			(26.1		)
Income from continuing operations	49.3			11			—			60.3
Net income from discontinued operations, net of income tax	—			—			—			58.2
Net income attributable to QEP	$	49.3		$	11		$	—		$	118.5
The following table is a summary of operating results for the nine months ended September 30, 2013, by line of business:
	QEP Energy			QEP Marketing			Eliminations			QEP
				& Other						Consolidated
	(in millions)
Revenues
From unaffiliated customers	$	1,575.20		$	489.6		$	—		$	2,064.80
From affiliated customers	—			686			(686.0		)	—
Total revenues	1,575.20			1,175.60			(686.0		)	2,064.80
Operating expenses
Purchased gas, oil and NGL expense	159.8			1,150.50			(660.0		)	650.3
Lease operating expense	130.2			—			—			130.2
Gas, oil and NGL transportation and other handling costs	180.8			—			(22.3		)	158.5
Gathering and other expense	—			6.4			—			6.4
General and administrative	100.2			20.3			(3.7		)	116.8
Production and property taxes	112.7			1			—			113.7
Depreciation, depletion and amortization	712.1			7.2			—			719.3
Impairment and exploration expense	13.5			—			—			13.5
Total operating expenses	1,409.30			1,185.40			(686.0		)	1,908.70
Net gain from asset sales	113.4			—			—			113.4
Operating income (loss)	279.3			(9.8		)	—			269.5
Realized and unrealized gains on derivative contracts	49.6			2			—			51.6
Interest and other income	7.5			158.4			(143.2		)	22.7
Interest expense	(143.4		)	(124.5		)	143.2			(124.7		)
Income before income taxes	193			26.1			—			219.1
Income tax provision	(71.1		)	(11.4		)	—			(82.5		)
Income for continuing operations	121.9			14.7			—			136.6
Net income from discontinued operations, net of income tax	—			—			—			74.8
Net income attributable to QEP	$	121.9		$	14.7		$	—		$	211.4

Subsequent_Event

Subsequent Event	9 Months Ended
	Sep. 30, 2014
Subsequent Event [Abstract]	'
Subsequent Events	'
	Subsequent Events
	On October 19, 2014, QEP announced that its wholly owned subsidiary, QEP Field Services, had entered into a definitive agreement to sell its midstream business, including its ownership interest in QEP Midstream, to Tesoro in an all cash transaction valued at $2.5 billion, including $230.0 million to refinance debt at QEP Midstream. QEP will retain ownership of QEP Field Services’ Haynesville Gathering System. The transaction is subject to customary closing conditions and regulatory approvals and is expected to close in the fourth quarter of 2014.
	On October 31, 2014, QEP entered into two purchase and sale agreements to divest non-core properties in southern Oklahoma for an aggregate sale price of $108 million, subject to customary purchase price adjustments. The aggregate net book value of the properties being sold is approximately $37 million as of September 30, 2014. Any gain or loss on the sale recorded by the Company will be determined based upon the final purchase price, which is subject to customary purchase price adjustments. The Company expects to close the transactions by year end.

Basis_of_Presentation_of_Inter1

Basis of Presentation of Interim Consolidated Financial Statements (Policies)	9 Months Ended
	Sep. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
New accounting pronouncements	'
	New accounting pronouncements
	In April 2014, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2014-08, Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity, which broadened the reporting of discontinued operations to a component of an entity that has operations and cash flows that can be clearly distinguished from the rest of the entity. Under this guidance, to be a discontinued operation, a component or group of components must represent a strategic shift that has (or will have) a major effect on an entity's operations and financial results. The amendments are effective prospectively for reporting periods beginning on or after December 15, 2014 and early adoption is permitted. The Company has chosen to early adopt ASU 2014-08 and implemented the amendments in the quarter ended September 30, 2014.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606), which seeks to provide a single, comprehensive revenue recognition model for all contracts with customers to improve comparability within industries, across industries, and across capital markets. The revenue standard contains principles that an entity will apply to determine the measurement of revenue and timing of when it is recognized. The underlying principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. The amendments are effective prospectively for reporting periods beginning after December 15, 2016 and early adoption is not permitted. The Company is currently assessing the impact on the Company's consolidated financial statements.
	In August 2014, the FASB issued ASU No. 2014-15, Presentation of Financial Statements-Going Concern (Topic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. This guidance provides additional information to guide management's evaluation of whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date that the financial statements are issued. The update is effective for annual periods beginning on or after December 15, 2016. The Company is currently evaluating the impact of this standard on its financial statements.

Acquisitions_Divestitures_Tabl

Acquisitions & Divestitures (Tables)	9 Months Ended
	Sep. 30, 2014
Business Acquisition, Pro Forma Information, Nonrecurring Adjustment [Line Items]	'
Business Combination, Separately Recognized Transactions [Table Text Block]	'
		As of September 30, 2014
		(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
Business Acquisition, Pro Forma Information [Table Text Block]	'
			Three Months Ended				Nine Months Ended
			September 30,				September 30,
			2013		2013		2014		2014		2013		2013
			Actual		Pro forma		Actual		Pro forma		Actual		Pro forma
							(in millions, except per share data)
	Revenues		$	719.5	$	776.5	$	2,614.70	$	2,640.80	$	2,064.80	$	2,195.40
	Net income (loss) attributable to QEP		37.3		54.2		118.5		125.5		211.4		240.4
	Earnings per common share attributable to QEP
	Basic		$	0.21	$	0.3	$	0.66	$	0.7	$	1.18	$	1.34
	Diluted		0.21		0.3		0.66		0.7		1.18		1.34

Discontinued_Operations_Tables

Discontinued Operations (Tables)	9 Months Ended
	Sep. 30, 2014
Discontinued Operations and Disposal Groups [Abstract]	'
Income Statement Impact Of Discontinued Operations [Table Text Block]	'
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in millions, except per share amounts)
	REVENUES
	NGL sales	$	28.8		$	23.6		$	94.6		$	70.6
	Other revenue	43.1			44.2			119.9			126.4
	Purchased gas, oil and NGL sales(1)	(11.9		)	(14.4		)	(38.5		)	(41.5		)
	Total Revenues	60			53.4			176			155.5
	OPERATING EXPENSES
	Purchased gas, oil and NGL expense(1)	(12.4		)	(14.4		)	(39.5		)	(41.4		)
	Lease operating expense(1)	(1.7		)	(0.8		)	(4.8		)	(2.6		)
	Natural gas, oil and NGL transport & other handling costs(1)	(10.6		)	(21.7		)	(40.1		)	(53.0		)
	Gathering, processing, and other	22.7			20.3			69.8			60.1
	General and administrative	11.1			8.6			34.3			19.4
	Production and property taxes	2.1			1.8			6.1			4
	Depreciation, depletion and amortization	14.3			14.7			43.1			37.8
	Total Operating Expenses	25.5			8.5			68.9			24.3
	Net loss from asset sales	—			(0.1		)	(0.1		)	(0.5		)
	OPERATING INCOME	34.5			44.8			107			130.7
	Interest income and other loss	—			(2.1		)	—			(13.7		)
	Income from unconsolidated affiliates	1.1			0.8			4.4			3.7
	Interest expense	(1.5		)	(0.3		)	(2.8		)	2.3
	INCOME FROM DISCONTINUED OPERATIONS BEFORE INCOME TAXES (2)	34.1			43.2			108.6			123
	Income taxes	(9.9		)	(14.2		)	(32.8		)	(42.4		)
	NET INCOME FROM DISCONTINUED OPERATIONS	24.2			29			75.8			80.6
	Net income attributable to noncontrolling interest	(6.8		)	(3.8		)	(17.6		)	(5.8		)
	NET INCOME FROM DISCONTINUED OPERATIONS, NET OF INCOME TAX	$	17.4		$	25.2		$	58.2		$	74.8
Assets And Liabilities Of Discontinued Operations [Table Text Block]	'
		September 30,			December 31,
		2014			2013
	Cash and cash equivalents	$	27.1		$	18.1
	Accounts receivable, net	71.8			53.9
	Income taxes receivable	—			38.4
	Deferred income taxes - current	7			2.7
	Prepaid expenses and other	32.4			8.9
	Current assets of discontinued operations held for sale	$	138.3		$	122
	Property, Plant and Equipment
	Midstream field services	$	1,550.50		$	1,500.80
	Material and supplies	6.5			4.8
	Total Property, Plant and Equipment	1,557.00			1,505.60
	Less Accumulated Depreciation, Depletion and Amortization
	Midstream field services	(422.2		)	(381.6		)
	Net Property, Plant and Equipment	1,134.80			1,124.00
	Investment in unconsolidated affiliates	35.9			39
	Other noncurrent assets	3.5			4.7
	Noncurrent assets of discontinued operations held for sale	$	1,174.20		$	1,167.70
	Accounts payable and accrued expenses	$	85.6		$	74.1
	Accrued income taxes	70.2			—
	Production and property taxes	5.4			1.2
	Interest payable	0.4			—
	Current liabilities of discontinued operations held for sale	$	161.6		$	75.3
	Long-term debt	$	230		$	—
	Deferred income taxes	126.5			195.7
	Asset retirement obligations	29.9			28.5
	Other long-term liabilities	15.6			14.1
	Noncurrent liabilities of discontinued operations held for sale	$	402		$	238.3

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2014
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		Nine Months Ended
		September 30,		September 30,
		2014	2013	2014	2013
		(in millions)
	Weighted-average basic common shares outstanding	180.1	179.3	180	179.2
	Potential number of shares issuable upon exercise of in-the-money stock options under the Long-term Stock Incentive Plan	0.5	0.2	0.4	0.2
	Average diluted common shares outstanding	180.6	179.5	180.4	179.4

