DCP Midstream (DCP-PC) 8-K 13 Jun 14 Other Events Financial data

Document_and_Entity_Informatio

Document and Entity Information	12 Months Ended
	Dec. 31, 2013
Document And Entity Information [Abstract]	'
Document Type	'8-K
Amendment Flag	'false
Document Period End Date	31-Dec-13
Entity Registrant Name	'DCP MIDSTREAM PARTNERS, LP
Entity Central Index Key	'0001338065

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Current assets:	'		'
Cash and cash equivalents	$12	[1]	$2	[1],[2],[3]
Accounts receivable:	'		'
Trade, net of allowance for doubtful accounts of $1 million and less than $1 million, respectively	130		107
Affiliates	212		132
Inventories	67		76	[3]
Unrealized gains on derivative instruments	79		49
Other	3		2
Total current assets	503	[4]	368	[3],[4]
Property, plant and equipment, net	3,046		2,592	[3]
Goodwill	154		154
Intangible assets, net	129		137
Investments in unconsolidated affiliates	627		304	[3]
Unrealized gains on derivative instruments	87		70
Other long-term assets	21		20
Total assets	4,567		3,645	[3]
Accounts payable:	'		'
Trade	232		151
Affiliates	43		72
Short-term borrowings	335		0
Unrealized losses on derivative instruments	28		31
Capital spending accrual	24		44
Other	61		47
Total current liabilities	723		345
Long-term debt	1,590		1,620	[3]
Unrealized losses on derivative instruments	1		8
Other long-term liabilities	40		36
Total liabilities	2,354		2,009	[3]
Commitments and contingent liabilities	'		'
Equity:	'		'
Predecessor equity	40	[3]	399	[3]
Limited partners (89,045,139 and 61,346,058 common units issued and outstanding, respectively)	1,948		1,063
General partner	8		0
Accumulated other comprehensive loss	-11		-15	[3]
Total partners' equity	1,985		1,447	[3]
Noncontrolling interests	228		189	[3]
Total equity	2,213		1,636	[3]
Total liabilities and equity	$4,567		$3,645	[3]
[1]	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[2]	The financial information during the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[3]	The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[4]	The segment information as of and for the years ended December 31, 2013, 2012 and 2011, includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas. Transfers of net assets between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information, similar to the pooling method.

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified
Common unitholders, units issued	89,045,139	61,346,058
Common unitholders, units outstanding	89,045,139	61,346,058
Maximum [Member]	'	'
Allowance for doubtful accounts	1	1

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Operating revenues:	'		'		'
Sales of natural gas, propane, NGLs and condensate	$2,763	[1]	$2,520	[2]	$3,574	[3]
Transportation, processing and other	271	[1]	234	[2]	208	[3]
Gains from commodity derivative activity, net	17	[1]	70	[2]	8	[3]
Total operating revenues	3,051	[1]	2,824	[2]	3,790	[3]
Operating costs and expenses:	'		'		'
Purchases of natural gas, propane and NGLs	2,426	[1]	2,215	[2]	3,155	[3]
Operating and maintenance expense	215	[1]	197	[2]	192	[3]
Depreciation and amortization expense	95	[1]	91	[2]	135	[3]
General and administrative expense	63	[1]	75	[2]	76	[3]
Other expense (income)	8	[1]	0		-1	[3]
Total operating costs and expenses	2,807	[1]	2,578	[2]	3,557	[3]
Operating income	244	[1]	246	[2]	233	[3]
Interest expense	-52	[1]	-42	[2]	-34	[3]
Earnings from unconsolidated affiliates	33	[1]	26	[2]	23	[3]
Income before income taxes	225	[1]	230	[2]	222	[3]
Income tax expense	-8	[1],[4]	-1	[2],[4]	-1	[3],[4]
Net income	217	[1]	229	[2]	221	[3]
Net income attributable to noncontrolling interests	-17	[1]	-13	[2]	-30	[3]
Net income attributable to partners	200	[1]	216	[2]	191	[3]
Net income attributable to predecessor operations	-25		-51		-91
General partner's interest in net income	-70		-41		-25
Net income allocable to limited partners	105		124		75
Net income per limited partner unit - basic (in dollars per share)	$1.34		$2.28		$1.73
Net income per limited partner unit - diluted (in dollars per share)	$1.34		$2.28		$1.72
Weighted-average limited partners units outstanding - basic (in shares)	78.4		54.5		43.5
Weighted-average limited partners units outstanding - diluted (in shares)	78.4		54.5		43.6
Third Party [Member]	'		'		'
Operating revenues:	'		'		'
Sales of natural gas, propane, NGLs and condensate	932		820		1,171
Transportation, processing and other	211		179		169
Gains from commodity derivative activity, net	-5		17		7
Operating costs and expenses:	'		'		'
Purchases of natural gas, propane and NGLs	2,159		1,807		2,445
General and administrative expense	17		17		19
Affiliated Entity [Member]	'		'		'
Operating revenues:	'		'		'
Sales of natural gas, propane, NGLs and condensate	1,831		1,700		2,403
Transportation, processing and other	60		55		39
Gains from commodity derivative activity, net	22		53		1
Operating costs and expenses:	'		'		'
Purchases of natural gas, propane and NGLs	267		408		710
General and administrative expense	$46		$58		$57
[1]	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[2]	The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[3]	The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[4]	For the year ended December 31, 2011, income tax expense relates primarily to the Texas margin tax and the Michigan business tax. The Michigan business tax was repealed in 2012; accordingly, income tax expense for the years ended December 31, 2013 and 2012 relates primarily to the Texas margin tax.

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Statement of Comprehensive Income [Abstract]	'		'		'
Net income	$217	[1]	$229	[2]	$221	[3]
Other comprehensive income (loss):	'		'		'
Reclassification of cash flow hedge losses into earnings	4		10	[2]	21	[3]
Net unrealized losses on cash flow hedges	0		0		-13
Net unrealized losses on cash flow hedges - predecessor operations	'		-1		-2
Total other comprehensive income	4		9	[2]	6	[3]
Total comprehensive income	221		238	[2]	227	[3]
Total comprehensive income attributable to noncontrolling interests	-17		-13	[2]	-30	[3]
Total comprehensive income attributable to partners	$204		$225	[2]	$197	[3]
[1]	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[2]	The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[3]	The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Consolidated_Statements_of_Cha

Consolidated Statements of Changes in Equity (USD $)

Total

Eagle Ford System [Member]

Southeast Texas and NGL Hedge [Member]

Southeast Texas [Member]

East Texas [Member]

Mont Belvieu Fractionators [Member]

Eagle Ford System and NGL Hedge [Member]

Eagle Ford System and Commodity Hedge [Member]

Predecessor Equity [Member]

Predecessor Equity [Member]

Predecessor Equity [Member]

Predecessor Equity [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

General Partner [Member]

Accumulated Other Comprehensive (Loss) Income [Member]

Noncontrolling Interests [Member]

Noncontrolling Interests [Member]

Noncontrolling Interests [Member]

In Millions

Eagle Ford System [Member]

Southeast Texas and NGL Hedge [Member]

Southeast Texas [Member]

Eagle Ford System [Member]

Southeast Texas and NGL Hedge [Member]

Southeast Texas [Member]

East Texas [Member]

Mont Belvieu Fractionators [Member]

Eagle Ford System and NGL Hedge [Member]

Eagle Ford System and Commodity Hedge [Member]

Eagle Ford System [Member]

East Texas [Member]

Beginning balance at Dec. 31, 2010

$1,460

'

'

'

'

'

'

'

$654

'

'

'

$552

'

'

'

'

'

'

'

($6)

($28)

$288

'

'

Net income

221

[1]

'

'

'

'

'

'

'

91

'

'

'

75

'

'

'

'

'

'

'

25

'

30

'

'

Other comprehensive (loss) income

6

[1]

'

'

'

'

'

'

'

-2

'

'

'

'

'

'

'

'

'

'

'

'

8

'

'

'

Net change in parent advances

57

'

'

'

'

'

'

'

42

'

'

'

'

'

'

'

'

'

'

'

'

'

15

'

'

Payments to Acquire Equity Method Investments

'

'

'

114

'

'

'

'

'

'

'

114

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity-based compensation

3

'

'

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

Excess purchase price over carrying value of acquired net assets

-36

'

'

'

'

'

'

'

'

'

'

'

-35

'

'

'

'

'

'

'

'

-1

'

'

'

Issuance of common units

170

'

'

'

'

'

'

'

'

'

'

'

170

'

'

'

'

'

'

'

'

'

'

'

'

Distributions to limited partners and general partner

-132

'

'

'

'

'

'

'

'

'

'

'

-108

'

'

'

'

'

'

'

-24

'

'

'

'

Distributions to noncontrolling interests

-45

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-45

'

'

Contributions from noncontrolling interests

18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

18

'

'

Payments of Ordinary Dividends, Noncontrolling Interest

-45

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distributions to DCP Midstream, LLC

-3

'

'

'

'

'

'

'

'

'

'

'

-3

'

'

'

'

'

'

'

'

'

'

'

'

Ending balance at Dec. 31, 2011

1,605

'

'

'

'

'

'

'

671

'

'

'

654

'

'

'

'

'

'

'

-5

-21

306

'

'

Net income

229

[2]

'

'

'

'

'

'

'

51

'

'

'

124

'

'

'

'

'

'

'

41

'

13

'

'

Other comprehensive (loss) income

9

[2]

'

'

'

'

'

'

'

-1

'

'

'

'

'

'

'

'

'

'

'

'

10

'

'

'

Net change in parent advances

221

'

'

'

'

'

'

'

181

'

'

'

'

'

'

'

'

'

'

'

'

'

40

'

'

Payments to Acquire Equity Method Investments

'

-232

'

'

'

'

'

'

'

-232

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of additional interest in subsidiary

'

'

-208

'

-176

'

'

'

'

'

-248

'

'

'

40

'

'

'

'

'

'

'

'

'

-176

Issuance of units

'

88

'

48

33

60

'

'

'

'

'

'

'

88

'

48

33

60

'

'

'

'

'

'

'

Deficit purchase price under carrying value of acquired net assets

32

'

'

'

'

'

'

'

'

'

'

'

36

'

'

'

'

'

'

'

'

-4

'

'

'

Excess purchase price over carrying value of acquired net assets

'

-42

'

'

'

-175

-156

'

'

-23

'

'

'

-9

'

'

'

-175

-156

'

'

'

'

-10

'

Issuance of common units

455

'

'

'

'

'

'

'

'

'

'

'

455

'

'

'

'

'

'

'

'

'

'

'

'

Distributions to limited partners and general partner

-181

'

'

'

'

'

'

'

'

'

'

'

-145

'

'

'

'

'

'

'

-36

'

'

'

'

Distributions to noncontrolling interests

-9

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-9

'

'

Contributions from noncontrolling interests

25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25

'

'

Payments of Ordinary Dividends, Noncontrolling Interest

[3]

-9

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contributions from DCP Midstream, LLC

10

'

'

'

'

'

'

'

'

'

'

'

10

'

'

'

'

'

'

'

'

'

'

'

'

Ending balance at Dec. 31, 2012

1,636

[4]

'

'

'

'

'

'

'

399

'

'

'

1,063

'

'

'

'

'

'

'

0

-15

189

'

'

Net income

217

[5]

'

'

'

'

'

'

'

25

'

'

'

105

'

'

'

'

'

'

'

70

'

17

'

'

Other comprehensive (loss) income

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

Net change in parent advances

11

'

'

'

'

'

'

'

11

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of additional interest in subsidiary

'

-395

'

'

'

'

'

'

'

-395

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of units

'

125

'

'

'

'

'

'

'

'

'

'

'

125

'

'

'

'

'

'

'

'

'

'

'

Excess purchase price over carrying value of acquired net assets

'

'

'

'

'

'

-7

-203

'

'

'

'

'

'

'

'

'

'

-7

-203

'

'

'

'

'

Issuance of common units

1,082

'

'

'

'

'

'

'

'

'

'

'

1,082

'

'

'

'

'

'

'

'

'

'

'

'

Distributions to limited partners and general partner

-277

'

'

'

'

'

'

'

'

'

'

'

-215

'

'

'

'

'

'

'

-62

'

'

'

'

Distributions to noncontrolling interests

-24

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-24

'

'

Contributions from noncontrolling interests

46

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

46

'

'

Payments of Ordinary Dividends, Noncontrolling Interest

[5]

-24

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contributions from DCP Midstream, LLC

1

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

Distributions to DCP Midstream, LLC

-3

'

'

'

'

'

'

'

'

'

'

'

-3

'

'

'

'

'

'

'

'

'

'

'

'

Ending balance at Dec. 31, 2013

$2,213

'

'

'

'

'

'

'

$40

'

'

'

$1,948

'

'

'

'

'

'

'

$8

($11)

$228

'

'

[1]

The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[2]

The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[3]

The financial information during the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[4]

The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[5]

The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Consolidated_Statements_of_Cha1

Consolidated Statements of Changes in Equity (Parenthetical)

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Limited Partners [Member]

Limited Partners [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System and NGL Hedge [Member]

Eagle Ford System and NGL Hedge [Member]

Eagle Ford System and NGL Hedge [Member]

Eagle Ford System and NGL Hedge [Member]

Eagle Ford System and Commodity Hedge [Member]

Eagle Ford System and Commodity Hedge [Member]

East Texas [Member]

East Texas [Member]

Southeast Texas and NGL Hedge [Member]

Southeast Texas and NGL Hedge [Member]

Predecessor Equity [Member]

Predecessor Equity [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

Noncontrolling Interests [Member]

Predecessor Equity [Member]

Ownership interest acquired

'

'

'

'

'

46.67%

33.33%

33.33%

33.33%

33.33%

33.33%

33.33%

46.67%

46.67%

49.90%

49.90%

66.67%

66.67%

Issuance of common units

24,897,977

11,285,956

4,357,921

11,285,956

4,357,921

'

'

'

'

'

'

'

'

'

'

'

'

'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
OPERATING ACTIVITIES:	'		'		'
Net income	$217	[1]	$229	[2]	$221	[3]
Adjustments to reconcile net income to net cash provided by operating activities:	'		'		'
Depreciation and amortization expense	95	[1]	91	[2]	135	[3]
Earnings from unconsolidated affiliates	-33	[1]	-26	[2]	-23	[3]
Distributions from unconsolidated affiliates	39		24		25
Net unrealized losses (gains) on derivative instruments	36	[4]	-21	[4]	-40	[4]
Deferred income taxes, net	5		0		-29
Other, net	14		3		5
Change in operating assets and liabilities, which (used) provided cash, net of effects of acquisitions:	'		'		'
Accounts receivable	-89		-11		34
Inventories	9		14		-14
Accounts payable	51		-194		106
Accrued interest	5		5		0
Other current assets and liabilities	-2		-4		2
Other long-term assets and liabilities	-2		-8		-5
Net cash provided by operating activities	345	[1]	102	[5]	417
INVESTING ACTIVITIES:	'		'		'
Capital expenditures	-363	[1]	-484	[5]	-385
Acquisitions, net of cash acquired	-696	[1]	-433		-38
Acquisition of unconsolidated affiliates	-86	[1]	-312		-114
Investments in unconsolidated affiliates	-242	[1]	-158	[5]	-8
Return of investment from unconsolidated affiliate	0		1	[5]	2
Proceeds from sales of assets	0		2	[5]	5
Net cash used in investing activities	-1,387	[1]	-1,384	[5]	-538
FINANCING ACTIVITIES:	'		'		'
Proceeds from long-term debt	1,957	[1]	2,665	[5]	1,524
Payments of long-term debt	-1,988	[1]	-1,792	[5]	-1,425
Proceeds from issuance of commercial paper	335	[1]	0		0
Payments of deferred financing costs	-4	[1]	-8	[5]	-4
Excess purchase price over acquired interests and commodity hedges	-85	[1]	-225	[5]	-36
Proceeds from issuance of common units, net of offering costs	1,083	[1]	455	[5]	170
Net change in advances to predecessor from DCP Midstream, LLC	11	[1]	336	[5]	52
Distributions to limited partners and general partner	-277	[1]	-181	[5]	-132
Distributions to noncontrolling interests	-24	[1]	-9	[5]	-45
Contributions from noncontrolling interests	46	[1]	25	[5]	18
Distributions to DCP Midstream, LLC	-3	[1]	0		0
Contributions from DCP Midstream, LLC	1	[1]	10	[5]	0
Net cash provided by financing activities	1,052	[1]	1,276	[5]	122
Net change in cash and cash equivalents	10	[1]	-6	[5]	1
Cash and cash equivalents, beginning of year	2	[1],[5],[6]	8	[5]	7
Cash and cash equivalents, end of year	$12	[1]	$2	[1],[5],[6]	$8	[5]
[1]	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[2]	The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[3]	The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[4]	Non-cash commodity derivative mark-to-market is included in segment gross margin, along with cash settlements for our commodity derivative contracts.
[5]	The financial information during the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[6]	The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Description_of_Business_and_Ba

