Supplemental Gas and Oil Information (Unaudited) Estimated Quantities of Proved Gas and Oil Reserves (Details) MMBoe in Millions, MMBbls in Millions, Bcf in Millions		12 Months Ended
		Dec. 31, 2016 MMBoe Bcf MMBbls		Dec. 31, 2015 MMBoe Bcf MMBbls		Dec. 31, 2014 MMBoe Bcf MMBbls
Oil [Member]
Reserve Quantities [Line Items]
Proved reserves balance, beginning balance | MMBbls		193.1		172.5		148.6
Revisions of previous estimates | MMBbls		(9.7)	[1]	(47.0)	[2]	(4.0)	[3]
Extensions and discoveries | MMBbls		13.0	[4]	85.6	[5]	16.8	[6]
Purchase of reserves in place | MMBbls		62.7	[7]	2.0	[8]	35.7	[9]
Sale of reserves in place | MMBbls		(0.2)	[10]	(0.4)	[11]	(7.5)	[12]
Production | MMBbls		(20.3)		(19.6)		(17.1)
Proved reserves balance, ending balance | MMBbls		238.6		193.1		172.5
Proved undeveloped reserves, beginning balance | MMBbls		83.4		73.2		76.8
Proved undeveloped reserve, ending balance | MMBbls		135.4		83.4		73.2
Proved developed reserves, beginning balance | MMBbls		109.7		99.3		71.8
Proved developed reserves, ending balance | MMBbls		103.2		109.7		99.3
Gas [Member]
Reserve Quantities [Line Items]
Proved reserves balance, beginning balance | Bcf		2,108.9		2,317.2		2,554.9
Revisions of previous estimates | Bcf		412.8	[1]	(463.8)	[2]	27.1	[3]
Extensions and discoveries | Bcf		158.1	[4]	467.7	[5]	141.4	[6]
Purchase of reserves in place | Bcf		54.6	[7]	3.2	[8]	72.5	[9]
Sale of reserves in place | Bcf		(3.6)	[10]	(34.3)	[11]	(299.4)	[12]
Production | Bcf		(177.0)		(181.1)		(179.3)
Proved reserves balance, ending balance | Bcf		2,553.8		2,108.9		2,317.2
Proved undeveloped reserves, beginning balance | Bcf		863.6		1,028.8		1,148.6
Proved undeveloped reserve, ending balance | Bcf		1,244.0		863.6		1,028.8
Proved developed reserves, beginning balance | Bcf		1,245.3		1,288.4		1,406.3
Proved developed reserves, ending balance | Bcf		1,309.8		1,245.3		1,288.4
Natural Gas Liquids [Member]
Reserve Quantities [Line Items]
Proved reserves balance, beginning balance | MMBbls		58.8		96.6		102.6
Revisions of previous estimates | MMBbls		(0.3)	[1]	(55.3)	[2]	1.4	[3]
Extensions and discoveries | MMBbls		3.3	[4]	21.8	[5]	8.6	[6]
Purchase of reserves in place | MMBbls		11.5	[7]	0.6	[8]	12.3	[9]
Sale of reserves in place | MMBbls		(0.1)	[10]	(0.2)	[11]	(21.5)	[12]
Production | MMBbls		(6.0)		(4.7)		(6.8)
Proved reserves balance, ending balance | MMBbls		67.2		58.8		96.6
Proved undeveloped reserves, beginning balance | MMBbls		24.4		44.4		49.8
Proved undeveloped reserve, ending balance | MMBbls		31.5		24.4		44.4
Proved developed reserves, beginning balance | MMBbls		34.4		52.2		52.8
Proved developed reserves, ending balance | MMBbls		35.7		34.4		52.2
Barrels of oil equivalent production [Member]
Reserve Quantities [Line Items]
Proved developed and undeveloped reserves, beginning balance | MMBoe	[13]	603.4		655.3		677.0
Revisions of previous estimates | MMBoe	[13]	58.8	[1]	(179.6)	[2]	1.9	[3]
Extensions and discoveries | MMBoe	[13]	42.6	[4]	185.4	[5]	49.0	[6]
Purchase of reserves in place | MMBoe	[13]	83.3	[7]	3.1	[8]	60.1	[9]
Sale of reserves in place | MMBoe	[13]	(0.9)	[10]	(6.3)	[11]	(78.9)	[12]
Production | MMBoe	[13]	(55.8)		(54.5)		(53.8)
Proved developed and undeveloped reserves, ending balance | MMBoe	[13]	731.4		603.4		655.3
Proved undeveloped reserves, beginning balance | MMBoe		251.8		289.1		318.0
Proved undeveloped reserves, ending balance | MMBoe		374.2		251.8		289.1
Proved developed reserves, beginning balance | MMBoe		351.6		366.2		359.0
Proved developed reserves, ending balance | MMBoe		357.2		351.6		366.2
Pricing Revisions [Member]
Reserve Quantities [Line Items]
Revisions of previous estimates | MMBoe		18.5		126.2		3.8
Pricing Revisions [Member] | Gas [Member]
Reserve Quantities [Line Items]
Revisions of previous estimates | MMBoe						3.7
Performance Revisions [Member]
Reserve Quantities [Line Items]
Revisions of previous estimates | MMBoe		5.5		13.7		41.4
Positive revisions [Member] | Barrels of oil equivalent production [Member]
Reserve Quantities [Line Items]
Revisions of previous estimates | MMBoe		77.3
Operating Cost Revisions [Member]
Reserve Quantities [Line Items]
Revisions of previous estimates | MMBoe						6.5
Other Revisions [Member]
Reserve Quantities [Line Items]
Revisions of previous estimates | MMBoe				67.2		33.0
Williston Basin [Member] | Barrels of oil equivalent production [Member]
Reserve Quantities [Line Items]
Extensions and discoveries | MMBoe				68.2		20.6
Pinedale [Member] | Barrels of oil equivalent production [Member]
Reserve Quantities [Line Items]
Extensions and discoveries | MMBoe						22.3
Pinedale [Member] | Performance Revisions [Member]
Reserve Quantities [Line Items]
Revisions of previous estimates | MMBoe						32.3
Uinta Basin [Member] | Barrels of oil equivalent production [Member]
Reserve Quantities [Line Items]
Extensions and discoveries | MMBoe				53.2
Permian Basin [Member] | Barrels of oil equivalent production [Member]
Reserve Quantities [Line Items]
Extensions and discoveries | MMBoe				49.6