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2014
Asset Retirement Obligation [Abstract]	'
Asset retirement obligations roll forward	'
		Asset Retirement Obligations
		2014
		(in millions)
	ARO liability at January 1, (1)	$	165.1
	Accretion	4.9
	Additions(2)	15.5
	Revisions	(0.3		)
	Liabilities settled(3)	(22.0		)
	ARO liability at September 30,(4)	$	163.2

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair value of financial assets and liabilities	'
	The fair value measurements of financial assets and liabilities at September 30, 2014, are shown in the table below:
		Fair Value Measurements
		September 30, 2014
		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)
	Financial Assets
	Commodity derivative instruments - short-term	$	—	$	36.6	$	—	$	(4.0	)	$	32.6
	Commodity derivative instruments - long-term	—		9.6		—		(0.4		)	9.2
	Interest rate swaps - long-term	—		3.5		—		—			3.5
	Total financial assets	$	—	$	49.7	$	—	$	(4.4	)	$	45.3
	Financial Liabilities
	Commodity derivative instruments - short-term	$	—	$	4.2	$	—	$	(4.0	)	$	0.2
	Interest rate swaps - short-term	—		4.3		—		—			4.3
	Commodity derivative instruments - long-term	—		0.6		—		(0.4		)	0.2
	Total financial liabilities	$	—	$	9.1	$	—	$	(4.4	)	$	4.7
	____________________________
	(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 fair value of financial assets and liabilities at December 31, 2013, is shown in the table below:
		Fair Value Measurements
		31-Dec-13
		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)
	Financial Assets
	Commodity derivative instruments - short-term	$	—	$	5.5	$	—	$	(5.3	)	$	0.2
	Commodity derivative instruments - long-term	—		0.4		—		—			0.4
	Interest rate swaps - long-term	—		0.6		—		—			0.6
	Total financial assets	$	—	$	6.5	$	—	$	(5.3	)	$	1.2
	Financial Liabilities
	Commodity derivative instruments - short-term	$	—	$	29.4	$	—	$	(5.3	)	$	24.1
	Interest rate swaps - short-term	—		2.6		—		—			2.6
	Total financial liabilities	$	—	$	32	$	—	$	(5.3	)	$	26.7
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
		September 30, 2014				December 31, 2013
		(in millions)
	Financial assets
	Cash and cash equivalents	$	—	$	—	$	11.9	$	11.9
	Financial liabilities
	Checks outstanding in excess of cash balances	$	36.8	$	36.8	$	109.1	$	109.1
	Long-term debt	$	3,115.50	$	3,209.30	$	2,997.50	$	3,034.90

Derivative_Contracts_Tables

Derivative Contracts (Tables)	9 Months Ended
	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Volumes and Average Prices	'
	Year		Type of Contract		Index	Total			Average Swap price per unit
						Volumes
						(in millions)
	Gas sales					(MMBtu)
	2014		SWAP		NYMEX	7.4			$	4.22
	2014		SWAP		IFNPCR	20.2			$	4.08
	2015		SWAP		NYMEX	25.6			$	4.14
	2015		SWAP		IFNPCR	11			$	4.06
	Oil sales					(Bbls)
	2014		SWAP		NYMEX WTI	3.1			$	93.54
	2015		SWAP		NYMEX WTI	7.7			$	90.04
	2015		SWAP		BRENT ICE	0.4			$	104.95
	2016		SWAP		NYMEX WTI	0.4			$	90
	The following table sets forth QEP Energy's oil basis swaps as of September 30, 2014:
	Year		Index		Index Less Differential	Total Volumes			Weighted Average Differential
						(in millions)
	Oil basis swaps					(Bbls)
	2014		NYMEX WTI		ICE Brent	0.2			$	13.78
	2014		NYMEX WTI		LLS	0.2			$	4.03
	2015		NYMEX WTI		LLS	0.1			$	4.03
	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 September 30, 2014:
	Year		Type of Contract		Index	Total			Average Swap price
						Volumes			per MMBtu
						(in millions)
	Gas sales					(MMBtu)
	2014		SWAP		IFNPCR	1.4			$	4.03
	2015		SWAP		IFNPCR	2.5			4.07
	Gas purchases					(MMBtu)
	2014		SWAP		IFNPCR	0.6			$	3.86
Schedule of Interest Rate Derivatives	'
	Notional amount		Type of Contract		Maturity	Fixed Rate Paid		Variable Rate Received
	(in millions)
	$300.00		Swap		Mar-17	1.07%		One-month LIBOR
	$300.00		Swap		Mar-17	0.86%		One-month LIBOR
	$600.00					0.96%
Fair Values of Derivatives by Balance Sheet Location	'
	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		September 30,			31-Dec-13				September 30,			31-Dec-13
		line item		2014							2014
				(in millions)							(in millions)
	Current:
	Commodity	Fair value of derivative contracts		$	36.6		$	5.5			$	4.2		$	29.4
	Interest rate swaps	Fair value of derivative contracts		—			—				4.3			2.6
	Long-term:
	Commodity	Fair value of derivative contracts		9.6			0.4				0.6			—
	Interest rate swaps	Fair value of derivative contracts		3.5			0.6				—			—
	Total derivative instruments			$	49.7		$	6.5			$	9.1		$	32
Effects of Derivative Transactions	'
	The effects of the change in fair value and settlement of QEP's derivative contracts recorded in "Realized and unrealized losses on derivative contracts" on the Condensed Consolidated Statements of Operations are summarized in the following tables:
			Three Months Ended							Nine Months Ended
	Derivative instruments not designated as cash flow hedges		September 30,							September 30,
			2014			2013				2014			2013
	Realized gains (losses) on commodity derivative contracts		(in millions)
	QEP Energy
	Gas derivative contracts		$	5.5		$	42.5			$	(23.3	)	$	112
	Oil derivative contracts		(12.2		)	(15.3		)		(50.2		)	(3.7		)
	QEP Marketing
	Gas derivative contracts		(0.4		)	(0.3		)		(2.4		)	0.7
	Total realized gains (losses) on commodity derivative contracts		(7.1		)	26.9				(75.9		)	109
	Unrealized gains (losses) on commodity derivative contracts
	QEP Energy
	Gas derivative contracts		27.6			(6.6		)		9.5			(9.6		)
	Oil derivative contracts		133.2			(46.2		)		54.3			(49.1		)
	QEP Marketing
	Gas derivative contracts		0.7			0.1				1			(0.3		)
	Total unrealized gains (losses) on commodity derivative contracts		161.5			(52.7		)		64.8			(59.0		)
	Total realized and unrealized gains (losses) on commodity derivative contracts		$	154.4		$	(25.8	)		$	(11.1	)	$	50
	Realized gains (losses) on interest rate swaps
	Realized losses on interest rate swaps		$	(1.3	)	$	(0.6	)		$	(3.2	)	$	(1.9	)
	Unrealized gains (losses) on interest rate swaps
	Unrealized gains (losses) on interest rate swaps		2.6			(1.4		)		1.1			3.5
	Total realized and unrealized gains (losses) on interest rate swaps		$	1.3		$	(2.0	)		$	(2.1	)	$	1.6
	Total net realized gains (losses) on derivative contracts		$	(8.4	)	$	26.3			$	(79.1	)	$	107.1
	Total net unrealized gains (losses) on derivative contracts		164.1			(54.1		)		65.9			(55.5		)
	Grand Total		$	155.7		$	(27.8	)		$	(13.2	)	$	51.6

Restructuring_Costs_Tables

Restructuring Costs (Tables)	9 Months Ended
	Sep. 30, 2014
Restructuring Costs [Abstract]	'
Reconciliation of QEP Energy's restructuring cost	'
		Total Restructuring Costs
		Total Expected to be Incurred		Recognized in Income
				Period from Inception to September 30, 2014		Three Months Ended September 30,				Nine Months Ended September 30,
						2014		2013		2014		2013
	Continuing Operations:	(in millions)
	QEP Energy
	One-time termination benefits	$	3.3	$	3.3	$	—	$	0.1	$	—	$	0.4
	Retention & relocation expense	3.7		3.7		—		0.1		—		0.3
	Lease termination costs	0.6		0.6		—		—		—		—
	Total restructuring costs	$	7.6	$	7.6	$	—	$	0.2	—		0.7
	QEP Marketing & Other
	One-time termination benefits	$	0.3	$	0.3	$	—	$	0.1	$	—	$	0.1
	Total restructuring costs	$	0.3	$	0.3	$	—	$	0.1	$	—	$	0.1
	Total QEP
	One-time termination benefits	$	3.6	$	3.6	$	—	$	0.2	$	—	$	0.5
	Retention & relocation expense	3.7		3.7		—		0.1		—		0.3
	Lease termination costs	0.6		0.6		—		—		—		—
	Total restructuring costs	$	7.9	$	7.9	$	—	$	0.3	$	—	$	0.8

Debt_Tables

Debt (Tables)	9 Months Ended
	Sep. 30, 2014
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, term loan and senior notes, consisted of the following:
		September 30,			December 31,
		2014			2013
		(in millions)
	QEP's revolving credit facility due 2016	$	297.5		$	480
	Term loan due 2017	600			300
	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	3,119.30			3,001.80
	Less unamortized discount	(3.8		)	(4.3		)
	Total long-term debt outstanding	$	3,115.50		$	2,997.50