Description of Business and Basis of Presentation	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Description of Business and Basis of Presentation	'
	Description of Business and Basis of Presentation
	DCP Midstream Partners, LP, with its consolidated subsidiaries, or us, we, our or the Partnership, is engaged in the business of gathering, compressing, treating, processing, transporting, storing and selling natural gas; producing, fractionating, transporting, storing and selling NGLs and recovering and selling condensate; and transporting, storing and selling propane in wholesale markets.
	We are a Delaware limited partnership that was formed in August 2005. Our partnership includes: our natural gas services segment (which includes our 80% interest in the Eagle Ford system, our 100% owned Eagle Plant; our East Texas system; our Southeast Texas system; our Michigan system; our Northern Louisiana system; our Southern Oklahoma system; our Wyoming system; a 75% interest in Collbran Valley Gas Gathering, LLC, or Collbran or our Piceance system; our 40% interest in Discovery Producer Services LLC, or Discovery; and our DJ Basin system, consisting of our O'Connor and Lucerne 1 plants), our NGL logistics segment (which includes the NGL storage facility in Michigan, our 12.5% interest in the Mont Belvieu Enterprise fractionator, our 20% interest in the Mont Belvieu 1 fractionator, the Black Lake and Wattenberg interstate NGL pipelines, the DJ Basin NGL fractionators, the Seabreeze and Wilbreeze intrastate NGL pipelines, our 33.33% interest in the Front Range interstate NGL pipeline, and our 10% interest in the Texas Express intrastate NGL pipeline), and our wholesale propane logistics segment (which includes six rail terminals, two marine terminals and one pipeline terminal).
	Our operations and activities are managed by our general partner, DCP Midstream GP, LP, which in turn is managed by its general partner, DCP Midstream GP, LLC, which we refer to as the General Partner, and is 100% owned by DCP Midstream, LLC. DCP Midstream, LLC and its subsidiaries and affiliates, collectively referred to as DCP Midstream, LLC, is owned 50% by Phillips 66 and 50% by Spectra Energy Corp and its affiliates, or Spectra Energy. DCP Midstream, LLC directs our business operations through its ownership and control of the General Partner. DCP Midstream, LLC and its affiliates’ employees provide administrative support to us and operate most of our assets. DCP Midstream, LLC owns approximately 23% of us.
	The consolidated financial statements include the accounts of the Partnership and all majority-owned subsidiaries where we have the ability to exercise control. Investments in greater than 20% owned affiliates that are not variable interest entities and where we do not have the ability to exercise control, and investments in less than 20% owned affiliates where we have the ability to exercise significant influence, are accounted for using the equity method. All intercompany balances and transactions have been eliminated.
	Our predecessor operations consist of a 66.67% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business, which we acquired from DCP Midstream, LLC in March 2012, an 80% interest in the Eagle Ford system, of which we acquired 33.33% and 46.67% in November 2012 and March 2013, respectively, from DCP Midstream, LLC, and our 100% interest in DCP Lucerne 1 Plant, LLC, a 35 MMcf/d cryogenic natural gas processing plant located in Weld County, Colorado, or the Lucerne 1 plant, which we acquired from DCP Midstream, LLC in March 2014. Prior to our acquisition of the remaining 66.67% interest in Southeast Texas, we accounted for our initial 33.33% interest as an unconsolidated affiliate using the equity method. Subsequent to the March 2012 transaction, we own 100% of Southeast Texas which we account for as a consolidated subsidiary. Prior to our acquisition of the additional 46.67% interest in the Eagle Ford system in March 2013, we accounted for our initial 33.33% interest as an unconsolidated affiliate using the equity method. Subsequent to the March 2013 transaction, we own 80% of the Eagle Ford system which we account for as a consolidated subsidiary. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years were retrospectively adjusted to furnish comparative information, similar to the pooling method. Accordingly, our consolidated financial statements include the historical results of our 100% interest in Southeast Texas and the commodity derivative hedge instruments associated with the storage business, our 80% interest in the Eagle Ford system and our Lucerne 1 plant for all periods presented. We recognize transfers of net assets between entities under common control at DCP Midstream, LLC’s basis in the net assets contributed. The amount of the purchase price in excess or in deficit of DCP Midstream, LLC’s basis in the net assets is recognized as a reduction or an addition to limited partners’ equity. The financial statements of our predecessor have been prepared from the separate records maintained by DCP Midstream, LLC and may not necessarily be indicative of the conditions that would have existed or the results of operations if our predecessor had been operated as an unaffiliated entity. In addition, the results of operations for acquisitions accounted for as business combinations have been included in the consolidated financial statements since their respective acquisition dates.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	Summary of Significant Accounting Policies
	Use of Estimates - Conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and notes. Although these estimates are based on management’s best available knowledge of current and expected future events, actual results could differ from those estimates.
	Cash and Cash Equivalents - We consider investments in highly liquid financial instruments purchased with an original stated maturity of 90 days or less and temporary investments of cash in short-term money market securities to be cash equivalents.
	Inventories - Inventories, which consist primarily of NGLs and natural gas, are recorded at the lower of weighted-average cost or market value. Transportation costs are included in inventory.
	Property, Plant and Equipment - Property, plant and equipment are recorded at historical cost. The cost of maintenance and repairs, which are not significant improvements, are expensed when incurred. Depreciation is computed using the straight-line method over the estimated useful lives of the assets.
	Goodwill and Intangible Assets - Goodwill is the cost of an acquisition less the fair value of the net assets of the acquired business. We perform an annual impairment test of goodwill at the reporting unit level during the third quarter, and update the test during interim periods when we believe events or changes in circumstances indicate that we may not be able to recover the carrying value of a reporting unit. We primarily use a discounted cash flow analysis, supplemented by a market approach analysis, to perform the assessment. Key assumptions in the analysis include the use of an appropriate discount rate, terminal year multiples, and estimated future cash flows including an estimate of operating and general and administrative costs. In estimating cash flows, we incorporate current market information, as well as historical and other factors, into our forecasted commodity prices.
	Intangible assets consist of customer contracts, including commodity purchase, transportation and processing contracts, and related relationships. These intangible assets are amortized on a straight-line basis over the period of expected future benefit. Intangible assets are removed from the gross carrying amount and the total of accumulated amortization in the period in which they become fully amortized.
	Long-Lived Assets - We periodically evaluate whether the carrying value of long-lived assets, including intangible assets, has been impaired when circumstances indicate the carrying value of those assets may not be recoverable. This evaluation is based on undiscounted cash flow projections. The carrying amount is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. We consider various factors when determining if these assets should be evaluated for impairment, including but not limited to:
	•	significant adverse change in legal factors or business climate;
	•	a current-period operating or cash flow loss combined with a history of operating or cash flow losses, or a projection or forecast that demonstrates continuing losses associated with the use of a long-lived asset;
	•	an accumulation of costs significantly in excess of the amount originally expected for the acquisition or construction of a long-lived asset;
	•	significant adverse changes in the extent or manner in which an asset is used, or in its physical condition;
	•	a significant adverse change in the market value of an asset; or
	•	a current expectation that, more likely than not, an asset will be sold or otherwise disposed of before the end of its estimated useful life.
	If the carrying value is not recoverable, the impairment loss is measured as the excess of the asset’s carrying value over its fair value. We assess the fair value of long-lived assets using commonly accepted techniques, and may use more than one method, including, but not limited to, recent third party comparable sales and discounted cash flow models. Significant changes in market conditions resulting from events such as the condition of an asset or a change in management’s intent to utilize the asset would generally require management to reassess the cash flows related to the long-lived assets.
	Asset Retirement Obligations - Our asset retirement obligations relate primarily to the retirement of various gathering pipelines and processing facilities, obligations related to right-of-way easement agreements, and contractual leases for land use. We adjust our asset retirement obligation each quarter for any liabilities incurred or settled during the period, accretion expense and any revisions made to the estimated cash flows.
	Asset retirement obligations associated with tangible long-lived assets are recorded at fair value in the period in which they are incurred, if a reasonable estimate of fair value can be made, and added to the carrying amount of the associated asset. This additional carrying amount is then depreciated over the life of the asset. The liability is determined using a risk free interest rate, and accretes due to the passage of time based on the time value of money until the obligation is settled.
	Investments in Unconsolidated Affiliates - We use the equity method to account for investments in greater than 20% owned affiliates that are not variable interest entities and where we do not have the ability to exercise control, and investments in less than 20% owned affiliates where we have the ability to exercise significant influence.
	We evaluate our investments in unconsolidated affiliates for impairment whenever events or changes in circumstances indicate that the carrying value of such investments may have experienced a decline in value. When there is evidence of loss in value, we compare the estimated fair value of the investment to the carrying value of the investment to determine whether impairment has occurred. We assess the fair value of our investments in unconsolidated affiliates using commonly accepted techniques, and may use more than one method, including, but not limited to, recent third party comparable sales and discounted cash flow models. If the estimated fair value is considered to be permanently less than the carrying value, the excess of the carrying value over the estimated fair value is recognized as an impairment loss.
	Unamortized Debt Expense - Expenses incurred with the issuance of long-term debt are amortized over the term of the debt using the effective interest method. These expenses are recorded on the consolidated balance sheet as other long-term assets.
	Noncontrolling Interest - Noncontrolling interest represents any third party or affiliate interest in non-wholly owned entities that we consolidate. For financial reporting purposes, the assets and liabilities of these entities are consolidated with those of our own, with any third party or affiliate interest in our consolidated balance sheet amounts shown as noncontrolling interest in equity. Distributions to and contributions from noncontrolling interests represent cash payments to and cash contributions from, respectively, such third party and affiliate investors.
	Accounting for Risk Management Activities and Financial Instruments - Non-trading energy commodity derivatives are designated as either a hedge of a forecasted transaction or future cash flow (cash flow hedge), a hedge of a recognized asset, liability or firm commitment (fair value hedge), or normal purchases or normal sales. The remaining non-trading derivatives, which are related to asset-based activities for which the normal purchase or normal sale exception is not elected, are recorded at fair value in the consolidated balance sheets as unrealized gains or unrealized losses in derivative instruments, with changes in the fair value recognized in the consolidated statements of operations. For each derivative, the accounting method and presentation of gains and losses or revenue and expense in the consolidated statements of operations are as follows:
	Classification of Contract	Accounting Method	Presentation of Gains & Losses or Revenue & Expense
	Cash Flow Hedge	Hedge method (a)	Gross basis in the same consolidated statements of operations category as the related hedged item
	Fair Value Hedge	Hedge method (a)	Gross basis in the same consolidated statements of operations category as the related hedged item
	Normal Purchases or Normal Sales	Accrual method (b)	Gross basis upon settlement in the corresponding consolidated statements of operations category based on purchase or sale
	Other Non-Trading Derivative Activity	Mark-to-market method (c)	Net basis in gains and losses from commodity derivative activity
	______________
	(a)	Hedge method - An accounting method whereby the change in the fair value of the asset or liability is recorded in the consolidated balance sheets as unrealized gains or unrealized losses on derivative instruments. For cash flow hedges, there is no recognition in the consolidated statements of operations for the effective portion until the service is provided or the associated delivery period impacts earnings. For fair value hedges, the change in the fair value of the asset or liability, as well as the offsetting changes in value of the hedged item, are recognized in the consolidated statements of operations in the same category as the related hedged item.
	(b)	Accrual method - An accounting method whereby there is no recognition in the consolidated balance sheets or consolidated statements of operations for changes in fair value of a contract until the service is provided or the associated delivery period impacts earnings.
	(c)	Mark-to-market method - An accounting method whereby the change in the fair value of the asset or liability is recognized in the consolidated statements of operations in gains and losses from commodity derivative activity during the current period.
	Cash Flow and Fair Value Hedges - For derivatives designated as a cash flow hedge or a fair value hedge, we maintain formal documentation of the hedge. In addition, we formally assess both at the inception of the hedging relationship and on an ongoing basis, whether the hedge contract is highly effective in offsetting changes in cash flows or fair values of hedged items. All components of each derivative gain or loss are included in the assessment of hedge effectiveness, unless otherwise noted.
	The fair value of a derivative designated as a cash flow hedge is recorded in the consolidated balance sheets as unrealized gains or unrealized losses on derivative instruments. The change in fair value of the effective portion of a derivative designated as a cash flow hedge is recorded in partners’ equity in accumulated other comprehensive income, or AOCI, and the ineffective portion is recorded in the consolidated statements of operations. During the period in which the hedged transaction impacts earnings, amounts in AOCI associated with the hedged transaction are reclassified to the consolidated statements of operations in the same line item as the item being hedged. Hedge accounting is discontinued prospectively when it is determined that the derivative no longer qualifies as an effective hedge, or when it is probable that the hedged transaction will not occur. When hedge accounting is discontinued because the derivative no longer qualifies as an effective hedge, the derivative is subject to the mark-to-market accounting method prospectively. The derivative continues to be carried on the consolidated balance sheets at its fair value; however, subsequent changes in its fair value are recognized in current period earnings. Gains and losses related to discontinued hedges that were previously accumulated in AOCI will remain in AOCI until the hedged transaction impacts earnings, unless it is probable that the hedged transaction will not occur, in which case, the gains and losses that were previously deferred in AOCI will be immediately recognized in current period earnings.
	The fair value of a derivative designated as a fair value hedge is recorded for balance sheet purposes as unrealized gains or unrealized losses on derivative instruments. We recognize the gain or loss on the derivative instrument, as well as the offsetting loss or gain on the hedged item in earnings in the current period. All derivatives designated and accounted for as fair value hedges are classified in the same category as the item being hedged in the results of operations.
	Valuation - When available, quoted market prices or prices obtained through external sources are used to determine a contract’s fair value. For contracts with a delivery location or duration for which quoted market prices are not available, fair value is determined based on pricing models developed primarily from historical relationships with quoted market prices and the expected relationship with quoted market prices.
	Values are adjusted to reflect the credit risk inherent in the transaction as well as the potential impact of liquidating open positions in an orderly manner over a reasonable time period under current conditions. Changes in market prices and management estimates directly affect the estimated fair value of these contracts. Accordingly, it is reasonably possible that such estimates may change in the near term.
	Revenue Recognition - We generate the majority of our revenues from gathering, compressing, treating, processing, transporting, storing and selling of natural gas, and producing, fractionating, transporting, storing and selling NGLs and recovering and selling condensate. Once natural gas is produced from wells, producers then seek to deliver the natural gas and its components to end-use markets. We realize revenues either by selling the residue natural gas, NGLs and condensate, or by receiving fees. We also generate revenue from transporting, storing and selling propane.
	We obtain access to commodities and provide our midstream services principally under contracts that contain a combination of one or more of the following arrangements:
	•	Fee-based arrangements - Under fee-based arrangements, we receive a fee or fees for one or more of the following services: gathering, compressing, treating, processing, transporting or storing natural gas; and fractionating, storing and transporting NGLs. Our fee-based arrangements include natural gas arrangements pursuant to which we obtain natural gas at the wellhead or other receipt points, at an index related price at the delivery point less a specified amount, generally the same as the transportation fees we would otherwise charge for transportation of natural gas from the wellhead location to the delivery point. The revenues we earn are directly related to the volume of natural gas or NGLs that flows through our systems and are not directly dependent on commodity prices. However, to the extent a sustained decline in commodity prices results in a decline in volumes, our revenues from these arrangements would be reduced.
	•	Percent-of-proceeds/liquids arrangements - Under percent-of-proceeds arrangements, we generally purchase natural gas from producers at the wellhead, or other receipt points, gather the wellhead natural gas through our gathering system, treat and process the natural gas, and then sell the resulting residue natural gas, NGLs and condensate based on index prices from published index market prices. We remit to the producers either an agreed-upon percentage of the actual proceeds that we receive from our sales of the residue natural gas, NGLs and condensate, or an agreed-upon percentage of the proceeds based on index related prices for the natural gas, NGLs and condensate, regardless of the actual amount of the sales proceeds we receive. We keep the difference between the proceeds received and the amount remitted back to the producer. Under percent-of-liquids arrangements, we do not keep any amounts related to residue natural gas proceeds and only keep amounts related to the difference between the proceeds received and the amount remitted back to the producer related to NGLs and condensate. Certain of these arrangements may also result in the producer retaining title to all or a portion of the residue natural gas and/or the NGLs, in lieu of us returning sales proceeds to the producer. Additionally, these arrangements may include fee-based components. Our revenues under percent-of-proceeds arrangements relate directly with the price of natural gas, NGLs and condensate. Our revenues under percent-of-liquids arrangements relate directly with the price of NGLs and condensate.
	•	Propane sales arrangements - Under propane sales arrangements, we generally purchase propane from natural gas processing plants and fractionation facilities, and crude oil refineries. We sell propane on a wholesale basis to propane distributors, who in turn resell to their customers. Our sales of propane are not contingent upon the resale of propane by propane distributors to their customers.
	Our marketing of natural gas and NGLs consists of physical purchases and sales, as well as positions in derivative instruments.
	We recognize revenues for sales and services under the four revenue recognition criteria, as follows:
	•	Persuasive evidence of an arrangement exists - Our customary practice is to enter into a written contract.
	•	Delivery - Delivery is deemed to have occurred at the time custody is transferred, or in the case of fee-based arrangements, when the services are rendered. To the extent we retain product as inventory, delivery occurs when the inventory is subsequently sold and custody is transferred to the third party purchaser.
	•	The fee is fixed or determinable - We negotiate the fee for our services at the outset of our fee-based arrangements. In these arrangements, the fees are nonrefundable. For other arrangements, the amount of revenue, based on contractual terms, is determinable when the sale of the applicable product has been completed upon delivery and transfer of custody.
	•	Collectability is reasonably assured - Collectability is evaluated on a customer-by-customer basis. New and existing customers are subject to a credit review process, which evaluates the customers’ financial position (for example, credit metrics, liquidity and credit rating) and their ability to pay. If collectability is not considered probable at the outset of an arrangement in accordance with our credit review process, revenue is not recognized until the cash is collected.
	We generally report revenues gross in the consolidated statements of operations, as we typically act as the principal in these transactions, take custody to the product, and incur the risks and rewards of ownership. We recognize revenues for non-trading commodity derivative activity net in the consolidated statements of operations as gains and losses from commodity derivative activity. These activities include mark-to-market gains and losses on energy trading contracts and the settlement of financial and physical energy trading contracts.
	Quantities of natural gas or NGLs over-delivered or under-delivered related to imbalance agreements with customers, producers or pipelines are recorded monthly as accounts receivable or accounts payable using current market prices or the weighted-average prices of natural gas or NGLs at the plant or system. These balances are settled with deliveries of natural gas or NGLs, or with cash.
	Significant Customers - There were no third party customers that accounted for more than 10% of total operating revenues for the years ended December 31, 2013, 2012 and 2011. We had significant transactions with affiliates.
	Environmental Expenditures - Environmental expenditures are expensed or capitalized as appropriate, depending upon the future economic benefit. Expenditures that relate to an existing condition caused by past operations and that do not generate current or future revenue are expensed. Liabilities for these expenditures are recorded on an undiscounted basis when environmental assessments and/or clean-ups are probable and the costs can be reasonably estimated. Environmental liabilities included in the consolidated balance sheets as other current liabilities amounted to $1 million, and other long-term liabilities amounted to $1 million at both December 31, 2013 and 2012.
	Equity-Based Compensation - Equity classified share-based compensation cost is measured at fair value, based on the closing common unit price at grant date, and is recognized as expense over the vesting period. Liability classified share-based compensation cost is remeasured at each reporting date at fair value, based on the closing common unit price, and is recognized as expense over the requisite service period. Compensation expense for awards with graded vesting provisions is recognized on a straight-line basis over the requisite service period of each separately vesting portion of the award. Awards granted to non-employees for acquiring, or in conjunction with selling, goods and services are measured at the estimated fair value of the goods or services, or the fair value of the award, whichever is more reliably measured.
	Allowance for Doubtful Accounts - Management estimates the amount of required allowances for the potential non-collectability of accounts receivable generally based upon the number of days past due, past collection experience and consideration of other relevant factors. However, past experience may not be indicative of future collections and therefore additional charges could be incurred in the future to reflect differences between estimated and actual collections.
	Income Taxes - We are structured as a master limited partnership which is a pass-through entity for federal income tax purposes. Our income tax expense includes certain jurisdictions, including state, local, franchise and margin taxes of the master limited partnership and subsidiaries. We follow the asset and liability method of accounting for income taxes. Under this method, deferred income taxes are recognized for the tax consequences of temporary differences between the financial statement carrying amounts and the tax basis of the assets and liabilities. Our taxable income or loss, which may vary substantially from the net income or loss reported in the consolidated statements of operations, is proportionately included in the federal returns of each partner.
	Net Income or Loss per Limited Partner Unit - Basic and diluted net income or loss per limited partner unit, or LPU, is calculated by dividing net income or loss allocable to limited partners, by the weighted-average number of outstanding LPUs during the period. Diluted net income or loss per limited partner unit is computed based on the weighted average number of units plus the effect of dilutive potential units outstanding during the period using the two-class method.
	Capitalized Interest - We capitalize interest during construction of major projects. Interest is calculated on the monthly outstanding capital balance and ceases in the month that the asset is placed into service. We also capitalize interest on our equity method investments which are devoting substantially all efforts to establishing a new business and have not yet begun planned principal operations. Capitalization ceases when the investee commences planned principal operations. The rates used to calculate capitalized interest are the weighted-average cost of debt, including the impact of interest rate swaps.