[1] Revisions of previous estimates in 2016 include 77.3 MMboe of positive revisions, primarily related to successful workovers in Haynesville/Cotton Valley; reserves associated with increased density wells in areas that have been previously developed on lower density spacing; and 5.5 MMboe of positive performance revisions. These positive revisions were partially offset by 18.5 MMboe of negative revisions related to pricing, driven by lower oil, gas and NGL prices.

[2] Revisions of previous estimates in 2015 include: 126.2 MMboe of negative revisions due to lower pricing and 67.2 MMboe of negative revisions unrelated to pricing, partially offset by 13.7 MMboe of positive performance revisions. Negative pricing revisions were driven by lower oil, gas and NGL prices. Negative other revisions included operating in ethane rejection in Pinedale and the Uinta Basin.

[3] Revisions of previous estimates in 2014 include 41.4 MMboe negative performance revisions partially offset by positive other revisions of 33.0 MMboe, operating cost revisions of 6.5 MMboe and pricing revisions of 3.8 MMboe. Negative performance revisions were driven by a 32.3 MMboe decrease in Pinedale reserves related to downward forecast revisions on proved developed (PDP) wells, additional production history on PUD to PDP performance and a downward adjustment in the number of PUD locations. Other negative revisions related to adjustments to shrink and lease operating expense. Pricing revisions were primarily due to increased gas prices, which increased reserves by 3.7 MMboe.

[4] Extensions and discoveries in 2016 were primarily in the Permian and Uinta basins and related to new well completions and associated new PUD locations.

[5] Extensions and discoveries in 2015 increased proved reserves by 185.4 MMboe, primarily related to extensions and discoveries in the Williston Basin of 68.2 MMboe, the Uinta Basin of 53.2 MMboe, and the Permian Basin of 49.6 MMboe. All of these extensions and discoveries related to new well completions and associated new PUD locations

[6] Extensions and discoveries in 2014 increased proved reserves by 49.0 MMboe, primarily related to extensions and discoveries in Pinedale of 22.3 MMboe and the Williston Basin of 20.6 MMboe. All of these extensions and discoveries related to new well completions and associated new PUD locations as well as new compression well projections in Pinedale.

[7] Purchase of reserves in place in 2016 relate primarily to the Company's 2016 Permian Basin Acquisition as discussed in Note 2 – Acquisitions and Divestitures.

[8] Purchase of reserves in place in 2015 related to the acquisition of additional interests in QEP operated wells in the Williston Basin as discussed in Note 2 – Acquisitions and Divestitures

[9] Purchase of reserves in place in 2014 relate to the Company's 2014 Permian Basin Acquisition as discussed in Note 2 – Acquisitions and Divestitures.

[10] Sale of reserves in place in 2016 relate to the divestiture of QEP's interest in certain non-core properties as discussed in Note 2 – Acquisitions and Divestitures.

[11] Sale of reserves in place in 2015 relate to the divestiture of QEP's interest in certain non-core properties as discussed in Note 2 – Acquisitions and Divestitures.

[12] Sale of reserves in place primarily related to property sales in the Other Southern area in the second and fourth quarters of 2014 as discussed in Note 2 – Acquisitions and Divestitures

[13] Proved reserves include gas reserves that QEP expects to produce and use as field fuel.