EquityBased_Compensation_Table

Equity-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2014
Share-based Compensation [Abstract]	'
Schedule of calculated fair value of options granted and major assumptions used	'
		Stock Option Assumptions
		Nine Months Ended
		September 30, 2014
	Weighted-average grant-date fair value of awards granted during the period	$	10.11
	Weighted-average risk-free interest rate	1.31		%
	Weighted-average expected price volatility	37.1		%
	Expected dividend yield	0.25		%
	Expected term in years at the date of grant	4.5
Summary of stock option transactions under the terms of LTSIP	'
	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, 2013	1,794,187			$	27.9
	Granted	282,236			31.67
	Exercised	(65,366	)		22.24
	Forfeited	(14,842	)		30.53
	Outstanding at September 30, 2014	1,996,215			$	28.6	3.43	$	6.3
	Options Exercisable at September 30, 2014	1,452,138			$	27.71	2.56	$	6.2
	Unvested Options at September 30, 2014	544,077			$	30.97	5.75	$	0.2
Restricted Share Units Activity	'
		Restricted Shares			Weighted-
		Outstanding			Average Grant-Date Fair Value
					(per share)
	Unvested balance at December 31, 2013	1,388,953			$	30.96
	Granted	968,118			31.82
	Vested	(637,677	)		31.63
	Forfeited	(116,238	)		30.96
	Unvested balance at September 30, 2014	1,603,156			$	31.22
Schedule of Performance Share Units Activity	'
		Performance Share			Weighted-
		Units Outstanding			Average Grant-Date Fair Value
	Unvested balance at December 31, 2013	480,660			$	32.33
	Granted	252,161			31.71
	Vested and paid out	(55,659	)		39.07
	Canceled (1)	(51,361	)		39.07
	Forfeited	(22,416	)		30.47
	Unvested balance at September 30, 2014	603,385			$	30.92

Employee_Benefits_Tables

Employee Benefits (Tables)	9 Months Ended
	Sep. 30, 2014
Compensation and Retirement Disclosure [Abstract]	'
Pension and Other Postretirement Benefit Costs	'
		Pension
		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in millions)
	Service cost	$	0.6		$	0.7		$	2		$	2.6
	Interest cost	1.2			1.2			4			3.7
	Expected return on plan assets	(1.4		)	(0.9		)	(3.8		)	(2.9		)
	Amortization of prior service costs (1)	1.1			1.2			3.6			3.7
	Amortization of actuarial losses (1)	0.2			0.5			0.6			1.7
	Curtailment cost	—			—			2			—
	Special termination benefits	—			—			0.3			—
	Periodic expense	$	1.7		$	2.7		$	8.7		$	8.8
	____________________________
	(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						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
		(in millions)
	Service cost	$	—		$	0.1		$	—		$	0.1
	Interest cost	—			—			0.2			0.2
	Amortization of prior service costs (1)	0.1			0.1			0.3			0.3
	Recognized net actuarial loss	—			0.1			—			0.1
	Curtailment cost	—						0.4			—
	Periodic expense	$	0.1		$	0.3		$	0.9		$	0.7
	____________________________
	(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)	9 Months Ended
	Sep. 30, 2014
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 marketing, the Haynesville Gathering System, an underground storage reservoir, and corporate (QEP Marketing & 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.
	The following table is a summary of operating results for the three months ended September 30, 2014, by line of business:
		QEP Energy			QEP Marketing			Eliminations			QEP
					& Other						Consolidated
		(in millions)
	Revenues
	From unaffiliated customers	$	652.9		$	257.1		$	—		$	910
	From affiliated customers	—			417.8			(417.8		)	—
	Total revenues	652.9			674.9			(417.8		)	910
	Operating expenses
	Purchased gas, oil and NGL expense	32.8			668.3			(412.7		)	288.4
	Lease operating expense	61.1			—			—			61.1
	Gas, oil and NGL transportation and other handling costs	75.2			—			(4.1		)	71.1
	Gathering and other expense	—			1.4			—			1.4
	General and administrative	44.3			6.1			(1.0		)	49.4
	Production and property taxes	59.3			0.1			—			59.4
	Depreciation, depletion and amortization	249			2.4			—			251.4
	Impairment and exploration expense	0.9			—			—			0.9
	Total operating expenses	522.6			678.3			(417.8		)	783.1
	Net (loss) gain from asset sales	(11.9		)	0.1						(11.8		)
	Operating income (loss)	118.4			(3.3		)	—			115.1
	Realized and unrealized gains on derivative contracts	154.1			1.6			—			155.7
	Interest and other income	3.9			56.6			(56.3		)	4.2
	Income from unconsolidated affiliates	0.1			—			—			0.1
	Interest expense	(57.0		)	(40.8		)	56.3			(41.5		)
	Income before income taxes	219.5			14.1			—			233.6
	Income tax provision	(72.7		)	(7.2		)	—			(79.9		)
	Income from continuing operations	146.8			6.9			—			153.7
	Net income from discontinued operations, net of income tax	—			—			—			17.4
	Net income attributable to QEP	$	146.8		$	6.9		$	—		$	171.1
	The following table is a summary of operating results for the three months ended September 30, 2013, by line of business:
		QEP Energy			QEP Marketing			Eliminations			QEP
					& Other						Consolidated
		(in millions)
	Revenues
	From unaffiliated customers	$	538.5		$	181		$	—		$	719.5
	From affiliated customers	—			265.6			(265.6		)	—
	Total revenues	538.5			446.6			(265.6		)	719.5
	Operating expenses
	Purchased gas, oil and NGL expense	39.2			438.2			(257.9		)	219.5
	Lease operating expense	43.5			—			—			43.5
	Gas, oil and NGL transportation and other handling costs	65.1			—			(6.5		)	58.6
	Gathering and other expense	—			2.1			—			2.1
	General and administrative	33.5			8.4			(1.2		)	40.7
	Production and property taxes	40.4			0.2			—			40.6
	Depreciation, depletion and amortization	236			2.4			—			238.4
	Impairment and exploration expense	5.6						—			5.6
	Total operating expenses	463.3			451.3			(265.6		)	649
	Net gain from assets sales	12.8			—			—			12.8
	Operating income (loss)	88			(4.7		)	—			83.3
	Realized and unrealized losses on derivative contracts	(25.6		)	(2.2		)	—			(27.8		)
	Interest and other income	2.6			52.2			(48.7		)	6.1
	Income from unconsolidated affiliates	—			—			—			—
	Interest expense	(49.2		)	(40.9		)	48.7			(41.4		)
	Income before income taxes	15.8			4.4			—			20.2
	Income tax (provision) benefit	(6.2		)	(1.9		)	—			(8.1		)
	Income from continuing operations	9.6			2.5			—			12.1
	Net income from discontinued operations, net of income tax	—			—			—			25.2
	Net income attributable to QEP	$	9.6		$	2.5		$	—		$	37.3
	The following table is a summary of operating results for the nine months ended September 30, 2014, by line of business:
		QEP Energy			QEP Marketing			Eliminations			QEP
					& Other						Consolidated
	(in millions)
Revenues
From unaffiliated customers	$	1,953.30		$	661.4		$	—		$	2,614.70
From affiliated customers	—			1,132.90			(1,132.9		)	—
Total revenues	1,953.30			1,794.30			(1,132.9		)	2,614.70
Operating expenses
Purchased gas, oil and NGL expense	120.9			1,771.60			(1,117.0		)	775.5
Lease operating expense	177			—			—			177
Gas, oil and NGL transportation and other handling costs	211.8			—			(13.3		)	198.5
Gathering and other expense	—			4.8			—			4.8
General and administrative	132			17.6			(2.6		)	147
Production and property taxes	159.8			1			—			160.8
Depreciation, depletion and amortization	704.7			7.8			—			712.5
Impairment and exploration expense	8.3			—			—			8.3
Total operating expenses	1,514.50			1,802.80			(1,132.9		)	2,184.40
Net loss from asset sales	(210.3		)	—			—			(210.3		)
Operating income (loss)	228.5			(8.5		)	—			220
Realized and unrealized losses on derivative contracts	(9.7		)	(3.5		)	—			(13.2		)
Interest and other income	7.4			162			(161.6		)	7.8
Income from unconsolidated affiliates	0.2			—			—			0.2
Interest expense	(162.5		)	(127.5		)	161.6			(128.4		)
Income before income taxes	63.9			22.5			—			86.4
Income tax provision	(14.6		)	(11.5		)	—			(26.1		)
Income from continuing operations	49.3			11			—			60.3
Net income from discontinued operations, net of income tax	—			—			—			58.2
Net income attributable to QEP	$	49.3		$	11		$	—		$	118.5
The following table is a summary of operating results for the nine months ended September 30, 2013, by line of business:
	QEP Energy			QEP Marketing			Eliminations			QEP
				& Other						Consolidated
	(in millions)
Revenues
From unaffiliated customers	$	1,575.20		$	489.6		$	—		$	2,064.80
From affiliated customers	—			686			(686.0		)	—
Total revenues	1,575.20			1,175.60			(686.0		)	2,064.80
Operating expenses
Purchased gas, oil and NGL expense	159.8			1,150.50			(660.0		)	650.3
Lease operating expense	130.2			—			—			130.2
Gas, oil and NGL transportation and other handling costs	180.8			—			(22.3		)	158.5
Gathering and other expense	—			6.4			—			6.4
General and administrative	100.2			20.3			(3.7		)	116.8
Production and property taxes	112.7			1			—			113.7
Depreciation, depletion and amortization	712.1			7.2			—			719.3
Impairment and exploration expense	13.5			—			—			13.5
Total operating expenses	1,409.30			1,185.40			(686.0		)	1,908.70
Net gain from asset sales	113.4			—			—			113.4
Operating income (loss)	279.3			(9.8		)	—			269.5
Realized and unrealized gains on derivative contracts	49.6			2			—			51.6
Interest and other income	7.5			158.4			(143.2		)	22.7
Interest expense	(143.4		)	(124.5		)	143.2			(124.7		)
Income before income taxes	193			26.1			—			219.1
Income tax provision	(71.1		)	(11.4		)	—			(82.5		)
Income for continuing operations	121.9			14.7			—			136.6
Net income from discontinued operations, net of income tax	—			—			—			74.8
Net income attributable to QEP	$	121.9		$	14.7		$	—		$	211.4