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Acquisitions	'
	Acquisitions
	On March 28, 2014, we acquired the Lucerne 1 Plant from DCP Midstream, LLC and its affiliates. The Lucerne 1 plant, along with our O'Connor plant, comprises our DJ Basin system. In conjunction with our acquisition of the Lucerne 1 plant, we entered into a long-term fee-based processing agreement with DCP Midstream, LLC pursuant to which DCP Midstream, LLC agreed to pay us (i) a fixed demand charge of 75% of the plant's capacity, and (ii) a throughput fee on all volumes processed for DCP Midstream, LLC at the Lucerne 1 plant. The acquisition of the Lucerne 1 plant represents a transaction between entities under common control and a change in reporting entity. Accordingly, our consolidated financial statements have been adjusted to retrospectively include the historical results of the Lucerne 1 plant for all periods presented, similar to the pooling method. Also in March 2014, DCP Midstream, LLC and its affiliates contributed or sold to us (i) the remaining 20% interest in DCP SC Texas GP; (ii) a 33.33% membership interest in each DCP Southern Hills Pipeline, LLC, which owns the Southern Hills pipeline, and DCP Sand Hills Pipeline, LLC, which owns the Sand Hills pipeline; and (iii) a 200 MMcf/d cryogenic natural gas processing plant also located in Weld County, Colorado, which is currently under construction, or the Lucerne 2 plant. The March 2014 transactions are discussed in Note 22. "Subsequent Events".
	On August 5, 2013, we entered into a purchase and sale agreement with DCP Midstream, LP, or Midstream LP, a 100% owned subsidiary of DCP Midstream, LLC, pursuant to which the Partnership acquired from Midstream LP all of the membership interests in DCP LaSalle Plant LLC, or the LaSalle Transaction, for consideration of $209 million, subject to certain customary purchase price adjustments. The LaSalle Transaction was financed at closing using borrowings under our revolving credit facility.
	DCP LaSalle Plant LLC owns the O'Connor plant, a cryogenic natural gas processing plant in Weld County, Colorado with initial capacity of 110 MMcf/d. Prior to the start of commercial operations in October 2013, the O'Connor plant was known as the LaSalle plant. The LaSalle Transaction represents a transfer of assets between entities under common control. The results of the O'Connor plant are included prospectively from the date of contribution in our Natural Gas Services segment. As of February 2014, the O'Connor plant expansion to 160 MMcf/d is mechanically complete.
	On August 5, 2013, we entered into a purchase and sale agreement with Midstream LP pursuant to which the Partnership acquired from Midstream LP all of the membership interests in DCP Midstream Front Range LLC, or Front Range, for consideration of $86 million, subject to certain customary purchase price adjustments, or the Front Range Transaction. The Front Range Transaction was financed at closing using borrowings under our revolving credit facility.
	Front Range owns a 33.33% equity interest in Front Range Pipeline LLC, a joint venture with affiliates of Enterprise Products Partners L.P., or Enterprise, and Anadarko Petroleum Corporation. The joint venture was formed to construct a new raw NGL mix pipeline that originates in the DJ Basin and extends approximately 435 miles to Skellytown, Texas, or the Front Range pipeline. With connections to the Mid-America pipeline, and to the Texas Express pipeline, in which the Partnership owns a 10% interest, the Front Range pipeline provides takeaway capacity and market access to the Gulf Coast for the expanding production of NGLs in the DJ Basin. The Front Range pipeline connects to the O'Connor plant as well as third party and DCP Midstream, LLC plants in the DJ Basin. The initial capacity of the Front Range pipeline is expected to be 150 MBbls/d, which could be expanded to 230 MBbls/d with the installation of additional pump stations. Enterprise is the operator of the pipeline, which was placed into service in February 2014. The Front Range pipeline currently has transportation agreements in place with affiliates of DCP Midstream, LLC and others. The transportation agreements provide for ship-or-pay arrangements for the first 10 years for a minimum volume specified in the agreement, with the last five years under plant dedication arrangements. The Front Range transaction represents a transfer of assets between entities under common control. The results of Front Range are included prospectively from the date of contribution in our NGL Logistics segment.
	On March 28, 2013, we acquired an additional 46.67% interest in DCP SC Texas GP, or the Eagle Ford system, from DCP Midstream, LLC and an $87 million fixed price commodity derivative hedge for a three-year period for aggregate consideration of $626 million, plus customary working capital and other purchase price adjustments. $490 million of the consideration was financed with the net proceeds from our 3.875% 10-year Senior Notes offering, $125 million was financed by the issuance at closing of an aggregate 2,789,739 of our common units to DCP Midstream, LLC and the remaining $11 million was paid with cash on hand. We also reimbursed DCP Midstream, LLC $50 million for 46.67% of the capital spent to date by the Eagle Ford system for the construction of the Goliad plant, plus an incremental payment of $23 million as reimbursement for 46.67% of preformation capital expenditures. The $203 million excess purchase price over the carrying value of the acquired interest in the Eagle Ford system, as adjusted for customary working capital and other purchase price adjustments, was recorded as a decrease in limited partners’ equity. Prior to the acquisition of the additional interest in the Eagle Ford system, we owned a 33.33% interest which we accounted for as an unconsolidated affiliate using the equity method. The Eagle Ford system acquisition represents a transaction between entities under common control and a change in reporting entity. Accordingly, our consolidated financial statements have been adjusted to retrospectively include the historical results of our 80% interest in the Eagle Ford system for all periods presented, similar to the pooling method.
	The assets and liabilities of our Lucerne 1 plant are included in the consolidated balance sheet as of December 31, 2013. The following table presents the previously reported December 31, 2013 consolidated balance sheet, adjusted for the acquisition of our Lucerne 1 plant from DCP Midstream, LLC:
	As of December 31, 2013
		DCP				Consolidate Lucerne 1 plant			Consolidated DCP Midstream Partners, LP (As currently reported)
		Midstream
		Partners, LP
		(As previously
		reported on Form 10-K filed on 2/26/14)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	12			$	—		$	12
	Accounts receivable	342				—			342
	Inventories	67				—			67
	Other	82				—			82
	Total current assets	503				—			503
	Property, plant and equipment, net	3,005				41			3,046
	Goodwill and intangible assets, net	283				—			283
	Investments in unconsolidated affiliates	627				—			627
	Other non-current assets	108				—			108
	Total assets	$	4,526			$	41		$	4,567
	LIABILITIES AND EQUITY
	Accounts payable and other current liabilities	$	722			$	1		$	723
	Long-term debt	1,590				—			1,590
	Other long-term liabilities	41				—			41
	Total liabilities	2,353				1			2,354
	Commitments and contingent liabilities
	Equity:
	Partners’ equity
	Net equity	1,956				40			1,996
	Accumulated other comprehensive loss	(11		)		—			(11		)
	Total partners’ equity	1,945				40			1,985
	Noncontrolling interests	228				—			228
	Total equity	2,173				40			2,213
	Total liabilities and equity	$	4,526			$	41		$	4,567
	The assets and liabilities of our Lucerne 1 plant are included in the consolidated balance sheet as of December 31, 2012. The following table presents the previously reported December 31, 2012 consolidated balance sheet, adjusted for the acquisition of our Lucerne 1 plant from DCP Midstream, LLC:
	As of December 31, 2012
		DCP				Consolidate Lucerne 1 plant			Consolidated DCP Midstream Partners, LP (As currently reported)
		Midstream
		Partners, LP
		(As previously
		reported on Form 10-K filed on 2/26/14)
		(Millions)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	2			$	—		$	2
	Accounts receivable	239				—			239
	Inventories	76				—			76
	Other	51				—			51
	Total current assets	368				—			368
	Property, plant and equipment, net	2,550				42			2,592
	Goodwill and intangible assets, net	291				—			291
	Investments in unconsolidated affiliates	304				—			304
	Other non-current assets	90				—			90
	Total assets	$	3,603			$	42		$	3,645
	LIABILITIES AND EQUITY
	Accounts payable and other current liabilities	$	345			$	—		$	345
	Long-term debt	1,620				—			1,620
Other long-term liabilities	44				—			44
Total liabilities	2,009				—			2,009
Commitments and contingent liabilities
Equity:
Partners’ equity
Net equity	1,420				42			1,462
Accumulated other comprehensive loss	(15		)		—			(15		)
Total partners’ equity	1,405				42			1,447
Noncontrolling interests	189				—			189
Total equity	1,594				42			1,636
Total liabilities and equity	$	3,603			$	42		$	3,645
The results of our Lucerne 1 plant are included in the consolidated statement of operations for the year ended December 31, 2013. The following table presents the previously reported consolidated statement of operations for the year ended December 31, 2013, adjusted for the acquisition of our Lucerne 1 plant from DCP Midstream, LLC:
Year ended December 31, 2013
		DCP				Consolidate Lucerne 1 plant			Consolidated DCP Midstream Partners, LP (As currently reported)
		Midstream
		Partners, LP
		(As previously
		reported on Form 10-K filed on 2/26/14)
	(Millions)
Sales of natural gas, propane, NGLs and condensate		$	2,695			$	68		$	2,763
Transportation, processing and other		268				3			271
Gains from commodity derivative activity, net		17				—			17
Total operating revenues		2,980				71			3,051
Operating costs and expenses:
Purchases of natural gas, propane and NGLs		2,381				45			2,426
Operating and maintenance expense		211				4			215
Depreciation and amortization expense		93				2			95
General and administrative expense		62				1			63
Other income		8				—			8
Total operating costs and expenses		2,755				52			2,807
Operating income		225				19			244
Interest expense		(52		)		—			(52		)
Earnings from unconsolidated affiliates		33				—			33
Income before income taxes		206				19			225
Income tax expense		(8		)		—			(8		)
Net income		198				19			217
Net income attributable to noncontrolling interests		(17		)		—			(17		)
Net income attributable to partners		$	181			$	19		$	200
The results of our Lucerne 1 plant are included in the consolidated statement of operations for the year ended December 31, 2012. The following table presents the previously reported consolidated statement of operations for the year ended December 31, 2012, adjusted for the acquisition of our Lucerne 1 plant from DCP Midstream, LLC:
Year Ended December 31, 2012
	DCP				Consolidate Lucerne 1 plant			Consolidated DCP Midstream Partners, LP (As currently reported)
	Midstream
	Partners, LP
	(As previously
	reported on Form 10-K filed on 2/26/14)
	(Millions)
Sales of natural gas, propane, NGLs and condensate	$	2,459			$	61		$	2,520
Transportation, processing and other	232				2			234
Losses from commodity derivative activity, net	70				—			70
Total operating revenues	2,761				63			2,824
Operating costs and expenses:
Purchases of natural gas, propane and NGLs	2,177				38			2,215
Operating and maintenance expense	193				4			197
Depreciation and amortization expense	89				2			91
General and administrative expense	74				1			75
Total operating costs and expenses	2,533				45			2,578
Operating income	228				18			246
Interest expense	(42		)		—			(42		)
Earnings from unconsolidated affiliates	26				—			26
Income before income taxes	212				18			230
Income tax expense	(1		)		—			(1		)
Net income	211				18			229
Net income attributable to noncontrolling interests	(13		)		—			(13		)
Net income attributable to partners	$	198			$	18		$	216
Year Ended December 31, 2011
The results of our Lucerne 1 plant are included in the consolidated statement of operations for the year ended December 31, 2011. The following table presents the previously reported consolidated statement of operations for the year ended December 31, 2011 adjusted for the acquisition of our Lucerne 1 plant from DCP Midstream, LLC:
		DCP				Consolidate Lucerne 1 plant			Consolidated DCP Midstream Partners, LP (As currently reported)
		Midstream
		Partners, LP
		(As previously
		reported on Form 10-K filed on 2/26/14)
		(Millions)
Sales of natural gas, propane, NGLs and condensate		$	3,487			$	87		$	3,574
Transportation, processing and other		205				3			208
Gains from commodity derivative activity, net		8				—			8
Total operating revenues		3,700				90			3,790
Operating costs and expenses:
Purchases of natural gas, propane and NGLs		3,100				55			3,155
Operating and maintenance expense		188				4			192
Depreciation and amortization expense		133				2			135
General and administrative expense		75				1			76
Other income		(1		)		—			(1		)
Total operating costs and expenses		3,495				62			3,557
Operating income		205				28			233
Interest expense		(34		)		—			(34		)
Earnings from unconsolidated affiliates		23				—			23
Income before income taxes		194				28			222
Income tax expense		(1		)		—			(1		)
Net income		193				28			221
Net income attributable to noncontrolling interests		(30		)		—			(30		)
Net income attributable to partners		$	163			$	28		$	191
On July 3, 2012, we acquired the Crossroads processing plant and associated gathering system from Penn Virginia Resource Partners, L.P. for $63 million. The acquisition was financed at closing with borrowings under our revolving credit facility. The Crossroads system, located in the southeastern portion of Harrison County in East Texas, includes approximately 8 miles of gas gathering pipeline, an 80 MMcf/d cryogenic processing plant, approximately 20 miles of NGL pipeline and a 50% ownership interest in an approximately 11-mile residue gas pipeline, or CrossPoint Pipeline, LLC, which we accounted for as an unconsolidated affiliate using the equity method. The Crossroads system is a part of our East Texas system, which is included in our Natural Gas Services segment.
We accounted for the Crossroads business combination based on estimates of the fair value of assets acquired and liabilities assumed, including: property, plant and equipment; the equity investment in CrossPoint Pipeline, LLC; a liability for a firm transportation agreement which expires in 2015; and a gas purchase agreement under which a portion of those firm transportation payments are recoverable. Expected cash payments and receipts were recorded at their estimated fair value and are included in other current liabilities, other long-term liabilities, and accounts receivable as of the acquisition date. The following table summarizes the aggregate consideration and fair value of the identifiable assets acquired and liabilities assumed in the acquisition of Crossroads as of the acquisition date:
	3-Jul-12
	(Millions)
Aggregate consideration	$	63
Accounts receivable	$	4
Property, plant and equipment	63
Investments in unconsolidated affiliates	6
Other current liabilities	(4		)
Other long-term liabilities	(6		)
Total	$	63
The results of operations for acquisitions accounted for as a business combination are included in our results subsequent to the date of acquisition. Accordingly, total operating revenues of $22 million and net income of $1 million associated with Crossroads from the acquisition date to December 31, 2012 are included in our consolidated statement of operations for the year ended December 31, 2012.
Supplemental pro forma information is presented for comparative periods prior to the date of acquisition; however, comparative periods in the consolidated financial statements are not adjusted to include the results of the acquisition. The following tables present unaudited supplemental pro forma information for the consolidated statement of operations for the years ended December 31, 2012 and 2011, as if the acquisition of Crossroads had occurred at the beginning of the earliest period presented.
	Year Ended December 31, 2012
	DCP Midstream Partners, LP				Acquisition of			DCP Midstream Partners, LP Pro Forma
					Crossroads (a)
	(Millions)
Total operating revenues	$	2,824			$	27		$	2,851
Net income attributable to partners	$	216			$	2		$	218
Less:
Net income attributable to predecessor operations	(51		)		—			(51		)
General partner’s interest in net income	(41		)		—			(41		)
Net income allocable to limited partners	$	124			$	2		$	126
Net income per limited partner unit - basic and diluted	$	2.28			$	0.03		$	2.31
(a)	The year ended December 31, 2012 includes the financial results of Crossroads for the period from January 1, 2012 through July 2, 2012.
	Year Ended December 31, 2011
	DCP Midstream Partners, LP				Acquisition of			DCP Midstream Partners, LP Pro Forma
					Crossroads
	(Millions)
Total operating revenues	$	3,790			$	114		$	3,904
Net income attributable to partners	$	191			$	4		$	195
Less:
Net income attributable to predecessor operations	(91		)		—			(91		)
General partner’s interest in net income	(25		)		—			(25		)
Net income allocable to limited partners	$	75			$	4		$	79
Net income per limited partner unit - basic	$	1.73			$	0.09		$	1.82
Net income per limited partner unit - diluted	$	1.72			$	0.09		$	1.81
The supplemental pro forma total operating revenues for the year ended December 31, 2012 was adjusted to eliminate $5 million related to a contractual gas processing arrangement between us and Crossroads during the period.
The supplemental pro forma information is not intended to reflect actual results that would have occurred if the acquired business had been combined during the periods presented, nor is it intended to be indicative of the results of operations that may be achieved by us in the future.

Agreements_and_Transactions_wi

Agreements and Transactions with Affiliates	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Agreements and Transactions with Affiliates	'
	Agreements and Transactions with Affiliates
	DCP Midstream, LLC
	Services Agreement and Other General and Administrative Charges
	We have entered into a services agreement, as amended, or the Services Agreement, with DCP Midstream, LLC. Under the Services Agreement, which replaced the Omnibus Agreement on February 14, 2013, we are required to reimburse DCP Midstream, LLC for salaries of operating personnel and employee benefits, as well as capital expenditures, maintenance and repair costs, taxes and other direct costs incurred by DCP Midstream, LLC on our behalf. We also pay DCP Midstream, LLC an annual fee under the Services Agreement for centralized corporate functions performed by DCP Midstream, LLC on our behalf, including legal, accounting, cash management, insurance administration and claims processing, risk management, health, safety and environmental, information technology, human resources, credit, payroll, taxes and engineering. Except with respect to the annual fee, there is no limit on the reimbursements we make to DCP Midstream, LLC under the Services Agreement for other expenses and expenditures incurred or payments made on our behalf. Pursuant to the Services Agreement, we will reimburse DCP Midstream, LLC for expenses and expenditures incurred or payments made on our behalf.
	The Services Agreement fee is subject to adjustment based on the scope of general and administrative services performed by DCP Midstream, LLC.
	The following is a summary of the fees we incurred under the Services and Omnibus Agreements, as well as other fees paid to DCP Midstream, LLC:
			Year Ended
			December 31,
			2013			2012		2011
			(Millions)
	Services/Omnibus Agreement		$	29		$	26	$	10
	Other fees — DCP Midstream, LLC		17			32		47
	Total — DCP Midstream, LLC		$	46		$	58	$	57
	In addition to the fees paid pursuant to the Services and Omnibus Agreements, we incurred allocated expenses, including insurance and internal audit fees with DCP Midstream, LLC of $2 million for the year ended December 31, 2013 and $1 million for each of the years ended December 31, 2012 and 2011, respectively. The Lucerne 1 plant incurred $1 million in general and administrative expenses directly from DCP Midstream, LLC for each of the years ended December 31, 2013, 2012 and 2011. The Eagle Ford system incurred $14 million for the year ended December 31, 2013 and $27 million for each of the years ended December 31, 2012 and 2011, respectively, in general and administrative expenses directly from DCP Midstream, LLC. For the years ended December 31, 2012 and 2011, Southeast Texas incurred $3 million and $10 million in general and administrative expenses directly from DCP Midstream, LLC, before the addition of Southeast Texas to the Omnibus Agreement in March 2012. During the year ended December 31, 2011, East Texas incurred $8 million in general and administrative expenses directly from DCP Midstream, LLC.
	Competition
	None of DCP Midstream, LLC, or any of its affiliates, including Phillips 66 and Spectra Energy, is restricted, under either the partnership agreement or the Services Agreement, from competing with us. DCP Midstream, LLC and any of its affiliates, including Phillips 66 and Spectra Energy, may acquire, construct or dispose of additional midstream energy or other assets in the future without any obligation to offer us the opportunity to purchase or construct those assets.
	Other Agreements and Transactions with DCP Midstream, LLC
	DCP Midstream, LLC was a significant customer during the years ended December 31, 2013, 2012 and 2011. We sell a portion of our residue gas, NGLs and condensate to, purchase natural gas and other petroleum products from, and provide gathering and transportation services for, DCP Midstream, LLC. We anticipate continuing to purchase from and sell commodities and services to DCP Midstream, LLC in the ordinary course of business. In addition, DCP Midstream, LLC conducts derivative activities on our behalf. We have and may continue to enter into derivative transactions directly with DCP Midstream, LLC, whereby DCP Midstream, LLC is the counterparty.
	We have a contractual arrangement with DCP Midstream, LLC, through March 2022, in which we pay DCP Midstream, LLC a fee for processing services associated with the gas we gather on our Southern Oklahoma system, which is part of our Natural Gas Services segment. In addition, we have an agreement with DCP Midstream, LLC providing for adjustments to those fees based upon plant efficiencies related to our portion of volumes from the Southern Oklahoma system being processed at DCP Midstream, LLC’s plant through March 2022. We generally report fees associated with these activities in the consolidated statements of operations as purchases of natural gas, propane and NGLs from affiliates. In addition, as part of this arrangement, DCP Midstream, LLC pays us a fee for certain gathering services. We generally report revenues associated with these activities in the consolidated statements of operations as transportation, processing and other to affiliates.
	DCP Midstream, LLC owns certain assets and is party to certain contractual relationships around our Pelico system, included in our Northern Louisiana system, which is part of our Natural Gas Services segment, that are periodically used for the benefit of Pelico. DCP Midstream, LLC is able to source natural gas upstream of Pelico and deliver it to us and is able to take natural gas from the outlet of the Pelico system and market it downstream of Pelico. We purchase natural gas from DCP Midstream, LLC upstream of Pelico and transport it to Pelico under an interruptible transportation agreement with an affiliate. Our purchases from DCP Midstream, LLC are at DCP Midstream, LLC’s actual acquisition cost plus any transportation service charges. Volumes that exceed our on-system demand are sold to DCP Midstream, LLC at an index-based price, less contractually agreed upon marketing fees. Revenues associated with these activities are reported gross in our consolidated statements of operations as sales of natural gas, propane, NGLs and condensate to affiliates.
	In our Natural Gas Services segment, we sell NGLs processed at certain of our plants, and sell condensate removed from the gas gathering systems that deliver to certain of our systems under contracts to a subsidiary of DCP Midstream, LLC equal to that subsidiary’s net weighted-average sales price, adjusted for transportation, processing and other charges from the tailgate of the respective asset.
	In conjunction with our acquisitions of our East Texas and Southeast Texas systems, which are part of our Natural Gas Services segment, we entered into agreements with DCP Midstream, LLC whereby DCP Midstream, LLC will reimburse us for certain expenditures on East Texas and Southeast Texas capital projects. These reimbursements are for specific capital projects which have commenced within three years from the respective acquisition dates. DCP Midstream, LLC made capital contributions to East Texas for capital projects of $1 million, $5 million and $18 million for the years ended December 31, 2013, 2012, and 2011 respectively. DCP Midstream, LLC made capital contributions to Southeast Texas for capital projects of $5 million for the year ended December 31, 2012. We made a distribution to DCP Midstream, LLC related to capital projects at Southeast Texas of $3 million for the year ended December 31, 2013.
	In conjunction with our acquisition of the O'Connor plant, we entered into a 15-year fee-based processing agreement with an affiliate of DCP Midstream, LLC pursuant to which such affiliate agreed to pay us (i) a fixed demand charge of 75% of the plant's capacity, and (ii) a throughput fee on all volumes processed for such affiliate at the O'Connor plant. Under this agreement, we received fees of $6 million during the year ended December 31, 2013, which are included in transportation, processing and other to affiliates in the consolidated statements of operations.
	As a result of a downstream outage, certain of our assets were required to curtail NGL production during 2012. DCP Midstream, LLC has reimbursed us for the impact of the curtailment and accordingly, we recorded $3 million to sales of natural gas, propane, NGLs and condensate to affiliates and less than $1 million to transportation, processing and other to affiliates in the consolidated statements of operations for the year ended December 31, 2012.
	During the year ended December 31, 2011, East Texas received $8 million in business interruption recoveries related to the first quarter 2009 fire that was caused by a third party underground pipeline rupture outside of our property, or the East Texas recovery settlement. We have allocated the recoveries based upon relative ownership percentages at the time the losses were incurred, factoring in amounts previously reimbursed to us by DCP Midstream, LLC. For the year ended December 31, 2011, we recorded $7 million to sales of natural gas, propane, NGLs and condensate, with $5 million representing DCP Midstream, LLC’s portion recorded in net income attributable to noncontrolling interests, in the consolidated statement of operations.
	In our NGL Logistics segment, we also have a contractual arrangement with a subsidiary of DCP Midstream, LLC that provides that DCP Midstream, LLC will pay us to transport NGLs over our Seabreeze and Wilbreeze pipelines, pursuant to fee-based rates that will be applied to the volumes transported. DCP Midstream, LLC is the sole shipper on these pipelines under the transportation agreements. We generally report revenues associated with these activities in the consolidated statements of operations as transportation, processing and other to affiliates.
	The Texas Express Pipeline has in place a long-term, fee-based, ship-or-pay transportation agreement with DCP Midstream, LLC of 20 MBbls/d.
	The Wattenberg pipeline has in place a 10-year dedication and transportation agreement with a subsidiary of DCP Midstream, LLC whereby certain NGL volumes produced at several of DCP Midstream, LLC’s processing facilities are dedicated for transportation on the Wattenberg pipeline. We collect fee-based transportation revenues under our tariff. We generally report revenues associated with these activities in the consolidated statements of operations as transportation, processing and other to affiliates.
	We pay a fee to DCP Midstream, LLC to operate our DJ Basin NGL fractionators and receive fees for the processing of DCP Midstream, LLC’s committed NGLs produced by them in Colorado at our DJ Basin NGL fractionators under agreements that are effective through March 2018. We incurred fees of $1 million and less than $1 million during the years ended December 31, 2013 and 2012, respectively, which are included in operating and maintenance expense in the consolidated statements of operations.
	Spectra Energy
	We had propane supply agreements with Spectra Energy that expired in April 2012, which provided us propane supply at our marine terminals, included in our Wholesale Propane Logistics segment, for up to approximately 185 million gallons of propane annually.
	Summary of Transactions with Affiliates
	The following table summarizes our transactions with affiliates:
			Year Ended
			December 31,
			2013			2012		2011
			(Millions)
	DCP Midstream, LLC:
	Sales of natural gas, propane, NGLs and condensate		$	1,830		$	1,691	$	2,346
	Transportation, processing and other		$	60		$	52	$	30
	Purchases of natural gas, propane and NGLs		$	204		$	173	$	244
	Gains from commodity derivative activity, net		$	22		$	53	$	1
	Operating and maintenance expense		$	1		$	1	$	1
	General and administrative expense		$	46		$	58	$	57
	Phillips 66:
	Sales of natural gas, propane, NGLs and condensate		$	1		$	—	$	—
	ConocoPhillips (a):
	Sales of natural gas, propane, NGLs and condensate		$	—		$	9	$	57
	Transportation, processing and other		$	—		$	3	$	9
	Purchases of natural gas, propane and NGLs		$	—		$	67	$	139
	Spectra Energy:
	Purchases of natural gas, propane and NGLs		$	63		$	166	$	321
	Unconsolidated affiliates:
	Purchases of natural gas, propane and NGLs		$	—		$	2	$	6
	(a)	In connection with Phillips 66's separation from ConocoPhillips, ConocoPhillips is not considered to be a related party for periods after April 30, 2012 and Phillips 66 is considered a related party for periods starting May 1, 2012.
	We had balances with affiliates as follows:
		December 31,			December 31,
		2013			2012
		(Millions)
	DCP Midstream, LLC:
	Accounts receivable	$	211		$	132
	Accounts payable	$	37		$	66
	Unrealized gains on derivative instruments — current	$	79		$	48
Unrealized gains on derivative instruments — long-term	$	81		$	64
Unrealized losses on derivative instruments — current	$	18		$	(11	)
Unrealized losses on derivative instruments — long-term	$	1		$	—
Spectra Energy:
Accounts receivable	$	1		$	—
Accounts payable	$	6		$	5
Unconsolidated affiliates:
Accounts payable	$	—		$	1

Inventories

Inventories	12 Months Ended
	Dec. 31, 2013
Inventory Disclosure [Abstract]	'
Inventories	'
	Inventories
	Inventories were as follows:
		December 31,		December 31,
		2013		2012
		(Millions)
	Natural gas	$	38	$	22
	NGLs	29		54
	Total inventories	$	67	$	76
	We recognize lower of cost or market adjustments when the carrying value of our inventories exceeds their estimated market value. These non-cash charges are a component of purchases of natural gas, propane and NGLs in the consolidated statements of operations. We recognized $4 million and $19 million in lower of cost or market adjustments during the years ended December 31, 2013 and 2012, respectively.

Property_Plant_and_Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment	'
	Property, Plant and Equipment
	A summary of property, plant and equipment by classification is as follows:
		Depreciable	December 31,			December 31,
		Life	2013			2012
			(Millions)
	Gathering and transmission systems	20 — 50 Years	$	2,205		$	1,921
	Processing, storage, and terminal facilities	35 — 60 Years	1,645			1,154
	Other	3 —  30 Years	49			32
	Construction work in progress		310			561
	Property, plant and equipment		4,209			3,668
	Accumulated depreciation		(1,163		)	(1,076		)
	Property, plant and equipment, net		$	3,046		$	2,592
	Interest capitalized on construction projects in 2013, 2012 and 2011 was $11 million, $7 million and $2 million, respectively.
	We revised the depreciable lives for our gathering and transmission systems, processing, storage and terminal facilities, and other assets effective April 1, 2012. The key contributing factors to the change in depreciable lives is an increase in the producers' estimated remaining economically recoverable reserves resulting from the widespread application of techniques, such as hydraulic fracturing and horizontal drilling, that improve commodity production in the regions our assets serve. Advances in extraction processes, along with better technology used to locate commodity reserves, is giving producers greater access to unconventional commodities. Based on our property, plant and equipment as of April 1, 2012, the new remaining depreciable lives resulted in an approximate $52 million reduction in depreciation expense for the year ended December 31, 2012. This change in our estimated depreciable lives increased net income per limited partner unit by $0.95 for the year ended December 31, 2012.
	Depreciation expense was $87 million, $83 million, and $127 million for the years ended December 31, 2013, 2012, and 2011, respectively.
	During the year ended December 31, 2013, we discontinued certain construction projects and wrote off approximately $8 million in construction work in progress to other expense in the consolidated statements of operations.
	Asset Retirement Obligations - As of December 31, 2013 and 2012, we had asset retirement obligations of $24 million and $23 million, respectively, included in other long-term liabilities in the consolidated balance sheets. Accretion expense was $1 million for each of the years ended December 31, 2013 and 2011 and accretion benefit was less than $1 million for the year ended December 31, 2012.
	We identified various assets as having an indeterminate life, for which there is no requirement to establish a fair value for future retirement obligations associated with such assets. These assets include certain pipelines, gathering systems and processing facilities. A liability for these asset retirement obligations will be recorded only if and when a future retirement obligation with a determinable life is identified. These assets have an indeterminate life because they are owned and will operate for an indeterminate future period when properly maintained. Additionally, if the portion of an owned plant containing asbestos were to be modified or dismantled, we would be legally required to remove the asbestos. We currently have no plans to take actions that would require the removal of the asbestos in these assets. Accordingly, the fair value of the asset retirement obligation related to this asbestos cannot be estimated and no obligation has been recorded.