Nature_of_Business_Nature_of_B

Nature of Business Nature of Business (Narrative) (Details) (USD $)	Sep. 30, 2014
Nature Of Business [Abstract]	'
Value of midstream business sold	$2,500,000,000
Debt refinancing included in sale of midstream business	$230,000,000

Acquisitions_Divestitures_Narr

Acquisitions & Divestitures (Narrative) (Details) (USD $)	4 Months Ended	9 Months Ended			3 Months Ended	9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Sep. 30, 2014		Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2014
		acre		Term Loan due 2017 [Member]	Permian Basin [Member]	Permian Basin [Member]
Business Acquisition [Line Items]	'	'		'	'	'
Liabilities incurred	'	$15.50	[1]	'	'	$9.70
Aggregate sale price of assets disposed	'	702.3		'	'	'
Pretax loss on sale of assets	'	210.4		'	'	'
Consideration Held In Escrow Pending Title Defects	'	28.7		'	'	'
Payments to Acquire Businesses, Gross	'	'		'	941.8	'
Payments to Acquire Businesses Net	'	941.8		'	'	'
Net acres of producing and undeveloped oil and gas properties	'	26,500		'	'	'
Number of vertical producing wells	'	270		'	'	'
Escrow Deposit	'	50		'	'	'
Borrowings to Fund Acquisition	'	'		300	'	'
Business Combination, Pro Forma Information, Revenue of Acquiree since Acquisition Date, Actual	114.2	'		'	'	'
Business Combination, Pro Forma Information, Earnings or Loss of Acquiree since Acquisition Date, Actual	23.1	'		'	'	'
Business Acquisition, Transaction Costs	'	0.6		'	'	'
Debt Issuance Cost	'	$1.10		'	'	'
[1]	Additions include $9.7 million related to the Permian Basin Acquisition (see Note 3 - Acquisitions and Divestitures).

Acquisitions_Divestitures_Sche

Acquisitions & Divestitures (Schedule Of Purchase Accounting Entries) (Details) (USD $)	3 Months Ended	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2014
Significant Acquisitions and Disposals [Line Items]	'	'
Payments to Acquire Businesses Net	'	$941.80
Liabilities incurred	'	-15.5	[1]
Fair value of assets acquired (liabilities assumed)	941.8	941.8
Proved Property [Member]	'	'
Significant Acquisitions and Disposals [Line Items]	'	'
Fair value of assets acquired (liabilities assumed)	472.1	472.1
Unproved Property [Member]	'	'
Significant Acquisitions and Disposals [Line Items]	'	'
Fair value of assets acquired (liabilities assumed)	480.6	480.6
Other Liabilities [Member]	'	'
Significant Acquisitions and Disposals [Line Items]	'	'
Fair value of assets acquired (liabilities assumed)	-1.2	-1.2
Permian Basin [Member]	'	'
Significant Acquisitions and Disposals [Line Items]	'	'
Payments to Acquire Businesses, Gross	941.8	'
Liabilities incurred	'	($9.70)
[1]	Additions include $9.7 million related to the Permian Basin Acquisition (see Note 3 - Acquisitions and Divestitures).

Acquisitions_Divestitures_Supp

Acquisitions & Divestitures Supplemental Proforma Results of Operations (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Business Acquisition [Line Items]	'	'	'	'
Total Revenues	$910	$719.50	$2,614.70	$2,064.80
Net income attributable to QEP	171.1	37.3	118.5	211.4
Earnings Per Share, Basic	$0.95	$0.21	$0.66	$1.18
Earnings Per Share, Diluted	$0.94	$0.21	$0.66	$1.18
Business Acquisition, Pro Forma Revenue	'	776.5	2,640.80	2,195.40
Business Acquisition, Pro Forma Net Income (Loss)	'	$54.20	$125.50	$240.40
Business Acquisition, Pro Forma Earnings Per Share, Basic	'	$0.30	$0.70	$1.34
Business Acquisition, Pro Forma Earnings Per Share, Diluted	'	$0.30	$0.70	$1.34

Discontinued_Operations_Narrat

Discontinued Operations (Narrative) (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'
Value of midstream business sold	$2,500,000,000	'	$2,500,000,000	'
Debt refinancing included in sale of midstream business	230,000,000	'	230,000,000	'
Continuing cash flows related to midstream business held for sale	19,000,000	25,900,000	64,100,000	67,200,000
Depreciation, depletion and amortization	251,400,000	238,400,000	712,500,000	719,300,000
Midstream Business Held For Sale [Member]	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'
Depreciation, depletion and amortization	14,300,000	14,700,000	43,100,000	37,800,000
Property, plant and equipment, including dry exploratory well expense	'	'	$45,600,000	$57,400,000

Discontinued_Operations_Income

Discontinued Operations - Income Statement Impact of Discontinued Operations (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'		'		'		'
NGL sales	$51.10		$47.70		$179.30		$144.40
Other revenue	3.4		2.8		5.1		8.7
Purchased gas, oil and NGL sales	290.4		220.4		780.1		644.9
Total Revenues	910		719.5		2,614.70		2,064.80
Purchased gas, oil and NGL expense	288.4		219.5		775.5		650.3
Lease operating expense	61.1		43.5		177		130.2
Natural gas, oil and NGL transportation and other handling costs	71.1		58.6		198.5		158.5
Gathering, processing and other	1.4		2.1		4.8		6.4
General and administrative	49.4		40.7		147		116.8
Production and property taxes	59.4		40.6		160.8		113.7
Depreciation, depletion and amortization	251.4		238.4		712.5		719.3
Total operating expenses	783.1		649		2,184.40		1,908.70
Net loss from asset sales	-11.8		12.8		-210.3		113.4
OPERATING INCOME	115.1		83.3		220		269.5
Interest income and other loss	4.2		6.1		7.8		22.7
Income from unconsolidated affiliates	'		'		4.6		3.7
Interest expense	-41.5		-41.4		-128.4		-124.7
Net income attributable to noncontrolling interest	'		'		-17.6		-5.8
DISCONTINUED OPERATIONS, NET OF INCOME TAX	17.4		25.2		58.2		74.8
Income from discontinued operations before income taxes attributable to QEP from QEP Midstream	7.9		7.9		20.4		26.2
Ownership percentage	57.80%		'		57.80%		'
Midstream Business Held For Sale [Member]	'		'		'		'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'		'		'		'
NGL sales	28.8		23.6		94.6		70.6
Other revenue	43.1		44.2		119.9		126.4
Purchased gas, oil and NGL sales	-11.9	[1]	-14.4	[1]	-38.5	[1]	-41.5	[1]
Total Revenues	60		53.4		176		155.5
Purchased gas, oil and NGL expense	-12.4	[1]	-14.4	[1]	-39.5	[1]	-41.4	[1]
Lease operating expense	-1.7	[1]	-0.8	[1]	-4.8	[1]	-2.6	[1]
Natural gas, oil and NGL transportation and other handling costs	-10.6	[1]	-21.7	[1]	-40.1	[1]	-53	[1]
Gathering, processing and other	22.7		20.3		69.8		60.1
General and administrative	11.1		8.6		34.3		19.4
Production and property taxes	2.1		1.8		6.1		4
Depreciation, depletion and amortization	14.3		14.7		43.1		37.8
Total operating expenses	25.5		8.5		68.9		24.3
Net loss from asset sales	0		-0.1		-0.1		-0.5
OPERATING INCOME	34.5		44.8		107		130.7
Interest income and other loss	0		-2.1		0		-13.7
Income from unconsolidated affiliates	1.1		0.8		4.4		3.7
Interest expense	-1.5		-0.3		-2.8		2.3
INCOME FROM DISCONTINUED OPERATIONS BEFORE INCOME TAXES	34.1	[2]	43.2	[2]	108.6	[2]	123	[2]
Income taxes	-9.9		-14.2		-32.8		-42.4
NET INCOME FROM DISCONTINUED OPERATIONS	24.2		29		75.8		80.6
Net income attributable to noncontrolling interest	($6.80)		($3.80)		($17.60)		($5.80)
[1]	Includes discontinued intercompany eliminations
[2]	Includes income from discontinued operations before income taxes attributable to QEP from QEP Midstream (of which QEP owns 57.8%) of $7.9 million and $20.4 million for the three and nine months ended September 30, 2014, respectively, and $7.9 million and $26.2 million for the three and nine months ended September 30, 2013, respectively