Goodwill_and_Intangible_Assets

Goodwill and Intangible Assets Goodwill and Intangible Assets	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Goodwill and Intangible Assets	'
	Goodwill and Intangible Assets
	The carrying value of goodwill as of December 31, 2013 and December 31, 2012 was $154 million for each of the periods, consisting of $82 million for our Natural Gas Services segment, $35 million for our NGL Logistics segment and $37 million for our Wholesale Propane Logistics segment.
	We performed our annual goodwill assessment at the reporting unit level, which is identified by assessing whether the components of our operating segments constitute businesses for which discrete financial information is available, whether segment management regularly reviews the operating results of those components and whether the economic and regulatory characteristics are similar. As a result of our assessment, we concluded that the fair value of goodwill substantially exceeded its carrying value and that the entire amount of goodwill disclosed on the consolidated balance sheet is recoverable. We primarily used a discounted cash flow analysis, supplemented by a market approach analysis, to perform the assessment. Key assumptions in the analysis include the use of an appropriate discount rate, terminal year multiples, and estimated future cash flows including an estimate of operating and general and administrative costs. In estimating cash flows, we incorporate current market information, as well as historical and other factors, into our forecasted commodity prices. If actual results are not consistent with our assumptions and estimates, or our assumptions and estimates change due to new information, we may be exposed to goodwill impairment charges, which would be recognized in the period in which the carrying value exceeds fair value.
	Intangible assets consist of customer contracts, including commodity purchase, transportation and processing contracts, and related relationships. The gross carrying amount and accumulated amortization of these intangible assets are included in the accompanying consolidated balance sheets as intangible assets, net, and are as follows:
		December 31,
		2013			2012
		(Millions)
	Gross carrying amount	$	164		$	164
	Accumulated amortization	(35		)	(27		)
	Intangible assets, net	$	129		$	137
	For each of the years ended December 31, 2013, 2012, and 2011, we recorded amortization expense of $8 million. As of December 31, 2013, the remaining amortization periods ranged from approximately 8 years to 22 years, with a weighted-average remaining period of approximately 17 years.
	Estimated future amortization for these intangible assets is as follows:
	Estimated Future Amortization
	(Millions)
	2014	$	8
	2015	8
	2016	8
	2017	8
	2018	8
	Thereafter	89
	Total	$	129

Investments_in_Unconsolidated_

Investments in Unconsolidated Affiliates	12 Months Ended
	Dec. 31, 2013
Equity Method Investments and Joint Ventures [Abstract]	'
Investments in Unconsolidated Affiliates	'
	Investments in Unconsolidated Affiliates
	The following table summarizes our investments in unconsolidated affiliates:
				Carrying Value as of
		Percentage		December 31,				December 31,
		Ownership		2013				2012
				(Millions)
	Discovery Producer Services LLC	40%		$	348			$	223
	Front Range Pipeline LLC	33.33%		134				—
	Texas Express Pipeline	10%		96				41
	Mont Belvieu Enterprise Fractionator	12.50%		26				19
	Mont Belvieu 1 Fractionator	20%		16				14
	CrossPoint Pipeline, LLC	50%		6				6
	Other	Various		1				1
	Total investments in unconsolidated affiliates			$	627			$	304
	There was a deficit between the carrying amount of the investment and the underlying equity of Discovery of $28 million and $30 million at December 31, 2013 and December 31, 2012, respectively, which is associated with, and is being amortized over, the life of the underlying long-lived assets of Discovery.
	There was an excess of the carrying amount of the investment over the underlying equity of Front Range of $4 million at December 31, 2013, which is associated with interest capitalized during the construction of the pipeline and will be amortized over the life of the underlying long-lived assets of Front Range pipeline.
	There was an excess of the carrying amount of the investment over the underlying equity of Texas Express of $3 million and less than $1 million at December 31, 2013 and December 31, 2012, respectively, which is associated with interest capitalized during the construction of the pipeline and is being amortized over the life of the underlying long-lived assets of Texas Express.
	There was a deficit between the carrying amount of the investment and the underlying equity of Mont Belvieu 1 of $5 million and $6 million at December 31, 2013 and December 31, 2012, respectively, which is associated with, and is being amortized over the life of the underlying long-lived assets of Mont Belvieu 1.
	Earnings from investments in unconsolidated affiliates were as follows:
		Year Ended December 31,
		2013				2012				2011
		(Millions)
	Mont Belvieu 1 Fractionator	$	19			$	6			$	—
	Mont Belvieu Enterprise Fractionator	14				5				—
	Discovery Producer Services LLC	1				15				23
	Texas Express	(1		)		—				—
	Total earnings from unconsolidated affiliates	$	33			$	26			$	23
	The following tables summarize the combined financial information of our investments in unconsolidated affiliates:
		Year Ended December 31,
		2013				2012				2011
		(Millions)
	Statements of operations:
	Operating revenue	$	484			$	293			$	213
	Operating expenses	$	298			$	190			$	163
	Net income	$	186			$	103			$	50
		December 31,				December 31,
		2013				2012
		(Millions)
	Balance sheets:
	Current assets	$	182			$	129
	Long-term assets	2,678				1,288
	Current liabilities	(276		)		(75		)
	Long-term liabilities	(37		)		(43		)
	Net assets	$	2,547			$	1,299

Fair_Value_Measurement

Fair Value Measurement	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurement	'
	Fair Value Measurement
	Determination of Fair Value
	Below is a general description of our valuation methodologies for derivative financial assets and liabilities which are measured at fair value. Fair values are generally based upon quoted market prices or prices obtained through external sources, where available. If listed market prices or quotes are not available, we determine fair value based upon a market quote, adjusted by other market-based or independently sourced market data such as historical commodity volatilities, crude oil future yield curves, and/or counterparty specific considerations. These adjustments result in a fair value for each asset or liability under an “exit price” methodology, in line with how we believe a marketplace participant would value that asset or liability. Fair values are adjusted to reflect the credit risk inherent in the transaction as well as the potential impact of liquidating open positions in an orderly manner over a reasonable time period under current conditions. These adjustments may include amounts to reflect counterparty credit quality, the effect of our own creditworthiness, the time value of money and/or the liquidity of the market.
	•	Counterparty credit valuation adjustments are necessary when the market price of an instrument is not indicative of the fair value as a result of the credit quality of the counterparty. Generally, market quotes assume that all counterparties have near zero, or low, default rates and have equal credit quality. Therefore, an adjustment may be necessary to reflect the credit quality of a specific counterparty to determine the fair value of the instrument. We record counterparty credit valuation adjustments on all derivatives that are in a net asset position as of the measurement date in accordance with our established counterparty credit policy, which takes into account any collateral margin that a counterparty may have posted with us as well as any letters of credit that they have provided.
	•	Entity valuation adjustments are necessary to reflect the effect of our own credit quality on the fair value of our net liability positions with each counterparty. This adjustment takes into account any credit enhancements, such as collateral margin we may have posted with a counterparty, as well as any letters of credit that we have provided. The methodology to determine this adjustment is consistent with how we evaluate counterparty credit risk, taking into account our own credit rating, current credit spreads, as well as any change in such spreads since the last measurement date.
	•	Liquidity valuation adjustments are necessary when we are not able to observe a recent market price for financial instruments that trade in less active markets for the fair value to reflect the cost of exiting the position. Exchange traded contracts are valued at market value without making any additional valuation adjustments and, therefore, no liquidity reserve is applied. For contracts other than exchange traded instruments, we mark our positions to the midpoint of the bid/ask spread, and record a liquidity reserve based upon our total net position. We believe that such practice results in the most reliable fair value measurement as viewed by a market participant.
	We manage our derivative instruments on a portfolio basis and the valuation adjustments described above are calculated on this basis. We believe that the portfolio level approach represents the highest and best use for these assets as there are benefits inherent in naturally offsetting positions within the portfolio at any given time, and this approach is consistent with how a market participant would view and value the assets and liabilities. Although we take a portfolio approach to managing these assets/liabilities, in order to reflect the fair value of any one individual contract within the portfolio, we allocate all valuation adjustments down to the contract level, to the extent deemed necessary, based upon either the notional contract volume, or the contract value, whichever is more applicable.
	The methods described above may produce a fair value calculation that may not be indicative of net realizable value or reflective of future fair values. While we believe that our valuation methods are appropriate and consistent with other market participants, we recognize that the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different estimate of fair value at the reporting date. We review our fair value policies on a regular basis taking into consideration changes in the marketplace and, if necessary, will adjust our policies accordingly. See Note 11 Risk Management and Hedging Activities.
	Valuation Hierarchy
	Our fair value measurements are grouped into a three-level valuation hierarchy. The valuation hierarchy is based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date. The three levels are defined as follows.
	•	Level 1 — inputs are unadjusted quoted prices for identical assets or liabilities in active markets.
	•	Level 2 — inputs include quoted prices for similar assets and liabilities in active markets, and inputs that are observable for the asset or liability, either directly or indirectly, for substantially the full term of the financial instrument.
	•	Level 3 — inputs are unobservable and considered significant to the fair value measurement.
	A financial instrument’s categorization within the hierarchy is based upon the input that requires the highest degree of judgment in the determination of the instrument’s fair value. Following is a description of the valuation methodologies used as well as the general classification of such instruments pursuant to the hierarchy.
	Commodity Derivative Assets and Liabilities
	We enter into a variety of derivative financial instruments, which may include over the counter, or OTC, instruments, such as natural gas, crude oil or NGL contracts.
	Within our Natural Gas Services segment we typically use OTC derivative contracts in order to mitigate a portion of our exposure to natural gas, NGL and condensate price changes. We also may enter into natural gas derivatives to lock in margin around our storage and transportation assets. These instruments are generally classified as Level 2. Depending upon market conditions and our strategy, we may enter into OTC derivative positions with a significant time horizon to maturity, and market prices for these OTC derivatives may only be readily observable for a portion of the duration of the instrument. In order to calculate the fair value of these instruments, readily observable market information is utilized to the extent that it is available; however, in the event that readily observable market data is not available, we may interpolate or extrapolate based upon observable data. In instances where we utilize an interpolated or extrapolated value, and it is considered significant to the valuation of the contract as a whole, we would classify the instrument within Level 3.
	Within our Wholesale Propane Logistics segment, we may enter into a variety of financial instruments to either secure sales or purchase prices, or capture a variety of market opportunities. Since financial instruments for NGLs tend to be counterparty and location specific, we primarily use the OTC derivative instrument markets, which are not as active and liquid as exchange traded instruments. Market quotes for such contracts may only be available for short dated positions (up to six months), and an active market itself may not exist beyond such time horizon. Contracts entered into with a relatively short time horizon for which prices are readily observable in the OTC market are generally classified within Level 2. Contracts with a longer time horizon, for which we internally generate a forward curve to value such instruments, are generally classified within Level 3. The internally generated curve may utilize a variety of assumptions including, but not limited to, data obtained from third party pricing services, historical and future expected relationship of NGL prices to crude oil prices, the knowledge of expected supply sources coming on line, expected weather trends within certain regions of the United States, and the future expected demand for NGLs.
	Each instrument is assigned to a level within the hierarchy at the end of each financial quarter depending upon the extent to which the valuation inputs are observable. Generally, an instrument will move toward a level within the hierarchy that requires a lower degree of judgment as the time to maturity approaches, and as the markets in which the asset trades will likely become more liquid and prices more readily available in the market, thus reducing the need to rely upon our internally developed assumptions. However, the level of a given instrument may change, in either direction, depending upon market conditions and the availability of market observable data.
	Interest Rate Derivative Assets and Liabilities
	We use interest rate swap agreements as part of our overall capital strategy. These instruments effectively exchange a portion of our existing floating rate debt for fixed-rate debt. Our swaps are generally priced based upon a London Interbank Offered Rate, or LIBOR, instrument with similar duration, adjusted by the credit spread between our company and the LIBOR instrument. Given that a portion of the swap value is derived from the credit spread, which may be observed by comparing similar assets in the market, these instruments are classified within Level 2. Default risk on either side of the swap transaction is also considered in the valuation. We record counterparty credit and entity valuation adjustments in the valuation of our interest rate swaps; however, these reserves are not considered to be a significant input to the overall valuation.
	Nonfinancial Assets and Liabilities
	We utilize fair value to perform impairment tests as required on our property, plant and equipment; goodwill; and intangible assets. Assets and liabilities acquired in third party business combinations are recorded at their fair value as of the date of acquisition. The inputs used to determine such fair value are primarily based upon internally developed cash flow models and would generally be classified within Level 3, in the event that we were required to measure and record such assets at fair value within our consolidated financial statements. Additionally, we use fair value to determine the inception value of our asset retirement obligations. The inputs used to determine such fair value are primarily based upon costs incurred historically for similar work, as well as estimates from independent third parties for costs that would be incurred to restore leased property to the contractually stipulated condition, and would generally be classified within Level 3.
	The following table presents the financial instruments carried at fair value as of December 31, 2013 and December 31, 2012, by consolidated balance sheet caption and by valuation hierarchy, as described above:
		31-Dec-13												31-Dec-12
		Level 1			Level 2			Level 3			Total			Level 1		Level 2			Level 3			Total
											Carrying											Carrying
											Value											Value
		(Millions)
	Current assets (a):
	Commodity derivatives	$	—		$	14		$	65		$	79		$	—	$	9		$	40		$	49
	Short-term investments (b)	$	9		$	—		$	—		$	9		$	2	$	—		$	—		$	2
	Long-term assets (c):
	Commodity derivatives	$	—		$	12		$	75		$	87		$	—	$	5		$	65		$	70
	Current liabilities (d):
	Commodity derivatives	$	—		$	(26	)	$	—		$	(26	)	$	—	$	(26	)	$	(1	)	$	(27	)
	Interest rate derivatives	$	—		$	(2	)	$	—		$	(2	)	$	—	$	(4	)	$	—		$	(4	)
	Long-term liabilities (e):
	Commodity derivatives	$	—		$	(1	)	$	—		$	(1	)	$	—	$	(6	)	$	—		$	(6	)
	Interest rate derivatives	$	—		$	—		$	—		$	—		$	—	$	(2	)	$	—		$	(2	)
	(a)	Included in current unrealized gains on derivative instruments in our consolidated balance sheets.
	(b)	Includes short-term money market securities included in cash and cash equivalents in our consolidated balance sheets.
	(c)	Included in long-term unrealized gains on derivative instruments in our consolidated balance sheets.
	(d)	Included in current unrealized losses on derivative instruments in our consolidated balance sheets.
	(e)	Included in long-term unrealized losses on derivative instruments in our consolidated balance sheets.
	Changes in Levels 1 and 2 Fair Value Measurements
	The determination to classify a financial instrument within Level 1 or Level 2 is based upon the availability of quoted prices for identical or similar assets and liabilities in active markets. Depending upon the information readily observable in the market, and/or the use of identical or similar quoted prices, which are significant to the overall valuation, the classification of any individual financial instrument may differ from one measurement date to the next. To qualify as a transfer, the asset or liability must have existed in the previous reporting period and moved into a different level during the current period. In the event that there is a movement between the classification of an instrument as Level 1 or 2, the transfer between Level 1 and Level 2 would be reflected in a table as Transfers in/out of Level 1/Level 2. During the years ended December 31, 2013 and 2012, there were no transfers between Level 1 and Level 2 of the fair value hierarchy.
	Changes in Level 3 Fair Value Measurements
	The tables below illustrate a rollforward of the amounts included in our consolidated balance sheets for derivative financial instruments that we have classified within Level 3. Since financial instruments classified as Level 3 typically include a combination of observable components (that is, components that are actively quoted and can be validated to external sources) and unobservable components, the gains and losses in the table below may include changes in fair value due in part to observable market factors, or changes to our assumptions on the unobservable components. Depending upon the information readily observable in the market, and/or the use of unobservable inputs, which are significant to the overall valuation, the classification of any individual financial instrument may differ from one measurement date to the next. The significant unobservable inputs used in determining fair value include adjustments by other market-based or independently sourced market data such as historical commodity volatilities, crude oil future yield curves, and/or counterparty specific considerations. In the event that there is a movement to/from the classification of an instrument as Level 3, we have reflected such items in the table below within the “Transfers into/out of Level 3” caption.
	We manage our overall risk at the portfolio level, and in the execution of our strategy, we may use a combination of financial instruments, which may be classified within any level. Since Level 1 and Level 2 risk management instruments are not included in the rollforward below, the gains or losses in the table do not reflect the effect of our total risk management activities.
		Commodity Derivative Instruments
		Current			Long-			Current			Long-
		Assets			Term			Liabilities			Term
					Assets						Liabilities
		(Millions)
	Year ended December 31, 2013 (a):
	Beginning balance	$	40		$	65		$	(1	)	$	—
	Net realized and unrealized gains (losses) included in earnings (c)	42			(50		)	—			—
	Transfers into Level 3 (b)	—			—			—
	Transfers out of Level 3 (b)	(1		)	(2		)	1			—
	Settlements	(40		)	—			—			—
	Purchases	24			62			—			—
	Ending balance	$	65		$	75		$	—		$	—
Net unrealized gains (losses) still held included in earnings (c)	$	41		$	(50	)	$	—		$	—
Year ended December 31, 2012 (a):
Beginning balance	$	1		$	1		$	(1	)	$	—
Net realized and unrealized gains included in earnings (c)	14			2			—			—
Transfers into Level 3 (b)	—			—			—			—
Transfers out of Level 3 (b)	—			—			—			—
Settlements	(2		)	—			—			—
Purchases	27			62			—			—
Ending balance	$	40		$	65		$	(1	)	$	—
Net unrealized gains still held included in earnings (c)	$	13		$	2		$	—		$	—
(a)	There were no issuances or sales of derivatives for the years ended December 31, 2013 and 2012.
(b)	Amounts transferred in and amounts transferred out are reflected at fair value as of the end of the period.
(c)	Represents the amount of total gains or losses for the year, included in gains or losses from commodity derivative activity, net, attributable to changes in unrealized gains or losses relating to assets and liabilities classified as Level 3.
Quantitative Information and Fair Value Sensitivities Related to Level 3 Unobservable Inputs
We utilize the market approach to measure the fair value of our commodity contracts. The significant unobservable inputs used in this approach to fair value are longer dated price quotes. Our sensitivity to these longer dated forward curve prices are presented in the table below. Significant changes in any of those inputs in isolation would result in significantly different fair value measurements, depending on our short or long position in contracts.
	31-Dec-13
Product Group	Fair Value			Forward
				Curve Range
	(Millions)
Assets
NGLs	$	140		$0.27-$2.11		Per gallon
Estimated Fair Value of Financial Instruments
Valuation of a contract’s fair value is validated by an internal group independent of the marketing group. While common industry practices are used to develop valuation techniques, changes in pricing methodologies or the underlying assumptions could result in significantly different fair values and income recognition. When available, quoted market prices or prices obtained through external sources are used to determine a contract’s fair value. For contracts with a delivery location or duration for which quoted market prices are not available, fair value is determined based on pricing models developed primarily from historical and expected relationship with quoted market prices.
Values are adjusted to reflect the credit risk inherent in the transaction as well as the potential impact of liquidating open positions in an orderly manner over a reasonable time period under current conditions. Changes in market prices and management estimates directly affect the estimated fair value of these contracts. Accordingly, it is reasonably possible that such estimates may change in the near term.
The fair value of our interest rate swaps and commodity non-trading derivatives is based on prices supported by quoted market prices and other external sources and prices based on models and other valuation methods. The “prices supported by quoted market prices and other external sources” category includes our interest rate swaps, our NGL and crude oil swaps, and our NYMEX positions in natural gas. In addition, this category includes our forward positions in natural gas for which our forward price curves are obtained from a third party pricing service and then validated through an internal process which includes the use of independent broker quotes. This category also includes our forward positions in NGLs at points for which over-the-counter, or OTC, broker quotes for similar assets or liabilities are available for the full term of the instrument. This category also includes “strip” transactions whose pricing inputs are directly or indirectly observable from external sources and then modeled to daily or monthly prices as appropriate. The “prices based on models and other valuation methods” category includes the value of transactions for which inputs to the fair value of the instrument are unobservable in the marketplace and are considered significant to the overall fair value of the instrument. The fair value of these instruments may be based upon an internally developed price curve, which was constructed as a result of the long dated nature of the transaction or the illiquidity of the specific market point.
We have determined fair value amounts using available market information and appropriate valuation methodologies. However, considerable judgment is required in interpreting market data to develop the estimates of fair value. Accordingly, the estimates presented herein are not necessarily indicative of the amounts that we could realize in a current market exchange. The use of different market assumptions and/or estimation methods may have a material effect on the estimated fair value amounts.
The fair value of accounts receivable, accounts payable and short-term borrowings are not materially different from their carrying amounts because of the short-term nature of these instruments or the stated rates approximating market rates. Derivative instruments are carried at fair value.
The carrying value of outstanding balances under our Credit Agreement was $525 million as of December 31, 2012, which approximated fair value.
The carrying and fair values of the 3.875% Senior Notes were $494 million and $461 million, respectively, as of December 31, 2013.
The carrying and fair values of the 2.50% Senior Notes was $497 million and $500 million as of December 31, 2013. The carrying value as of December 31, 2012 was $500 million, which approximated fair value.
The carrying and fair values of the 4.95% Senior Notes was $349 million and $354 million, respectively as of December 31, 2013, and $350 million and $374 million, respectively, as of December 31, 2012.
The carrying and fair values of the 3.25% Senior Notes were $250 million and $258 million, respectively, as of December 31, 2013, and $250 million and $259 million, respectively, as of December 31, 2012.
We determine the fair value of our Credit Agreement borrowings based upon the discounted present value of expected future cash flows, taking into account the difference between the contractual borrowing spread and the spread for similar credit facilities available in the marketplace. We determine the fair value of our fixed-rate Senior Notes based on quotes obtained from bond dealers. We classify the fair values of our outstanding debt balances within Level 2 of the valuation hierarchy.

Debt

Debt	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Debt	'
	Debt
		December 31,			December 31,
		2013			2012
		(Millions)
	Commercial Paper
	Short-term borrowings, weighted-average interest rate of 1.14%	$	335		$	—
	Credit Agreement
	Revolving credit facility, weighted-average variable interest rate of 1.47%, as of December 31, 2012, due November 10, 2016 (a)	—			525
	Debt Securities
	Issued March 14, 2013, interest at 3.875% payable semi-annually, due March 15, 2023	500			—
	Issued November 27, 2012, interest at 2.50% payable semi-annually, due December 1, 2017	500			500
	Issued March 13, 2012, interest at 4.95% payable semi-annually, due April 1, 2022	350			350
	Issued September 30, 2010, interest at 3.25% payable semi-annually, due October 1, 2015	250			250
	Unamortized discount	(10		)	(5		)
	Total debt	1,925			1,620
	Short-term borrowings	(335		)	—
	Total long-term debt	$	1,590		$	1,620
	(a)	$150 million was swapped to a fixed rate obligation with fixed rates ranging from 2.94% to 2.99%, for a net effective rate of 2.25% on the $525 million of outstanding debt under our revolving credit facility as of December 31, 2012.
	Commercial Paper Program
	In October 2013, we entered into a commercial paper program, or the Commercial Paper Program, under which we may issue unsecured commercial paper notes, or the Notes. The Commercial Paper Program serves as an alternative source of funding and does not increase our current overall borrowing capacity. Amounts available under the Commercial Paper Program may be borrowed, repaid, and re-borrowed from time to time with the maximum aggregate principal amount of Notes outstanding, combined with the amount outstanding under our revolving credit facility, not to exceed $1 billion in the aggregate. Amounts undrawn under our revolving credit facility are available to repay the Notes, if necessary. The maturities of the Notes will vary, but may not exceed 397 days from the date of issue. The Notes will be sold under customary terms in the commercial paper market and may be issued at a discount from par, or, alternatively, may be sold at par and bear varying interest rates on a fixed or floating basis. The proceeds of the issuances of the Notes are expected to be used for capital expenditures and other general partnership purposes. As of December 31, 2013, we had $335 million of commercial paper outstanding, which is included in short-term borrowings in our consolidated balance sheets.
	Credit Agreement
	We have a $1 billion revolving credit facility that matures November 10, 2016, or the Credit Agreement.
	At December 31, 2013 and 2012, we had $1 million of letters of credit issued and outstanding under the Credit Agreement. As of December 31, 2013, the unused capacity under the Credit Agreement was $664 million, net of amounts outstanding under our Commercial Paper Program and letters of credit, which was available for general working capital purposes.
	Our borrowing capacity may be limited by the Credit Agreement’s financial covenant requirements. Except in the case of a default, amounts borrowed under our Credit Agreement will not become due prior to the November 10, 2016 maturity date.
	We may prepay all loans at any time without penalty, subject to the reimbursement of lender breakage costs in the case of prepayment of London Interbank Offered Rate, or LIBOR, borrowings. Under the Credit Agreement, indebtedness under the revolving credit facility bears interest at either: (1) LIBOR, plus an applicable margin of 1.25% based on our current credit rating; or (2) (a) the base rate which shall be the higher of Wells Fargo Bank N.A.’s prime rate, the Federal Funds rate plus 0.50% or the LIBOR Market Index rate plus 1%, plus (b) an applicable margin of 0.25% based on our current credit rating. The revolving credit facility incurs an annual facility fee of 0.25% based on our current credit rating. This fee is paid on drawn and undrawn portions of the revolving credit facility.
	The Credit Agreement requires us to maintain a leverage ratio (the ratio of our consolidated indebtedness to our consolidated EBITDA, in each case as is defined by the Credit Agreement) of not more than 5.0 to 1.0, and following the consummation of qualifying acquisitions, not more than 5.5 to 1.0, on a temporary basis for three consecutive quarters, including the quarter in which such acquisition is consummated.
	Debt Securities
	On March 14, 2013, we issued $500 million of 3.875% 10-year Senior Notes due March 15, 2023. We received proceeds of $490 million, net of underwriters’ fees, related expenses and unamortized discounts of $10 million, which we used to fund a portion of the purchase price for the acquisition of an additional 46.67% interest in the Eagle Ford system. Interest on the notes will be paid semi-annually on March 15 and September 15 of each year, commencing September 15, 2013. The notes will mature on March 15, 2023, unless redeemed prior to maturity.
	On November 27, 2012, we issued $500 million of our 2.50% 5-year Senior Notes due December 1, 2017. We received net proceeds of $494 million, net of underwriters’ fees, related expenses and unamortized discounts of $6 million. Interest on the notes will be paid semi-annually on June 1 and December 1 of each year, commencing June 1, 2013. The notes will mature on December 1, 2017, unless redeemed prior to maturity.
	On March 13, 2012, we issued $350 million of our 4.95% 10-year Senior Notes due April 1, 2022. We received net proceeds of $346 million, net of underwriters’ fees, related expenses and unamortized discounts of $4 million, which we used to fund the cash portion of the acquisition of the remaining 66.67% interest in Southeast Texas and to repay funds borrowed under our Term Loan and Credit Agreement. Interest on the notes is paid semi-annually on April 1 and October 1 of each year. The notes will mature on April 1, 2022, unless redeemed prior to maturity.
	On September 30, 2010, we issued $250 million of our 3.25% Senior Notes due October 1, 2015. We received net proceeds of $248 million, net of underwriters’ fees, related expense and unamortized discounts of $2 million, which we used to repay funds borrowed under the revolver portion of our Credit Agreement. Interest on the notes is paid semi-annually on April 1 and October 1 of each year. The notes will mature on October 1, 2015, unless redeemed prior to maturity.
	The notes are senior unsecured obligations, ranking equally in right of payment with other unsecured indebtedness, including indebtedness under our Credit Agreement. We are not required to make mandatory redemption or sinking fund payments with respect to any of these notes, and they are redeemable at a premium at our option. The underwriters’ fees and related expenses are deferred in other long-term assets in our consolidated balance sheets and will be amortized over the term of the notes.
	The future maturities of long-term debt in the year indicated are as follows:
		Debt
		Maturities
		(Millions)
	2014	$	—
	2015	250
	2016	—
	2017	500
	2018	—
	Thereafter	850
		1,600
	Unamortized discount	(10		)
	Total	$	1,590

Risk_Management_and_Hedging_Ac

Risk Management and Hedging Activities	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Risk Management and Hedging Activities	'
	Risk Management and Hedging Activities
	Our day-to-day operations expose us to a variety of risks including but not limited to changes in the prices of commodities that we buy or sell, changes in interest rates, and the creditworthiness of each of our counterparties. We manage certain of these exposures with either physical or financial transactions. We have established a comprehensive risk management policy, or Risk Management Policy, and a risk management committee, or the Risk Management Committee, to monitor and manage market risks associated with commodity prices and counterparty credit. The Risk Management Committee is composed of senior executives who receive regular briefings on positions and exposures, credit exposures and overall risk management in the context of market activities. The Risk Management Committee is responsible for the overall management of credit risk and commodity price risk, including monitoring exposure limits. The following describes each of the risks that we manage.
	Commodity Price Risk
	Cash Flow Protection Activities — We are exposed to the impact of market fluctuations in the prices of natural gas, NGLs and condensate as a result of our gathering, processing, sales and storage activities. For gathering, processing and storage services, we may receive cash or commodities as payment for these services, depending on the contract type. We enter into derivative financial instruments to mitigate a portion of the risk of weakening natural gas, NGL and condensate prices associated with our gathering, processing and sales activities, thereby stabilizing our cash flows. We have mitigated a significant portion of our expected commodity price risk associated with our gathering, processing and sales activities through 2017 with commodity derivative instruments. Our commodity derivative instruments used for our hedging program are a combination of direct NGL product, crude oil, and natural gas hedges. Due to the limited liquidity and tenor of the NGL derivative market, we have used crude oil swaps and costless collars to mitigate a portion of our commodity price exposure to NGLs. Historically, prices of NGLs have generally been related to crude oil prices; however, there are periods of time when NGL pricing may be at a greater discount to crude oil, resulting in additional exposure to NGL commodity prices. The relationship of NGLs to crude oil continues to be lower than historical relationships; however, a significant amount of our NGL hedges from 2014 through 2017 are direct product hedges. When our crude oil swaps become short-term in nature, we have periodically converted certain crude oil derivatives to NGL derivatives by entering into offsetting crude oil swaps while adding NGL swaps. Our crude oil and NGL transactions are primarily accomplished through the use of forward contracts that effectively exchange our floating price risk for a fixed price. We also utilize crude oil costless collars that minimize our floating price risk by establishing a fixed price floor and a fixed price ceiling. However, the type of instrument that we use to mitigate a portion of our risk may vary depending upon our risk management objective. These transactions are not designated as hedging instruments for accounting purposes and the change in fair value is reflected within our consolidated statements of operations as a gain or a loss on commodity derivative activity.
	Our Wholesale Propane Logistics segment is generally designed to establish stable margins by entering into supply arrangements that specify prices based on established floating price indices and by entering into sales agreements that provide for floating prices that are tied to our variable supply costs plus a margin. To the extent possible, we match the pricing of our supply portfolio to our sales portfolio in order to lock in value and reduce our overall commodity price risk. However, to the extent that we carry propane inventories or our sales and supply arrangements are not aligned, we are exposed to market variables and commodity price risk. We manage the commodity price risk of our supply portfolio and sales portfolio with both physical and financial transactions, including fixed price sales. While the majority of our sales and purchases in this segment are index-based, occasionally, we may enter into fixed price sales agreements in the event that a propane distributor desires to purchase propane from us on a fixed price basis. In such cases, we may manage this risk with derivatives that allow us to swap our fixed price risk to market index prices that are matched to our market index supply costs. In addition, we may use financial derivatives to manage the value of our propane inventories. These transactions are not designated as hedging instruments for accounting purposes and any change in fair value is reflected in the current period within our consolidated statements of operations as a gain or loss on commodity derivative activity.
	Our portfolio of commodity derivative activity is primarily accounted for using the mark-to-market method of accounting, whereby changes in fair value are recorded directly to the consolidated statements of operations; however, depending upon our risk profile and objectives, in certain limited cases, we may execute transactions that qualify for the hedge method of accounting.
	Natural Gas Storage and Pipeline Asset Based Commodity Derivative Program — Our natural gas storage and pipeline assets are exposed to certain risks including changes in commodity prices. We manage commodity price risk related to our natural gas storage and pipeline assets through our commodity derivative program. The commercial activities related to our natural gas storage and pipeline assets primarily consist of the purchase and sale of gas and associated time spreads and basis spreads.
	A time spread transaction is executed by establishing a long gas position at one point in time and establishing an equal short gas position at a different point in time. Time spread transactions allow us to lock in a margin supported by the injection, withdrawal, and storage capacity of our natural gas storage assets. We may execute basis spread transactions to mitigate the risk of sale and purchase price differentials across our system. A basis spread transaction allows us to lock in a margin on our physical purchases and sales of gas, including injections and withdrawals from storage. We typically use swaps to execute these transactions, which are not designated as hedging instruments and are recorded at fair value with changes in fair value recorded in the current period consolidated statements of operations. While gas held in our storage locations is recorded at the lower of average cost or market, the derivative instruments that are used to manage our storage facilities are recorded at fair value and any changes in fair value are currently recorded in our consolidated statements of operations. Even though we may have economically hedged our exposure and locked in a future margin, the use of lower-of-cost-or-market accounting for our physical inventory and the use of mark-to-market accounting for our derivative instruments may subject our earnings to market volatility.
	Commodity Cash Flow Hedges — In order for storage facilities to remain operational, a minimum level of base gas must be maintained in each storage cavern, which is capitalized on our consolidated balance sheets as a component of property, plant and equipment, net. During 2011, Southeast Texas commenced an expansion project to build an additional storage cavern. To mitigate risk associated with the forecasted purchase of natural gas, we executed a series of derivative financial instruments, which were designated as cash flow hedges. During the second half of 2013, Southeast Texas purchased base gas to bring the storage cavern to operation. The balance in accumulated other comprehensive income, or AOCI, of these cash flow hedges was in a loss position of $3 million as of December 31, 2013. While the cash paid upon settlement of these hedges economically fixed the cash required to purchase the base gas, the deferred loss will remain in AOCI until the cavern is emptied and the base gas is sold.
	Interest Rate Risk
	At December 31, 2013, we had interest rate swap agreements extending through June 2014 with notional values totaling $150 million, which are accounted for under the mark-to-market method of accounting and reprice prospectively approximately every 30 days. Under the terms of the interest rate swap agreements, we pay fixed-rates ranging from 2.94% to 2.99%, and receive interest payments based on the one-month LIBOR. Prior to August of 2013, these interest rate swaps were designated as cash flow hedges whereby the effective portions of changes in fair value were recognized in AOCI in the consolidated balance sheets. The deferred loss in AOCI of $3 million, at the time of de-designation, will be reclassified into earnings as the hedged transactions impact earnings.
	In March 2012, we settled $195 million of our forward-starting interest rate swap agreements for $7 million. The net deferred losses in AOCI of $5 million, at the settlement date, will be amortized into interest expense associated with our long-term debt offering through 2022.
	Contingent Credit Features
	Each of the above risks is managed through the execution of individual contracts with a variety of counterparties. Certain of our derivative contracts may contain credit-risk related contingent provisions that may require us to take certain actions in certain circumstances.
	We have International Swap Dealers Association, or ISDA, contracts which are standardized master legal arrangements that establish key terms and conditions which govern certain derivative transactions. These ISDA contracts contain standard credit-risk related contingent provisions. Some of the provisions we are subject to are outlined below.
	•	If we were to have an effective event of default under our Credit Agreement that occurs and is continuing, our ISDA counterparties may have the right to request early termination and net settlement of any outstanding derivative liability positions.
	•	In the event that we or DCP Midstream, LLC were to be downgraded below investment grade by at least one of the major credit rating agencies, certain of our ISDA counterparties have the right to reduce our collateral threshold to zero, potentially requiring us to fully collateralize any commodity contracts in a net liability position.
	•	Additionally, in some cases, our ISDA contracts contain cross-default provisions that could constitute a credit-risk related contingent feature. These provisions apply if we default in making timely payments under those agreements and the amount of the default is above certain predefined thresholds, which are significantly high and are generally consistent with the terms of our Credit Agreement. As of December 31, 2013, we are not a party to any agreements that would be subject to these provisions other than our Credit Agreement.
	Our commodity derivative contracts that are not governed by ISDA contracts do not have any credit-risk related contingent features.
	Depending upon the movement of commodity prices and interest rates, each of our individual contracts with counterparties to our commodity derivative instruments or to our interest rate swap instruments are in either a net asset or net liability position. As of December 31, 2013, we had $8 million of individual commodity derivative contracts that contain credit-risk related contingent features that were in a net liability position, and have not posted any cash collateral relative to such positions. If a credit-risk related event were to occur and we were required to net settle our position with an individual counterparty, our ISDA contracts permit us to net all outstanding contracts with that counterparty, whether in a net asset or net liability position, as well as any cash collateral already posted. As of December 31, 2013, if a credit-risk related event were to occur we may be required to post additional collateral. Additionally, although our commodity derivative contracts that contain credit-risk related contingent features were in a net liability position as of December 31, 2013, if a credit-risk related event were to occur, the net liability position would be partially offset by contracts in a net asset position reducing our net liability to $6 million.
	As of December 31, 2013, we had $150 million of interest rate swap instruments that were in a net liability position of $2 million and were subject to credit-risk related contingent features. If we were to have a default of any of our covenants to our Credit Agreement that occurs and is continuing, the counterparties to our swap instruments have the right to request that we net settle the instrument in the form of cash.
	Unconsolidated Affiliates
	Discovery Producer Services LLC, one of our unconsolidated affiliates, entered into agreements with a pipe vendor denominated in a foreign currency in connection with the expansion of the natural gas gathering pipeline system in the deepwater Gulf of Mexico, the Keathley Canyon Connector. Discovery entered into certain foreign currency derivative contracts to mitigate a portion of the foreign currency exchange risks which were designated as cash flow hedges. As these hedges are owned by Discovery, an unconsolidated affiliate, we include the impact to AOCI on our consolidated balance sheet.
	Offsetting
	Certain of our derivative instruments are subject to a master netting or similar arrangement, whereby we may elect to settle multiple positions with an individual counterparty through a single net payment. Each of our individual derivative instruments are presented on a gross basis on the consolidated balance sheets, regardless of our ability to net settle our positions. Instruments that are governed by agreements that include net settle provisions allow final settlement, when presented with a termination event, of outstanding amounts by extinguishing the mutual debts owed between the parties in exchange for a net amount due. We have trade receivables and payables associated with derivative instruments, subject to master netting or similar agreements, which are not included in the table below. The following summarizes the gross and net amounts of our derivative instruments:
		Gross Amounts				Amounts Not				Net				Gross Amounts				Amounts Not			Net
		of Assets and				Offset in the				Amount				of Assets and				Offset in the			Amount
		(Liabilities)				Balance Sheet -								(Liabilities)				Balance Sheet -
		Presented in the				Financial								Presented in the				Financial
		Balance Sheet				Instruments (a)								Balance Sheet				Instruments (a)
		31-Dec-13												31-Dec-12
	Assets:
	Commodity derivatives	$	166			$	(13	)		$	153			$	119			$	(10	)	$	109
	Interest rate derivatives	$	—			$	—			$	—			$	—			$	—		$	—
	Liabilities:
	Commodity derivatives	$	(27	)		$	13			$	(14	)		$	(33	)		$	10		$	(23	)
	Interest rate derivatives	$	(2	)		$	—			$	(2	)		$	(6	)		$	—		$	(6	)
	(a)	There is no cash collateral pledged or received against these positions.
	Summarized Derivative Information
	The fair value of our derivative instruments that are designated as hedging instruments and those that are marked-to-market each period, as well as the location of each within our consolidated balance sheets, by major category, is summarized as follows:
	Balance Sheet Line Item	December 31,				December 31,				Balance Sheet Line Item		December 31,				December 31,
		2013				2012						2013				2012
		(Millions)										(Millions)
	Derivative Assets Designated as Hedging Instruments:									Derivative Liabilities Designated as Hedging Instruments:
	Commodity derivatives:									Commodity derivatives:
	Unrealized gains on derivative instruments — current	$	—			$	—			Unrealized losses on derivative instruments — current		$	—			$	(3	)
	Unrealized gains on derivative instruments — long-term	—				—				Unrealized losses on derivative instruments — long-term		—				—
		$	—			$	—					$	—			$	(3	)
	Interest rate derivatives:									Interest rate derivatives:
	Unrealized gains on derivative instruments — current	$	—			$	—			Unrealized losses on derivative instruments — current		$	—			$	(4	)
	Unrealized gains on derivative instruments — long-term	—				—				Unrealized losses on derivative instruments — long-term		—				(2		)
		$	—			$	—					$	—			$	(6	)
	Derivative Assets Not Designated as Hedging Instruments:									Derivative Liabilities Not Designated as Hedging Instruments:
	Commodity derivatives:									Commodity derivatives:
	Unrealized gains on derivative instruments — current	$	79			$	49			Unrealized losses on derivative instruments — current		$	(26	)		$	(24	)
	Unrealized gains on derivative instruments — long-term	87				70				Unrealized losses on derivative instruments — long-term		(1		)		(6		)
		$	166			$	119					$	(27	)		$	(30	)
	Interest rate derivatives:									Interest rate derivatives:
	Unrealized gains on derivative instruments — current	$	—			$	—			Unrealized losses on derivative instruments — current		$	(2	)		$	—
	Unrealized gains on derivative instruments — long-term	—				—				Unrealized losses on derivative instruments — long-term		—				—
		$	—			$	—					$	(2	)		$	—
	The following summarizes the balance and activity within AOCI relative to our interest rate, commodity and foreign currency cash flow hedges as of and for the year ended December 31, 2013:
		Interest						Commodity				Foreign				Total
Rate Cash			Cash Flow					Currency
Flow			Hedges					Cash Flow
Hedges								Hedges (a)
	(Millions)
Net deferred (losses) gains in AOCI (beginning balance)	$	(10	)				$	(6	)		$	1			$	(15	)
Losses reclassified from AOCI to earnings — effective portion	4				(b)		—				—				4
Net deferred (losses) gains in AOCI (ending balance)	$	(6	)				$	(6	)		$	1			$	(11	)
Deferred losses in AOCI expected to be reclassified into earnings over the next 12 months	$	(2	)				$	—			$	—			$	(2	)
(a)	Relates to Discovery, our unconsolidated affiliate.
(b)	Included in interest expense in our consolidated statements of operations.
For the year ended December 31, 2013, less than $1 million of derivative losses attributable to the ineffective portion was recognized in gains or losses from commodity derivative activity, net and interest expense in our consolidated statements of operations. For the year ended December 31, 2013, $1 million of derivative gains were reclassified from AOCI to earnings from unconsolidated affiliates as a result of amounts excluded from effectiveness testing or as a result of the discontinuance of cash flow hedges related to certain forecasted transactions that are not probable of occurring.
The following table summarizes the impact on our consolidated balance sheet and consolidated statements of operations of our derivative instruments that are accounted for using the cash flow hedge method of accounting for the year ended December 31, 2012:
	(Losses) gains				Losses						Losses Recognized
	Recognized in				Reclassified						in Income on
	AOCI on				From AOCI to						Derivatives —
	Derivatives —				Earnings —						Ineffective Portion
	Effective Portion				Effective						and Amount
					Portion						Excluded From
											Effectiveness
											Testing
	(Millions)
Interest rate derivatives	$	(1	)		$	(10	)		(a)		$	(2	)		(a) (b)
Commodity derivatives	$	(1	)		$	—					$	—
Foreign currency derivatives (c)	$	1			$	—					$	—
(a)	Included in interest expense in our consolidated statements of operations.
(b)	For the year ended December 31, 2012, less than $1 million of derivative losses were reclassified from AOCI to current period earnings as a result of the discontinuance of cash flow hedges related to certain forecasted transactions that are not probable of occurring.
(c)	Relates to Discovery, our unconsolidated affiliate.
Changes in value of derivative instruments, for which the hedge method of accounting has not been elected from one period to the next, are recorded in the consolidated statements of operations. The following summarizes these amounts and the location within the consolidated statements of operations that such amounts are reflected:
Commodity Derivatives: Statements of Operations Line Item		Year Ended December 31,
		2013				2012				2011
	(Millions)
Third party:
Realized (losses) gains		$	(19	)		$	4			$	(36	)
Unrealized gains		14				13				43
(Losses) gains from commodity derivative activity, net		$	(5	)		$	17			$	7
Affiliates:
Realized gains		$	73			$	45			$	2
Unrealized (losses) gains		(51		)		8				(1		)
Gains from commodity derivative activity, net —affiliates		$	22			$	53			$	1
Interest Rate Derivatives: Statements of Operations Line Item		Year Ended December 31,
		2013				2012				2011
	(Millions)
Third party:
Realized losses		$	(2	)		$	(7	)		$	(4	)
Unrealized gains		2				7				5
Interest expense		$	—			$	—			$	1
We do not have any derivative financial instruments that qualify as a hedge of a net investment.
The following tables represent, by commodity type, our net long or short positions that are expected to partially or entirely settle in each respective year. To the extent that we have long dated derivative positions that span multiple calendar years, the contract will appear in more than one line item in the tables below.
	31-Dec-13
	Crude Oil			Natural Gas			Natural Gas			Natural Gas
							Liquids			Basis Swaps
Year of Expiration	Net (Short)			Net			Net			Net Long
	Position			(Short)			(Short)			Position
	(Bbls)			Position			Position			(MMbtu)
				(MMBtu)			(Bbls)
2014	(690,945	)		(21,673,620	)		(5,171,910	)		21,415,000
2015	(745,695	)		(9,458,975	)		(5,691,570	)		1,875,000
2016	(561,922	)		(1,838,564	)		(813,267	)		—
	31-Dec-12
	Crude Oil			Natural Gas			Natural Gas			Natural Gas
							Liquids			Basis Swaps
Year of Expiration	Net (Short)			Net (Short)			Net (Short)			Net Long
	Position			Position			Position			(Short)
	(Bbls)			(MMBtu)			(Bbls)			Position
										(Mmbtu)
2013	(943,379	)		(8,887,980	)		(2,593,955	)		9,690,000
2014	(584,365	)		(4,712,880	)		(2,584,930	)		(1,350,000	)
2015	(401,865	)		(5,127,155	)		(2,491,250	)		—
2016	(183,000	)		—			—			—
We periodically enter into interest rate swap agreements to mitigate a portion of our floating rate interest exposure. As of December 31, 2013, we have swaps with a notional value of $70 million and $80 million, which, in aggregate, exchange $150 million of our floating rate obligation to a fixed rate obligation through June 2014.