Discontinued_Operations_Assets

Discontinued Operations - Assets and Liabilities of Discontinued Operations (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'
Cash and cash equivalents	$0	$11.90	$123	$0
Accounts receivable, net	599.4	316.3	'	'
Deferred income taxes - current	0	27.9	'	'
Prepaid expenses and other	50.8	45.4	'	'
Current assets of discontinued operations held for sale	138.3	122	'	'
Midstream field services	197.5	197.3	'	'
Material and supplies	55.3	54.3	'	'
Total Property, Plant and Equipment	13,191.50	12,573.60	'	'
Midstream field services	-34.3	-28.1	'	'
Other noncurrent assets	39.4	46.6	'	'
Noncurrent assets of discontinued operations held for sale	1,174.20	1,167.70	'	'
Production and property taxes	73.5	49.4	'	'
Interest payable	34.1	37.2	'	'
Current liabilities of discontinued operations held for sale	161.6	75.3	'	'
Long-term debt	3,115.50	2,997.50	'	'
Deferred income taxes	1,500.80	1,364.90	'	'
Asset retirement obligations	162.3	163.3	'	'
Other long-term liabilities	90.3	94.5	'	'
Noncurrent liabilities of discontinued operations held for sale	402	238.3	'	'
Midstream Business Held For Sale [Member]	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'
Cash and cash equivalents	27.1	18.1	'	'
Accounts receivable, net	71.8	53.9	'	'
Income taxes receivable	0	38.4	'	'
Deferred income taxes - current	7	2.7	'	'
Prepaid expenses and other	32.4	8.9	'	'
Current assets of discontinued operations held for sale	138.3	122	'	'
Midstream field services	1,550.50	1,500.80	'	'
Material and supplies	6.5	4.8	'	'
Total Property, Plant and Equipment	1,557	1,505.60	'	'
Midstream field services	-422.2	-381.6	'	'
Net Property, Plant and Equipment	1,134.80	1,124	'	'
Investment in unconsolidated affiliates	35.9	39	'	'
Other noncurrent assets	3.5	4.7	'	'
Noncurrent assets of discontinued operations held for sale	1,174.20	1,167.70	'	'
Accounts payable and accrued expenses	85.6	74.1	'	'
Accrued income taxes	70.2	0	'	'
Production and property taxes	5.4	1.2	'	'
Interest payable	0.4	0	'	'
Current liabilities of discontinued operations held for sale	161.6	75.3	'	'
Long-term debt	230	0	'	'
Deferred income taxes	126.5	195.7	'	'
Asset retirement obligations	29.9	28.5	'	'
Other long-term liabilities	15.6	14.1	'	'
Noncurrent liabilities of discontinued operations held for sale	$402	$238.30	'	'

Earnings_Per_Share_Details

Earnings Per Share (Details)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Earnings Per Share [Abstract]	'	'	'	'
Weighted-average basic common shares outstanding (in shares)	180.1	179.3	180	179.2
Potential number of shares issuable upon excerise of in-the-money stock options under the Long-term Stock Incentive Plan	0.5	0.2	0.4	0.2
Average diluted common shares outstanding (in shares)	180.6	179.5	180.4	179.4

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2014		Dec. 31, 2013
Liabilities Settled Through Divestiture	$20.20		'		'
Asset retirement obligations	162.3		162.3		163.3
Asset Retirement Obligation, Current	0.9		0.9		1.8
ARO Liability [Roll Forward]	'		'		'
ARO liability, Beginning Balance	'		165.1	[1]	'
Accretion	'		4.9		'
Liabilities incurred	'		15.5	[2]	'
Revisions	'		-0.3		'
Liabilities settled	'		-22	[3]	'
ARO liability, Ending Balance	163.2	[4]	163.2	[4]	'
Midstream Business Held For Sale [Member]	'		'		'
Asset retirement obligations	29.9		29.9		28.5
Permian Basin [Member]	'		'		'
ARO Liability [Roll Forward]	'		'		'
Liabilities incurred	'		$9.70		'
[1]	Excludes $28.5 million of ARO classified as liabilities held for sale on the Condensed Consolidated Balance Sheet.
[2]	Additions include $9.7 million related to the Permian Basin Acquisition (see Note 3 - Acquisitions and Divestitures).
[3]	Settlements include $20.2 million related to the property sales in the second quarter of 2014 (see Note 3 - Acquisitions and Divestitures).
[4]	Excludes $29.9 million of ARO classified as liabilities held for sale on the Condensed Consolidated Balance Sheet.

Fair_Value_Measurements_Fair_V

Fair Value Measurements - Fair Value of Financial Assets and Liabilities (Details) (USD $)	Sep. 30, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Financial Assets	'		'
Derivative Asset, Fair Value, Gross	$49.70		$6.50
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	9.1		32
Fair Value, Measurements, Recurring [Member]	'		'
Financial Assets	'		'
Net amount of derivative assets presented on condensed consolidated balance sheets	45.3		1.2
Financial liabilities	'		'
Net amount of derivative liabilities presented on condensed consolidated balance sheets	4.7		26.7
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	49.7		6.5
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	9.1		32
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	-4.4	[1]	-5.3	[1]
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	-4.4	[1]	-5.3	[1]
Long-term [Member] | Interest Rate Swap [Member]	'		'
Financial Assets	'		'
Derivative Asset, Fair Value, Gross	'		0.6
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	0		0
Long-term [Member] | Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member]	'		'
Financial Assets	'		'
Net amount of derivative assets presented on condensed consolidated balance sheets	3.5		0.6
Long-term [Member] | Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]	'		'
Financial Assets	'		'
Derivative Asset, Fair Value, Gross	0		0
Long-term [Member] | Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]	'		'
Financial Assets	'		'
Derivative Asset, Fair Value, Gross	3.5		0.6
Long-term [Member] | Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]	'		'
Financial Assets	'		'
Derivative Asset, Fair Value, Gross	0		0
Long-term [Member] | Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member]	'		'
Financial Assets	'		'
Derivative Asset, Fair Value, Gross	0	[1]	0	[1]
Long-term [Member] | Commodity Contract [Member]	'		'
Financial Assets	'		'
Derivative Asset, Fair Value, Gross	'		0.4
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	'		0
Long-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member]	'		'
Financial Assets	'		'
Net amount of derivative assets presented on condensed consolidated balance sheets	9.2		0.4
Financial liabilities	'		'
Net amount of derivative liabilities presented on condensed consolidated balance sheets	0.2		'
Long-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		'
Long-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]	'		'
Financial Assets	'		'
Derivative Asset, Fair Value, Gross	9.6		0.4
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	0.6		'
Long-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		'
Long-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member]	'		'
Financial Assets	'		'
Derivative Asset, Fair Value, Gross	-0.4	[1]	0	[1]
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	-0.4	[1]	'
Short-term [Member] | Interest Rate Swap [Member]	'		'
Financial Assets	'		'
Derivative Asset, Fair Value, Gross	0		0
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	'		2.6
Short-term [Member] | Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member]	'		'
Financial liabilities	'		'
Net amount of derivative liabilities presented on condensed consolidated balance sheets	4.3		2.6
Short-term [Member] | Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]	'		'
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	0		0
Short-term [Member] | Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]	'		'
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	4.3		2.6
Short-term [Member] | Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]	'		'
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	0		0
Short-term [Member] | Interest Rate Swap [Member] | Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member]	'		'
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	0	[1]	0	[1]
Short-term [Member] | Commodity Contract [Member]	'		'
Financial Assets	'		'
Derivative Asset, Fair Value, Gross	'		5.5
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	'		29.4
Short-term [Member] | Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member]	'		'
Financial Assets	'		'
Net amount of derivative assets presented on condensed consolidated balance sheets	32.6		0.2
Financial liabilities	'		'
Net amount of derivative liabilities presented on condensed consolidated balance sheets	0.2		24.1
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	36.6		5.5
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	4.2		29.4
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	-4	[1]	-5.3	[1]
Financial liabilities	'		'
Derivative Liability, Fair Value, Gross	($4)	[1]	($5.30)	[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 $)	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and Cash Equivalents, at Carrying Value	$0	$11.90	$123	$0
Checks outstanding in excess of cash balances	36.8	109.1	'	'
Estimate of Fair Value Measurement [Member]	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Long-term Debt, Fair Value	3,209.30	3,034.90	'	'
Cash and Cash Equivalents, at Carrying Value	0	11.9	'	'
Checks outstanding in excess of cash balances	36.8	109.1	'	'
Reported Value Measurement [Member]	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Long-term Debt, Fair Value	3,115.50	2,997.50	'	'
Cash and Cash Equivalents, at Carrying Value	0	11.9	'	'
Checks outstanding in excess of cash balances	$36.80	$109.10	'	'

Derivative_Contracts_Narrative

Derivative Contracts (Narrative) (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013		Dec. 31, 2013
Derivative [Line Items]	'		'		'		'		'
Maximum Forecasted Production Covered By Derivatives	'		'		100.00%		'		'
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	$0	[1]	$19.70	[1]	$0	[1]	$60.40	[1]	'
Long-term Debt, Gross	3,119.30		'		3,119.30		'		3,001.80
Term Loan due 2017 [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Long-term Debt, Gross	600		'		600		'		300
Effective interest Rate Before Impact of Derivatives	3.21%		'		3.21%		'		'
Interest Rate Swap [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Derivative, Fixed Interest Rate	0.96%		'		0.96%		'		'
Derivative, Maturity Date	'		'		31-Mar-17		'		'
First Term Loan Tranche [Member] | Interest Rate Swap [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Derivative Liability, Notional Amount	300		'		300		'		'
Derivative, Fixed Interest Rate	1.07%		'		1.07%		'		'
Second Term Loan Tranche [Member] | Interest Rate Swap [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Derivative Liability, Notional Amount	$300		'		$300		'		'
Derivative, Fixed Interest Rate	0.86%		'		0.86%		'		'
[1]	Presented net of income tax benefit of $11.7 million and $35.8 million during the three and nine months ended SeptemberB 30, 2013

Schedule_of_Commodity_Derivati

Schedule of Commodity Derivative Contracts (Details) (USD $)

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

In Millions, unless otherwise specified

QEP Marketing [Member]

QEP Energy [Member]

QEP Energy [Member]