Partnership_Equity_and_Distrib

Partnership Equity and Distributions	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Partnership Equity and Distributions	'
	Partnership Equity and Distributions
	General — During the year ended December 31, 2013, we issued 1,408,547 of our common units pursuant to an equity distribution agreement entered into in August 2011, or the 2011 equity distribution agreement. We received proceeds of $67 million, net of commissions and offering costs of $2 million, which were used to finance growth opportunities and for general partnership purposes. The 2011 equity distribution agreement provided for the offer and sale of common units having an aggregate offering amount of up to $150 million. As of December 31, 2013, no common units remain available for sale pursuant to this equity distribution agreement and we have deregistered the corresponding registration statement.
	In August 2013, we issued 9,000,000 common units at $50.04 per unit. We received proceeds of $434 million, net of offering costs.
	In June 2013, we filed a shelf registration statement on Form S-3 with the SEC with a maximum offering price of $300 million, which became effective on June 27, 2013. The shelf registration statement allows us to issue additional common units. In November 2013, we entered into an equity distribution agreement, or the 2013 equity distribution agreement, with a group of financial institutions as sales agents. The agreement provides for the offer and sale from time to time, through our sales agents, of common units having an aggregate offering amount of up to $300 million. During the year ended December 31, 2013, we issued 1,839,430 of our common units pursuant to the 2013 equity distribution agreement and received proceeds of $87 million, net of accrued commissions and offering costs of $1 million, which were used to finance growth opportunities and for general partnership purposes. As of December 31, 2013, approximately $212 million of the aggregate offering amount remains available for sale pursuant to the 2013 equity distribution agreement.
	In March 2013, we issued 2,789,739 common units to DCP Midstream, LLC as partial consideration for 46.67% interest in the Eagle Ford system.
	In March 2013, we issued 12,650,000 common units at $40.63 per unit. We received proceeds of $494 million, net of offering costs.
	In November 2012, we issued 1,912,663 common units to DCP Midstream, LLC as partial consideration for our 33.33% interest in the Eagle Ford system.
	In July 2012, we issued 1,536,098 common units to DCP Midstream, LLC as partial consideration for the Mont Belvieu fractionators.
	In July 2012, we closed a private placement of equity with a group of institutional investors in which we sold 4,989,802 common units at a price of $35.55 per unit, and received proceeds of $174 million net of offering costs.
	In June 2012, we filed a universal shelf registration statement on Form S-3 with the SEC with an unlimited offering amount, to replace an existing shelf registration statement. The universal shelf registration statement allows us to issue additional common units and debt securities. Our 9,000,000 and 12,650,000 common units issued in August 2013 and March 2013, respectively, and 2.50% 5-year Senior Notes were issued under this registration statement.
	In March 2012, we issued 5,148,500 common units at $47.42 per unit. We received proceeds of $234 million, net of offering costs.
	In March 2012, we issued 1,000,417 common units to DCP Midstream, LLC as partial consideration for the remaining 66.67% interest in Southeast Texas.
	In February 2012, we issued 30,701 common units under our 2005 Long-Term Incentive Plan, or 2005 LTIP, to employees as compensation for their service.
	In January 2012, we issued 727,520 common units to DCP Midstream, LLC as partial consideration for the remaining 49.9% interest in East Texas.
	In March 2011, we issued 3,596,636 common units at $40.55 per unit. We received proceeds of $140 million, net of offering costs.
	In February 2011, we issued 8,399 common units, from our LTIP to employees as compensation for their service during 2010, 2009 and 2008.
	Definition of Available Cash — Our partnership agreement requires that, within 45 days after the end of each quarter, we distribute all of our Available Cash, as defined in the partnership agreement, to unitholders of record on the applicable record date, as determined by our general partner. Available Cash, for any quarter, consists of all cash and cash equivalents on hand at the end of that quarter:
	•	less the amount of cash reserves established by the general partner to:
	•provide for the proper conduct of our business;
	•comply with applicable law, any of our debt instruments or other agreements; and
	•	provide funds for distributions to the unitholders and to our general partner for any one or more of the next four quarters;
	•	plus, if our general partner so determines, all or a portion of cash and cash equivalents on hand on the date of determination of Available Cash for the quarter.
	General Partner Interest and Incentive Distribution Rights - The general partner is entitled to a percentage of all quarterly distributions equal to its general partner interest of approximately 1% and limited partner interest of 1% as of December 31, 2013. The general partner has the right, but not the obligation, to contribute a proportionate amount of capital to us to maintain its current general partner interest.
	The incentive distribution rights held by the general partner entitle it to receive an increasing share of Available Cash when pre-defined distribution targets are achieved. Currently, our distribution to our general partner related to its incentive distribution rights is at the highest level. The general partner’s incentive distribution rights were not reduced as a result of our common unit issuances, and will not be reduced if we issue additional units in the future and the general partner does not contribute a proportionate amount of capital to us to maintain its current general partner interest. Please read the Distributions of Available Cash sections below for more details about the distribution targets and their impact on the general partner’s incentive distribution rights.
	Distributions of Available Cash - Our partnership agreement, after adjustment for the general partner’s relative ownership level, requires that we make distributions of Available Cash from operating surplus for any quarter in the following manner:
	•	first, to all unitholders and the general partner, in accordance with their pro rata interest, until each unitholder receives a total of $0.4025 per unit for that quarter;
	•	second, 13% to the general partner, plus the general partner’s pro rata interest, and the remainder to all unitholders pro rata until each unitholder receives a total of $0.4375 per unit for that quarter;
	•	third, 23% to the general partner, plus the general partner’s pro rata interest, and the remainder to all unitholders pro rata until each unitholder receives a total of $0.525 per unit for that quarter; and
	•	thereafter, 48% to the general partner, plus the general partner’s pro rata interest, and the remainder to all unitholders.
	The following table presents our cash distributions paid in 2013, 2012 and 2011:
	Payment Date	Per Unit		Total Cash
		Distribution		Distribution
				(Millions)
	November 14, 2013	$	0.72	$	82
	August 14, 2013	$	0.71	$	72
	May 15, 2013	$	0.7	$	69
	February 14, 2013	$	0.69	$	54
	November 14, 2012	$	0.68	$	53
	August 14, 2012	$	0.67	$	49
	May 15, 2012	$	0.66	$	43
	February 14, 2012	$	0.65	$	37
	November 14, 2011	$	0.64	$	35
	August 12, 2011	$	0.6325	$	34
	May 13, 2011	$	0.625	$	33
	February 14, 2011	$	0.6175	$	30