QEP Energy [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Long-term [Member]

Long-term [Member]

Long-term [Member]

Long-term [Member]

Short-term [Member]

Short-term [Member]

Short-term [Member]

Short-term [Member]

Short-term [Member]

Short-term [Member]

Oil Sales [Member]

Oil Sales [Member]

Oil Sales [Member]

Oil Sales [Member]

Natural Gas Sales [Member]

Natural Gas Sales [Member]

Natural Gas Sales [Member]

Natural Gas Sales [Member]

Natural Gas Sales [Member]

Natural Gas Sales [Member]

2014 [Member]

2014 [Member]

2014 [Member]

2015 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Commodity Contract [Member]

Fair Value, Measurements, Recurring [Member]

Interest Rate Swap [Member]

Commodity Contract [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

QEP Energy [Member]

QEP Energy [Member]

QEP Energy [Member]

QEP Energy [Member]

QEP Marketing [Member]

QEP Marketing [Member]

QEP Energy [Member]

QEP Energy [Member]

QEP Energy [Member]

QEP Energy [Member]

Swap [Member]

Swap [Member]

Swap [Member]

Swap [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 2 [Member]

2014 [Member]

2015 [Member]

2015 [Member]

Year2016 [Member]

2014 [Member]

2015 [Member]

2014 [Member]

2014 [Member]

2015 [Member]

2015 [Member]

IFNPCR [Member]

NYMEX WTI less ICE Brent Differential [Member]

NYMEX WTI less LLS Differential [Member]

NYMEX WTI less LLS Differential [Member]

Commodity Contract [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Swap [Member]

Swap [Member]

Swap [Member]

Swap [Member]

Swap [Member]

Swap [Member]

Swap [Member]

Swap [Member]

Swap [Member]

Swap [Member]

Purchased Gas and Oil Expense [Member]

Oil Sales [Member]

Oil Sales [Member]

Oil Sales [Member]

NYMEX WTI [Member]

NYMEX WTI [Member]

BRENT ICE [Member]

NYMEX WTI [Member]

IFNPCR [Member]

IFNPCR [Member]

NYMEX [Member]

IFNPCR [Member]

NYMEX [Member]

IFNPCR [Member]

Btu

bbl

bbl

bbl

bbl

bbl

bbl

bbl

Btu

Btu

MMBTU

MMBTU

MMBTU

MMBTU

Derivatives, Fair Value [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Year

'

'

'2014

'2014

'2014

'2015

'

'

'

'

'

'

'

'

'

'

'

'

'2014

'2015

'2015

'2016

'2014

'2015

'2014

'2014

'2015

'2015

Index

'

'

'IFNPCR

'ICE Brent

'LLS

'LLS

'

'

'

'

'

'

'

'

'

'

'

'

'NYMEX WTI

'NYMEX WTI

'BRENT ICE

'NYMEX WTI

'IFNPCR

'IFNPCR

' NYMEX

' IFNPCR

'NYMEX

'IFNPCR

Derivative Liability, Fair Value, Gross Liability

$9.10

$32

'

'

'

'

$9.10

$32

$0

$0

$0

$0.60

$2.60

$29.40

$4.30

$2.60

$4.20

$29.40

'

'

'

'

'

'

'

'

'

'

Total Volume (in Bcf, Mbbl, millions of gallons, millions of MMBtu)

'

'

600,000

200,000

200,000

100,000

'

'

'

'

'

'

'

'

'

'

'

'

3,100,000

7,700,000

400,000

400,000

1,400,000

2,500,000

7,400,000

20,200,000

25,600,000

11,000,000

Average Swap price per unit ($ per unit)

'

'

3.86

13.78

4.03

4.03

'

'

'

'

'

'

'

'

'

'

'

'

93.54

90.04

104.95

90

4.03

4.07

4.22

4.08

4.14

4.06

Derivative_Contracts_Schedule_

Derivative Contracts Schedule of Interest Rate Contracts (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014
Interest Rate Swap [Member]	'
Derivative [Line Items]	'
Derivative, Maturity Date	31-Mar-17
Derivative, Fixed Interest Rate	0.96%
First Term Loan Tranche [Member] | Interest Rate Swap [Member]	'
Derivative [Line Items]	'
Notional amount	300
Derivative, Fixed Interest Rate	1.07%
Derivative, Description of Terms	'One-month LIBOR
Second Term Loan Tranche [Member] | Interest Rate Swap [Member]	'
Derivative [Line Items]	'
Notional amount	300
Derivative, Fixed Interest Rate	0.86%
Derivative, Description of Terms	'One-month LIBOR
Term Loan due 2017 [Member]	'
Derivative [Line Items]	'
Notional amount	600

Derivative_Contracts_Schedule_1

Derivative Contracts - Schedule of Derivatives Financial Statement Presentation (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Derivative [Line Items]	'	'
Derivative Asset, Fair Value, Gross	$49.70	$6.50
Derivative Liability, Fair Value, Gross Liability	9.1	32
Interest Rate Swap [Member] | Short-term [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Fair Value, Gross	0	0
Derivative Liability, Fair Value, Gross Liability	'	2.6
Interest Rate Swap [Member] | Long-term [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Fair Value, Gross	'	0.6
Derivative Liability, Fair Value, Gross Liability	0	0
Commodity Contract [Member] | Short-term [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Fair Value, Gross	'	5.5
Derivative Liability, Fair Value, Gross Liability	'	29.4
Commodity Contract [Member] | Long-term [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Fair Value, Gross	'	0.4
Derivative Liability, Fair Value, Gross Liability	'	0
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Fair Value, Gross	49.7	6.5
Derivative Liability, Fair Value, Gross Liability	9.1	32
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate Swap [Member] | Short-term [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	4.3	2.6
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate Swap [Member] | Long-term [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Fair Value, Gross	3.5	0.6
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	36.6	5.5
Derivative Liability, Fair Value, Gross Liability	4.2	29.4
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	9.6	0.4
Derivative Liability, Fair Value, Gross Liability	$0.60	'

Gain_Loss_in_Statement_of_Fina

Gain (Loss) in Statement of Financial Performance (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Derivative Instruments Not Designated as Hedging Instruments [Abstract]	'	'	'	'
Realized gain (loss) derivative contracts not designated as hedging instruments	($8.40)	$26.30	($79.10)	$107.10
Unrealized gain (loss) derivative contracts not designated as hedging instruments	164.1	-54.1	65.9	-55.5
Total gain (loss) on commodity derivative instruments	155.7	-27.8	-13.2	51.6
Realized and unrealized gains on commodity derivative instruments [Member]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments [Abstract]	'	'	'	'
Realized gain (loss) on commodity derivative contracts	-7.1	26.9	-75.9	109
Unrealized gain (loss) on commodity derivative contracts	161.5	-52.7	64.8	-59
Total gain (loss) on commodity derivative instruments	154.4	-25.8	-11.1	50
Natural gas derivative contracts [Member] | QEP Energy [Member]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments [Abstract]	'	'	'	'
Realized gain (loss) on commodity derivative contracts	5.5	42.5	-23.3	112
Unrealized gain (loss) on commodity derivative contracts	27.6	-6.6	9.5	-9.6
Natural gas derivative contracts [Member] | QEP Marketing [Member]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments [Abstract]	'	'	'	'
Realized gain (loss) on commodity derivative contracts	-0.4	-0.3	-2.4	0.7
Unrealized gain (loss) on commodity derivative contracts	0.7	0.1	1	-0.3
Oil derivative contracts [Member] | QEP Energy [Member]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments [Abstract]	'	'	'	'
Realized gain (loss) on commodity derivative contracts	-12.2	-15.3	-50.2	-3.7
Unrealized gain (loss) on commodity derivative contracts	133.2	-46.2	54.3	-49.1
Interest Rate Swap [Member]	'	'	'	'
Derivative Instruments Not Designated as Hedging Instruments [Abstract]	'	'	'	'
Realized gain (loss) on commodity derivative contracts	-1.3	-0.6	-3.2	-1.9
Unrealized gain (loss) on commodity derivative contracts	2.6	-1.4	1.1	3.5
Realized and Unrealized Gain (Loss) on Commodity Derivative Contracts Not Designated as Hedging Instruments	$1.30	($2)	($2.10)	$1.60

Restructuring_Costs_Restructur

Restructuring Costs Restructuring Costs - Narrative (Details) (USD $)	3 Months Ended	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2014
Restructuring and Related Activities [Abstract]	'	'
Estimated restructuring costs	'	$10.30
Restructuring costs incurred from inception to reporting date	'	7.9
Restructuring and Related Cost, Incurred Cost	$2.30	$7.10

Restructuring_Costs_Summary_of

Restructuring Costs - Summary of Restructuring Costs (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Restructuring costs incurred from inception to reporting date	'	'	$7.90	'
Restructuring Charges	0	0.3	0	0.8
One-time Termination Benefits [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Restructuring costs incurred from inception to reporting date	'	'	3.6	'
Restructuring Charges	0	0.2	0	0.5
Employee Relocation [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Restructuring costs incurred from inception to reporting date	'	'	3.7	'
Restructuring Charges	0	0.1	0	0.3
Termination of Lease [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Restructuring costs incurred from inception to reporting date	'	'	0.6	'
Restructuring Charges	0	0	0	0
QEP Energy [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Restructuring costs incurred from inception to reporting date	'	'	7.6	'
Restructuring Charges	0	0.2	0	0.7
QEP Energy [Member] | One-time Termination Benefits [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Restructuring costs incurred from inception to reporting date	'	'	3.3	'
Restructuring Charges	0	0.1	0	0.4
QEP Energy [Member] | Employee Relocation [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Restructuring costs incurred from inception to reporting date	'	'	3.7	'
Restructuring Charges	0	0.1	0	0.3
QEP Energy [Member] | Termination of Lease [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Restructuring costs incurred from inception to reporting date	'	'	0.6	'
Restructuring Charges	0	0	0	0
QEP Marketing [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Restructuring costs incurred from inception to reporting date	'	'	0.3	'
Restructuring Charges	0	0.1	0	0.1
QEP Marketing [Member] | One-time Termination Benefits [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Restructuring costs incurred from inception to reporting date	'	'	0.3	'
Restructuring Charges	$0	$0.10	$0	$0.10

Debt_Narrative_Details

Debt (Narrative) (Details) (USD $)	3 Months Ended	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Debt Instrument [Line Items]	'	'	'	'
Long-term Debt, Gross	$3,119,300,000	$3,119,300,000	'	$3,001,800,000
Revolving credit facility origination fees	'	-1,100,000	'	'
Less unamortized discount	-3,800,000	-3,800,000	'	-4,300,000
Debt Maturity Period	'5 years 0 months 0 days	'	'	'
Proceeds from Issuance of Long-term Debt	'	300,000,000	0	'
Principal amount of senior notes outstanding	2,221,800,000	2,221,800,000	'	'
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 2016 [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Long-term Debt, Gross	297,500,000	297,500,000	'	480,000,000
Maturity date of long-term debt	'	25-Aug-16	'	'
Borrowing capacity	1,500,000,000	1,500,000,000	'	'
Potential increased borrowing capacity	2,000,000,000	2,000,000,000	'	'
NumberOfMaturityDateExtensions	2	2	'	'
Additional period with in which maturity to be extended	'	'1 year	'	'
Weighted-average interest rate (in hundredths)	2.22%	2.22%	2.56%	'
Amount outstanding	297,500,000	297,500,000	'	'
Letters of credit outstanding	3,800,000	3,800,000	'	'
Term Loan due 2017 [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Long-term Debt, Gross	600,000,000	600,000,000	'	300,000,000
Maturity date of long-term debt	'	18-Apr-17	'	'
Additional period with in which maturity to be extended	'	'1 year	'	'
Weighted-average interest rate (in hundredths)	2.26%	2.26%	2.23%	'
6.05% Senior Notes due 2016 [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Long-term Debt, Gross	176,800,000	176,800,000	'	176,800,000
Long-term debt, interest rate (in hundredths)	6.05%	6.05%	'	'
Maturity date of long-term debt	'	1-Sep-16	'	'
6.80% Senior Notes due 2018 [Member]	'	'	'	'
Debt Instrument [Line Items]	'	'	'	'
Long-term Debt, Gross	$134,000,000	$134,000,000	'	$134,000,000
Long-term debt, interest rate (in hundredths)	6.80%	6.80%	'	'
Maturity date of long-term debt	'	1-Apr-18	'	'

Debt_Schedule_of_Debt_Instrume

Debt Schedule of Debt Instruments (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Debt Instrument [Line Items]	'	'
Long-term Debt, Gross	$3,119.30	$3,001.80
Less unamortized discount	-3.8	-4.3
Long-term Debt	3,115.50	2,997.50
Line of Credit [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term Debt, Gross	297.5	480
Term Loan due 2017 [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term Debt, Gross	600	300
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 $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2014
Loss Contingencies [Line Items]	'	'
Deferred Revenue	'	$13.20
Administrative penalty	0.2	'
Loss Contingency, Range of Possible Loss, Maximum	'	$20

EquityBased_Compensation_Detai

Equity-Based Compensation (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014		Sep. 30, 2013
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'	'	'		'
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant	10,900,000	'	10,900,000		'
Weighted-Average Price [Abstract]	'	'	'		'
Equity-based compensation	'	'	$20.70		$20
Continuing Operations [Member]	'	'	'		'
Weighted-Average Price [Abstract]	'	'	'		'
Equity-based compensation	6.4	5.5	17.7		17.9
Discontinued Operations [Member]	'	'	'		'
Weighted-Average Price [Abstract]	'	'	'		'
Equity-based compensation	0.9	1.3	3		2.1
Stock Options [Member]	'	'	'		'
Options Outstanding [RollForward]	'	'	'		'
Outstanding Beginning Balance (in shares)	'	'	1,794,187		'
Granted (in shares)	'	'	282,236		'
Exercised (in shares)	'	'	-65,366		'
Forfeited (in shares)	'	'	-14,842		'
Outstanding Ending Balance (in shares)	1,996,215	'	1,996,215		'
Options Excercisable (in shares)	1,452,138	'	1,452,138		'
Unvested Options (in shares)	544,077	'	544,077		'
Weighted-Average Price [Abstract]	'	'	'		'
Weighted-Average Price, beginning (in dollars per share)	'	'	$27.90		'
Weighted-Average Price, Granted (in dollars per share)	'	'	$31.67		'
Weighted-Average Price, Exercised (in dollars per share)	'	'	$22.24		'
Weighted-Average Price, Forfeited (in dollars per share)	'	'	$30.53		'
Weighted-Average Price, Ending (in dollars per share)	$28.60	'	$28.60		'
Weighted-Average Price, Options Excercisable	$27.71	'	$27.71		'
Weighted-Average Price, Unvested Options	$30.97	'	$30.97		'
Weighted-Average Remaining Contractual Term, Outstanding	'	'	'3 years 5 months 4 days		'
Aggregate Intrinsic Value, Outstanding	6.3	'	6.3		'
Weighted-Average Remaining Contractual Term, Options Excercisable	'	'	'2 years 6 months 22 days		'
Aggregate Intrinsic Value, Options Excercisable	6.2	'	6.2		'
Weighted-Average Remaining Contractual Term, Unvested Options	'	'	'5 years 8 months 29 days		'
Aggregate Intrinsic Value, Unvested Options	0.2	'	0.2		'
Intrinsic value of options exercised	'	'	0.6		4.2
Unrecognized compensation cost	2.7	'	2.7		'
Weighted-average period for recognition of compensation costs	'	'	'2 years 20 days		'
Employee Service Share-based Compensation, Cash Received from Exercise of Stock Options	'	'	1.5		'
Restricted Stock [Member]	'	'	'		'
Options Outstanding [RollForward]	'	'	'		'
Total fair value of stock that vested	'	'	20.2		18.4
Shares Outstanding [Roll Forward]	'	'	'		'
Balance, beginning (in shares)	'	'	1,388,953		'
Granted (in shares)	'	'	968,118		'
Vested and paid out (in shares)	'	'	-637,677		'
Forfeited (in shares)	'	'	-116,238		'
Balance, Ending (in shares)	1,603,156	'	1,603,156		'
Weighted-Average Price [Abstract]	'	'	'		'
Weighted-Average Price, Forfeited (in dollars per share)	'	'	$30.96		'
Weighted-Average Price, beginning balance (in dollars per share)	'	'	$30.96		'
Weighted-Average Price, Granted (in dollars per share)	'	'	$31.82		$30.03
Weighted-Average Price, Vested and paid out (in dollars per share)	'	'	$31.63		'
Weighted-Average Price, Ending Balance (in dollars per share)	$31.22	'	$31.22		'
Unrecognized compensation cost	18.2	'	18.2		'
Weighted-average period for recognition of compensation costs	'	'	'2 years 3 months 4 days		'
Vesting period (in years)	'	'	'3 years 0 months 0 days		'
Performance Share Units [Member]	'	'	'		'
Shares Outstanding [Roll Forward]	'	'	'		'
Balance, beginning (in shares)	'	'	480,660		'
Granted (in shares)	'	'	252,161		'
Vested and paid out (in shares)	'	'	-55,659		'
Forfeited (in shares)	'	'	-22,416		'
Vested and canceled (in shares)	'	'	-51,361	[1]	'
Balance, Ending (in shares)	603,385	'	603,385		'
Weighted-Average Price [Abstract]	'	'	'		'
Weighted-Average Price, Forfeited (in dollars per share)	'	'	$30.47		'
Weighted-Average Price, beginning balance (in dollars per share)	'	'	$32.33		'
Weighted-Average Price, Granted (in dollars per share)	'	'	$31.71		$30.12
Weighted-Average Price, Vested and paid out (in dollars per share)	'	'	$39.07		'
Weighted-Average Price, Vested and canceled (in dollars per share)	'	'	$39.07		'
Weighted-Average Price, Ending Balance (in dollars per share)	$30.92	'	$30.92		'
Unrecognized compensation cost	$3.20	'	$3.20		'
Weighted-average period for recognition of compensation costs	'	'	'2 years 24 days		'
[1]	Represents units that were not paid out due to not meeting performance targets. Payout of the performance share units is dependent upon the Companybs total shareholder return compared to a group of its peers over a three-year period.

EquityBased_Compensation_Sched

Equity-Based Compensation Schedule of Major Assumptions Used in Valuation Model (Details) (USD $)	9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2014
Performance Share Units [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Unrecognized compensation cost	$3.20
Stock Options [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Unrecognized compensation cost	$2.70
Fair value of options at grant date	$10.11
Risk-free interest rate (in hundredths)	1.31%
Expected price volatility (in hundredths)	37.10%
Expected dividend yield (in hundredths)	0.25%
Expected life in years	'4 years 6 months

Employee_Benefits_Details

Employee Benefits (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'		'		'		'
Loss on curtailment	'		'		$2.40		'
Expense related to special termination benefits	'		'		0.3		'
Continuing Operations [Member]	'		'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'		'		'		'
Recurring employee benefit expense	1.4		2.3		5.5		7.6
Discontinued Operations [Member]	'		'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'		'		'		'
Recurring employee benefit expense	0.4		0.7		1.4		1.9
Pension [Member]	'		'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'		'		'		'
Service cost	0.6		0.7		2		2.6
Interest cost	1.2		1.2		4		3.7
Expected return on plan assets	-1.4		-0.9		-3.8		-2.9
Amortization of prior service costs	1.1	[1]	1.2	[1]	3.6	[1]	3.7	[1]
Loss on curtailment	0		'		2		'
Expense related to special termination benefits	0		0		0.3		0
Amortization of actuarial loss	0.2	[1]	0.5	[1]	0.6	[1]	1.7	[1]
Periodic expense	1.7		2.7		8.7		8.8
Other Postretirement Benefit Plans, Defined Benefit [Member]	'		'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'		'		'		'
Service cost	0		0.1		0		0.1
Interest cost	0		0		0.2		0.2
Amortization of prior service costs	0.1	[2]	0.1	[2]	0.3	[2]	0.3	[2]
Recognized net actuarial loss	0		0.1		0		0.1
Loss on curtailment	0		'		0.4		0
Periodic expense	0.1		0.3		0.9		0.7
Funded Pension Plan [Member] | Pension [Member]	'		'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'		'		'		'
Contributions to pension plan	'		'		8.1		'
Unfunded Pension Plan [Member] | Pension [Member]	'		'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'		'		'		'
Contributions to pension plan	'		'		4.4		'
Expected to contribute to pension plans	0.6		'		'		'
Other Postretirement Benefit Plans, Defined Benefit [Member] | Pension [Member]	'		'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'		'		'		'
Expected to contribute to pension plans	$0.10		'		'		'
[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."
[2]	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_Business2

Operations by Line of Business (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Revenues	'	'	'	'	'
Total Revenues	$910	$719.50	$2,614.70	$2,064.80	'
Operating expenses	'	'	'	'	'
Purchased gas, oil and NGL expense	288.4	219.5	775.5	650.3	'
Lease operating expense	61.1	43.5	177	130.2	'
Natural gas, oil and NGL transportation and other handling costs	71.1	58.6	198.5	158.5	'
Gathering, processing and other	1.4	2.1	4.8	6.4	'
General and administrative	49.4	40.7	147	116.8	'
Production and property taxes	59.4	40.6	160.8	113.7	'
Depreciation, depletion and amortization	251.4	238.4	712.5	719.3	'
Other operating expenses	0.9	5.6	8.3	13.5	'
Total operating expenses	783.1	649	2,184.40	1,908.70	'
Net gain (loss) from asset sales	-11.8	12.8	-210.3	113.4	'
Operating income (loss)	115.1	83.3	220	269.5	'
Realized and unrealized gains (losses) on derivative contracts	155.7	-27.8	-13.2	51.6	'
Interest and other income	4.2	6.1	7.8	22.7	'
Income from unconsolidated affiliates	0.1	0	0.2	0	'
Interest expense	-41.5	-41.4	-128.4	-124.7	'
Income (loss) before income taxes	233.6	20.2	86.4	219.1	'
Income taxes	-79.9	-8.1	-26.1	-82.5	'
Income from continuing operations	153.7	12.1	60.3	136.6	'
Discontinued operations, net of income tax	17.4	25.2	58.2	74.8	'
Net income attributable to QEP	171.1	37.3	118.5	211.4	'
Assets	10,276.20	'	10,276.20	'	9,394.90
Unaffiliated customers [Member]	'	'	'	'	'
Revenues	'	'	'	'	'
Total Revenues	910	719.5	2,614.70	2,064.80	'
Affiliated customers [Member]	'	'	'	'	'
Revenues	'	'	'	'	'
Total Revenues	0	0	0	0	'
QEP Energy [Member]	'	'	'	'	'
Revenues	'	'	'	'	'
Total Revenues	652.9	538.5	1,953.30	1,575.20	'
Operating expenses	'	'	'	'	'
Purchased gas, oil and NGL expense	32.8	39.2	120.9	159.8	'
Lease operating expense	61.1	43.5	177	130.2	'
Natural gas, oil and NGL transportation and other handling costs	75.2	65.1	211.8	180.8	'
Gathering, processing and other	0	0	0	0	'
General and administrative	44.3	33.5	132	100.2	'
Production and property taxes	59.3	40.4	159.8	112.7	'
Depreciation, depletion and amortization	249	236	704.7	712.1	'
Other operating expenses	0.9	5.6	8.3	13.5	'
Total operating expenses	522.6	463.3	1,514.50	1,409.30	'
Net gain (loss) from asset sales	-11.9	12.8	-210.3	113.4	'
Operating income (loss)	118.4	88	228.5	279.3	'
Realized and unrealized gains (losses) on derivative contracts	154.1	-25.6	-9.7	49.6	'
Interest and other income	3.9	2.6	7.4	7.5	'
Income from unconsolidated affiliates	0.1	0	0.2	'	'
Interest expense	-57	-49.2	-162.5	-143.4	'
Income (loss) before income taxes	219.5	15.8	63.9	193	'
Income taxes	-72.7	-6.2	-14.6	-71.1	'
Income from continuing operations	146.8	9.6	49.3	121.9	'
Net income attributable to QEP	146.8	9.6	49.3	121.9	'
QEP Energy [Member] | Unaffiliated customers [Member]	'	'	'	'	'
Revenues	'	'	'	'	'
Total Revenues	652.9	538.5	1,953.30	1,575.20	'
QEP Energy [Member] | Affiliated customers [Member]	'	'	'	'	'
Revenues	'	'	'	'	'
Total Revenues	0	0	0	0	'
QEP Marketing and Other [Member]	'	'	'	'	'
Revenues	'	'	'	'	'
Total Revenues	674.9	446.6	1,794.30	1,175.60	'
Operating expenses	'	'	'	'	'
Purchased gas, oil and NGL expense	668.3	438.2	1,771.60	1,150.50	'
Lease operating expense	0	0	0	0	'
Natural gas, oil and NGL transportation and other handling costs	0	0	0	0	'
Gathering, processing and other	1.4	2.1	4.8	6.4	'
General and administrative	6.1	8.4	17.6	20.3	'
Production and property taxes	0.1	0.2	1	1	'
Depreciation, depletion and amortization	2.4	2.4	7.8	7.2	'
Other operating expenses	0	'	0	0	'
Total operating expenses	678.3	451.3	1,802.80	1,185.40	'
Net gain (loss) from asset sales	0.1	0	0	0	'
Operating income (loss)	-3.3	-4.7	-8.5	-9.8	'
Realized and unrealized gains (losses) on derivative contracts	1.6	-2.2	-3.5	2	'
Interest and other income	56.6	52.2	162	158.4	'
Income from unconsolidated affiliates	0	0	0	'	'
Interest expense	-40.8	-40.9	-127.5	-124.5	'
Income (loss) before income taxes	14.1	4.4	22.5	26.1	'
Income taxes	-7.2	-1.9	-11.5	-11.4	'
Income from continuing operations	6.9	2.5	11	14.7	'
Net income attributable to QEP	6.9	2.5	11	14.7	'
QEP Marketing and Other [Member] | Unaffiliated customers [Member]	'	'	'	'	'
Revenues	'	'	'	'	'
Total Revenues	257.1	181	661.4	489.6	'
QEP Marketing and Other [Member] | Affiliated customers [Member]	'	'	'	'	'
Revenues	'	'	'	'	'
Total Revenues	417.8	265.6	1,132.90	686	'
Elimination [Member]	'	'	'	'	'
Revenues	'	'	'	'	'
Total Revenues	-417.8	-265.6	-1,132.90	-686	'
Operating expenses	'	'	'	'	'
Purchased gas, oil and NGL expense	-412.7	-257.9	-1,117	-660	'
Lease operating expense	0	0	0	0	'
Natural gas, oil and NGL transportation and other handling costs	-4.1	-6.5	-13.3	-22.3	'
Gathering, processing and other	0	0	0	0	'
General and administrative	-1	-1.2	-2.6	-3.7	'
Production and property taxes	0	0	0	0	'
Depreciation, depletion and amortization	0	0	0	0	'
Other operating expenses	0	0	0	0	'
Total operating expenses	-417.8	-265.6	-1,132.90	-686	'
Net gain (loss) from asset sales	'	0	0	0	'
Operating income (loss)	0	0	0	0	'
Realized and unrealized gains (losses) on derivative contracts	0	0	0	0	'
Interest and other income	-56.3	-48.7	-161.6	-143.2	'
Income from unconsolidated affiliates	0	0	0	'	'
Interest expense	56.3	48.7	161.6	143.2	'
Income (loss) before income taxes	0	0	0	0	'
Income taxes	0	0	0	0	'
Income from continuing operations	0	0	0	0	'
Net income attributable to QEP	0	0	0	0	'
Elimination [Member] | Unaffiliated customers [Member]	'	'	'	'	'
Revenues	'	'	'	'	'
Total Revenues	0	0	0	0	'
Elimination [Member] | Affiliated customers [Member]	'	'	'	'	'
Revenues	'	'	'	'	'
Total Revenues	($417.80)	($265.60)	($1,132.90)	($686)	'

Subsequent_Event_Details

Subsequent Event (Details) (USD $)	Sep. 30, 2014
Subsequent Event [Line Items]	'
Value of midstream business sold	$2,500,000,000
Debt refinancing included in sale of midstream business	230,000,000
Aggregate sale price for announced divestiture	108,000,000
Net book value of property disposed	$37,000,000