EquityBased_Compensation

Equity-Based Compensation	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Equity-Based Compensation	'
	Equity-Based Compensation
	Total compensation cost for equity-based arrangements was as follows:
		Year Ended December 31,
		2013			2012			2011
		(Millions)
	Performance Phantom Units	$	1		$	1		$	5
	Phantom Units	—			—			—
	Restricted Phantom Units	1			1			2
	Total compensation cost	$	2		$	2		$	7
	On November 28, 2005, the board of directors of our General Partner adopted a Long-Term Incentive Plan, or the 2005 LTIP, for employees, consultants and directors of our General Partner and its affiliates who perform services for us. The 2005 LTIP provides for the grant of limited partner units, or LPUs, phantom units, unit options and substitute awards, and, with respect to unit options and phantom units, the grant of dividend equivalent rights, or DERs. Subject to adjustment for certain events, an aggregate of 850,000 LPUs may be issued and delivered pursuant to awards under the 2005 LTIP. Awards that are canceled or forfeited, or are withheld to satisfy the General Partner’s tax withholding obligations, are available for delivery pursuant to other awards.
	On February 15, 2012, the board of directors of our General Partner adopted a 2012 LTIP for employees, consultants and directors of our General Partner and its affiliates who perform services for us. The 2012 LTIP provides for the grant of phantom units and the grant of DERs. The phantom units consist of a notional unit based on the value of common units or shares of the Partnership, Phillips 66 and Spectra Energy.
	The LTIPs were administered by the compensation committee of the General Partner’s board of directors through 2012, and by the General Partner’s board of directors beginning in 2013. All awards are subject to cliff vesting.
	Prior to February 18, 2011, substantially all equity-based awards were accounted for as liability awards. Effective February 18, 2011, the Modification Date, we have the intent and ability to settle certain awards within our control in units and therefore modified the accounting for these awards. We classified them as equity awards based on their re-measured fair value. The fair value was determined based on the closing price of our common units on the Modification Date. Such modification resulted in a reclassification of $2 million from share-based compensation liability to additional paid-in capital on the Modification Date. Compensation expense on unvested equity awards as of the Modification Date is recognized ratably over each remaining vesting period.
	We account for other awards, which are subject to settlement in cash, as liability awards. Compensation expense on these awards is recognized ratably over each vesting period, and will be re-measured each reporting period for all awards outstanding until the units are vested. The fair value of all liability awards is determined based on the closing price of our common units at each measurement date.
	The reclassification of the affected awards did not impact our accounting for dividend equivalent rights as these instruments will continue to be settled in cash and therefore retain their share-based compensation liability classification.
	Performance Phantom Units - We have awarded Performance Phantom Units, or PPUs, pursuant to the LTIP to certain employees. PPUs generally vest in their entirety at the end of a three year performance period. The number of PPUs that will ultimately vest range, in value up to 200% of the outstanding PPUs, depending on the achievement of specified performance targets over three year performance periods. The final performance payout is determined by the board of directors of our General Partner. The DERs are paid in cash at the end of the performance period. Of the remaining PPUs outstanding at December 31, 2013, 2,070 units are expected to vest on December 31, 2014 and 10,890 units are expected to vest on December 31, 2015.
	At December 31, 2013, there was less than $1 million of unrecognized compensation expense related to the PPUs that is expected to be recognized over a weighted-average period of approximately 2 years. The following table presents information related to the PPUs:
		Units		Grant Date			Measurement
				Weighted-			Date Price
				Average Price			per Unit
				per Unit
	Outstanding at January 1, 2011	67,350		$	15.42
	Granted	10,580		$	41.8
	Vested	(50,720	)	$	10.05
	Forfeited	—		$	—
	Outstanding at December 31, 2011	27,210		$	35.69
	Granted (a)	11,740		$	39.31
	Vested	(20,100	)	$	34.57
	Forfeited	(7,760	)	$	38.97
	Outstanding at December 31, 2012	11,090		$	39.24
	Granted	11,450		$	40.88
	Vested (b)	(3,800	)	$	40.75
	Forfeited	(4,990	)	$	38.77
	Outstanding at December 31, 2013	13,750		$	40.36		$	50.33
	Expected to vest (c)	12,960		$	40.38		$	50.33
	(a)	Includes the impact of conversion of the underlying securities, in connection with Phillip 66's separation from ConocoPhillips, granted under the 2012 LTIP.
	(b)	The units vested at 150%.
	(c)	Based on our December 31, 2013 estimated achievement of specified performance targets, the performance estimate for units granted in both 2013 and 2012 is 100%. The estimated forfeiture rate for units granted in both 2013 and 2012 is 10%.
	The estimate of PPUs that are expected to vest is based on highly subjective assumptions that could potentially change over time, including the expected forfeiture rate and achievement of performance targets. Therefore, the amount of unrecognized compensation expense noted above does not necessarily represent the value that will ultimately be realized in our consolidated statements of operations.
	The following table presents the fair value of units vested and the unit-based liabilities paid related to PPUs, including the related DERs:
		Year Ended December 31,
		2013			2012			2011
		(Millions)
	Fair value of units vested	less than $1			$	1		$	5
	Unit-based liabilities paid	$	1		$	5		$	—
	Phantom Units - As part of their director fees, we granted 4,400 Phantom Units to directors during the year ended December 31, 2013 and 4,000 Phantom Units to directors during each of the years ended December 31, 2012, and 2011, respectively. All of these units vested in their respective grant years, and were settled in units. The DERs are paid in cash quarterly in arrears. The following table presents information related to the Phantom Units:
		Units		Grant Date			Measurement
				Weighted-			Date Price
				Average Price			per Unit
				per Unit
	Outstanding at January 1, 2011	—		$	—
	Granted	4,000		$	41.8
	Vested	(4,000	)	$	41.8
	Outstanding at December 31, 2011	—		$	—
	Granted	4,000		$	48.03
	Vested	(4,000	)	$	48.03
	Outstanding at December 31, 2012	—		$	—
	Granted	4,400		$	46.39
	Vested	(4,400	)	$	46.39
	Outstanding at December 31, 2013	—		$	—		$	—
	The fair value of units vested related to Phantom Units was less than $1 million for each of the years ended December 31, 2013, 2012 and 2011.
	Restricted Phantom Units - Our General Partner’s board of directors awarded restricted phantom LPUs, or RPUs, to key employees under the LTIP. Of the remaining RPUs outstanding at December 31, 2013, 2,070 units are expected to vest on December 31, 2014 and 11,281 units are expected to vest on December 31, 2015. The DERs are paid in cash quarterly in arrears. At December 31, 2013, there was less than $1 million of unrecognized compensation expense related to the RPUs that is expected to be recognized over a weighted-average period of approximately 2 years. The following table presents information related to the RPUs:
		Units		Grant Date			Measurement
Weighted-				Date Price
Average Price				per Unit
per Unit
Outstanding at January 1, 2011	67,350		$	15.42
Granted	10,580		$	41.8
Vested	(58,600	)	$	12.97
Forfeited	—		$	—
Outstanding at December 31, 2011	19,330		$	37.27
Granted (a)	11,740		$	39.31
Vested	(19,060	)	$	37.31
Forfeited	(7,760	)	$	43.27
Outstanding at December 31, 2012	4,250		$	39.63
Granted	11,590		$	41.94
Vested	(1,950	)	$	41.8
Forfeited	—		$	—
Outstanding at December 31, 2013	13,890		$	41.25		$	50.33
Expected to vest	13,351		$	41.38		$	50.3
(a)	Includes the impact of conversion of the underlying securities, in connection with Phillip 66's separation from ConocoPhillips, granted under the 2012 LTIP.
The following table presents the fair value of units vested and the unit-based liabilities paid for unit based awards related to Restricted Phantom Units:
	Year Ended December 31,
	2013			2012			2011
	(Millions)
Fair value of units vested	less than $1			$	1		$	3
Unit-based liabilities paid	$	1		$	2		$	1
The estimate of RPUs that are expected to vest is based on highly subjective assumptions that could potentially change over time, including the expected forfeiture rate, which was estimated at 10% for units granted in both 2013 and 2012. Therefore, the amount of unrecognized compensation expense noted above does not necessarily represent the value that will ultimately be realized in our consolidated statements of operations.

Net_Income_or_Loss_per_Limited

Net Income or Loss per Limited Partner Unit	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Net Income or Loss per Limited Partner Unit	'
	Net Income or Loss per Limited Partner Unit
	Our net income or loss is allocated to the general partner and the limited partners in accordance with their respective ownership percentages, after allocating Available Cash generated during the period in accordance with our partnership agreement.
	Securities that meet the definition of a participating security are required to be considered for inclusion in the computation of basic earnings per unit using the two-class method. Under the two-class method, earnings per unit is calculated as if all of the earnings for the period were distributed under the terms of the partnership agreement, regardless of whether the general partner has discretion over the amount of distributions to be made in any particular period, whether those earnings would actually be distributed during a particular period from an economic or practical perspective, or whether the general partner has other legal or contractual limitations on its ability to pay distributions that would prevent it from distributing all of the earnings for a particular period.
	These required disclosures do not impact our overall net income or loss or other financial results; however, in periods in which aggregate net income exceeds our Available Cash it will have the impact of reducing net income per LPU.
	Basic and diluted net income or loss per LPU is calculated by dividing net income or loss allocable to limited partners, by the weighted-average number of outstanding LPUs during the period. Diluted net income or loss per LPU is computed based on the weighted average number of units plus the effect of dilutive potential units outstanding during the period using the two-class method. Dilutive potential units include outstanding Performance Units, Phantom Units and Restricted Units. The dilutive effect of unit-based awards was 19,179, 33,043 and 64,286 equivalent units during the years ended December 31, 2013, 2012 and 2011, respectively.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Income Taxes
	We are structured as a master limited partnership with sufficient qualifying income, which is a pass-through entity for federal income tax purposes. Accordingly, we had no federal income tax expense for the years ended December 31, 2013 and 2012.
	In December 2010, we acquired all of the interests in Marysville Hydrocarbons Holdings, LLC, an entity that owned a taxable C-Corporation consolidated return group. We estimated $35 million of deferred tax liabilities resulting from built-in tax gains recognized in the transaction and recorded this as part of our preliminary acquisition accounting as of December 31, 2010. In January 2011, we merged two 100% owned subsidiaries of Marysville Hydrocarbons Holding, LLC and converted the combined entity’s organizational structure from a corporation to a limited liability company. This conversion to a limited liability company triggered the deferred tax liabilities resulting from built-in tax gains to become currently payable. Accordingly, the estimated $35 million of deferred tax liabilities at December 31, 2010 became currently payable on January 4, 2011. During 2011, we made federal and state tax payments of $29 million and less than $1 million, respectively, related to our estimated $35 million tax liability that resulted from our acquisition of Marysville. In 2011, the remaining $5 million estimated tax payable was reclassified to goodwill in our final acquisition accounting for the Marysville business combination.
	The State of Texas imposes a margin tax that is assessed at 0.975% of taxable margin apportioned to Texas for the year ended December 31, 2013 and 1% for the years ended December 31, 2012 and 2011. For the year ended December 31, 2011, the state of Michigan imposed a business tax of 0.8% on gross receipts and 4.95% of Michigan taxable income. The sum of the gross receipts and income tax was subject to a tax surcharge of 21.99%. The Michigan business tax was repealed beginning with the year ended December 31, 2012.
	Income tax expense consists of the following:
		Year Ended December 31,
		2013			2012			2011
		(Millions)
	Current:
	Federal income tax expense	$	—		$	—		$	(29	)
	State income tax expense	(3		)	(1		)	(2		)
	Deferred:
	Federal income tax benefit	—			—			29
	State income tax (expense) benefit	(5		)	—			1
	Total income tax expense	$	(8	)	$	(1	)	$	(1	)
	We had net long-term deferred tax liabilities of $11 million and $6 million as of December 31, 2013 and 2012, included in other long-term liabilities on the consolidated balance sheets. These state deferred tax liabilities relate to our Texas operations, and are primarily associated with depreciation related to property, plant and equipment.
	Our effective tax rate differs from statutory rates, primarily due to being structured as a master limited partnership, which is a pass-through entity for federal income tax purposes, while being treated as a taxable entity in certain states.

Commitments_and_Contingent_Lia

Commitments and Contingent Liabilities	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingent Liabilities	'
	Commitments and Contingent Liabilities
	Litigation
	Prospect — In 2011, we received an arbitration claim, or the Claim, filed with the American Arbitration Association by Prospect Street Energy, LLC and Prospect Street Ventures I, LLC, or together, the Claimants, against EE Group, LLC, or EE Group, and a number of other parties that previously owned, directly or indirectly, our Marysville NGL storage facility, or collectively, the Respondents. EE Group is our indirect subsidiary which we acquired in connection with our acquisition of Marysville Hydrocarbons Holdings, LLC, or Marysville, on December 30, 2010. The Claim involves actions taken and time periods prior to our ownership of EE Group and Marysville, and includes several causes of action including claims of civil conspiracy, breach of fiduciary duty and fraud. As of February 2014, we have entered into separate settlement agreements with the Claimants and the other Respondents involved in the arbitration. We believe these settlement agreements substantially mitigate our liability in this matter and therefore, we consider this matter closed.
	Other — We are not a party to any other significant legal proceedings, but are a party to various administrative and regulatory proceedings and commercial disputes that have arisen in the ordinary course of our business. Management currently believes that the ultimate resolution of the foregoing matters, taken as a whole, and after consideration of amounts accrued, insurance coverage or other indemnification arrangements, will not have a material adverse effect on our consolidated results of operations, financial position, or cash flow.
	Insurance - We renewed our insurance policies in May, June and July 2013 for the 2013-2014 insurance year. We contract with third party and affiliate insurers for: (1) automobile liability insurance for all owned, non-owned and hired vehicles; (2) general liability insurance; (3) excess liability insurance above the established primary limits for general liability and automobile liability insurance; and (4) property insurance, which covers replacement value of real and personal property and includes business interruption/extra expense. These renewals have not resulted in any material change to the premiums we are contracted to pay or our limits in the 2013-2014 insurance year compared with the 2012-2013 insurance year. We are jointly insured with DCP Midstream, LLC for a portion of the directors and officers insurance covering our directors and officers for acts related to our business activities. All coverage is subject to certain limits and deductibles, the terms and conditions of which are common for companies that are of similar size to us and with similar types of operations.
	The insurance on Discovery, as placed by Williams Field Service Group LLC, for the 2013-2014 insurance year includes general and excess liability, onshore property damage, including named windstorm and business interruption, and offshore non-wind property and business interruption insurance. The availability of offshore named windstorm property and business interruption insurance has been significantly reduced over the past few years as a result of higher industry-wide damage claims. Additionally, the named windstorm property and business interruption insurance that is available comes at uneconomic premium levels, higher deductibles and lower coverage limits. As such, Discovery continues to elect not to purchase offshore named windstorm property and business interruption insurance coverage for the 2013-2014 insurance year.
	Environmental — The operation of pipelines, plants and other facilities for gathering, transporting, processing, treating, or storing natural gas, NGLs and other products is subject to stringent and complex laws and regulations pertaining to health, safety and the environment. As an owner or operator of these facilities, we must comply with United States laws and regulations at the federal, state and local levels that relate to air and water quality, hazardous and solid waste management and disposal, and other environmental matters. The cost of planning, designing, constructing and operating pipelines, plants, and other facilities incorporates compliance with environmental laws and regulations and safety standards. Failure to comply with these laws and regulations may trigger a variety of administrative, civil and potentially criminal enforcement measures, including citizen suits, which can include the assessment of monetary penalties, the imposition of remedial requirements, and the issuance of injunctions or restrictions on operation. Management believes that, based on currently known information, compliance with these laws and regulations will not have a material adverse effect on our consolidated results of operations, financial position or cash flows.
	Indemnification - DCP Midstream, LLC has indemnified us for certain potential environmental claims, losses and expenses associated with the operation of the assets of certain of our predecessors.
	Other Commitments and Contingencies - We utilize assets under operating leases in several areas of operation. Consolidated rental expense, including leases with no continuing commitment, totaled $17 million, $14 million, and $15 million for the years ended December 31, 2013, 2012, and 2011, respectively. Rental expense for leases with escalation clauses is recognized on a straight line basis over the initial lease term.
	Minimum rental payments under our various operating leases in the year indicated are as follows at December 31, 2013:
		(Millions)
	2014	$	16
	2015	14
	2016	12
	2017	10
	2018	9
	Thereafter	33
	Total minimum rental payments	$	94

Business_Segments

Business Segments	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Business Segments	'
	Business Segments
	Our operations are located in the United States and are organized into three reporting segments: Natural Gas Services; NGL Logistics; and Wholesale Propane Logistics.
	Natural Gas Services — Our Natural Gas Services segment provides services that include gathering, compressing, treating, processing, transporting and storing natural gas, and fractionating NGLs. The segment consists of our 80% interest in the Eagle Ford system, 100% owned Eagle Plant, East Texas system, Southeast Texas system, Michigan system, Northern Louisiana system, Southern Oklahoma system, Wyoming system, 75% interest in the Piceance system, 40% interest in Discovery, and the DJ Basin system.
	NGL Logistics — Our NGL Logistics segment provides services that include transportation, storage and fractionation of NGLs. The segment consists of the NGL storage facility in Michigan, our 20% interest in the Mont Belvieu 1 fractionator, our 12.5% interest in the Mont Belvieu Enterprise fractionator, the Black Lake and Wattenberg interstate NGL pipelines, the DJ Basin NGL fractionators in Colorado, the Seabreeze and Wilbreeze intrastate NGL pipelines, our 33.33% interest in the Front Range interstate NGL pipeline, and our 10% interest in the Texas Express intrastate NGL pipeline.
	Wholesale Propane Logistics — Our Wholesale Propane Logistics segment provides services that include the receipt of propane by pipeline, rail or ship to our terminals that store and deliver the product to distributors. The segment consists of six owned rail terminals, one owned marine terminal, one leased marine terminal, one pipeline terminal and access to several open-access pipeline terminals.
	These segments are monitored separately by management for performance against our internal forecast and are consistent with internal financial reporting. These segments have been identified based on the differing products and services, regulatory environment and the expertise required for these operations. Gross margin is a performance measure utilized by management to monitor the business of each segment.
	The following tables set forth our segment information:
	Year Ended December 31, 2013:
		Natural Gas			NGL			Wholesale			Other			Total
		Services (d)			Logistics			Propane
								Logistics
		(Millions)
	Total operating revenue	$	2,598		$	73		$	380		$	—		$	3,051
	Gross margin (a)	$	501		$	72		$	52		—			$	625
	Operating and maintenance expense	(184		)	(16		)	(15		)	—			(215		)
	Depreciation and amortization expense	(87		)	(6		)	(2		)	—			(95		)
	General and administrative expense	—			—			—			(63		)	(63		)
	Other expense	(1		)	(3		)	(4		)	—			(8		)
	Earnings from unconsolidated affiliates	1			32			—			—			33
	Interest expense	—			—			—			(52		)	(52		)
	Income tax expense (b)	—			—			—			(8		)	(8		)
	Net income (loss)	$	230		$	79		$	31		$	(123	)	$	217
	Net income attributable to noncontrolling interests	(17		)	—			—			—			(17		)
	Net income (loss) attributable to partners	$	213		$	79		$	31		$	(123	)	$	200
	Non-cash derivative mark-to-market (c)	$	(36	)	$	—		$	(1	)	$	1		$	(36	)
	Non-cash lower of cost or market adjustments	$	2		$	—		$	2					$	4
	Capital expenditures	$	334		$	24		$	5		$	—		$	363
	Acquisition expenditures	$	696		$	86		$	—		$	—		$	782
	Investments in unconsolidated affiliates	$	133		$	109		$	—		$	—		$	242
	Year Ended December 31, 2012:
		Natural Gas			NGL			Wholesale			Other			Total
		Services (d)			Logistics			Propane
								Logistics
		(Millions)
	Total operating revenue	$	2,345		$	64		$	415		$	—		$	2,824
	Gross margin (a)	$	503		$	64		$	42		$	—		$	609
	Operating and maintenance expense	(166		)	(16		)	(15		)	—			(197		)
	Depreciation and amortization expense	(83		)	(6		)	(2		)	—			(91		)
	General and administrative expense	—			—			—			(75		)	(75		)
	Earnings from unconsolidated affiliates	15			11			—			—			26
	Interest expense	—			—			—			(42		)	(42		)
	Income tax expense (b)	—			—			—			(1		)	(1		)
	Net income (loss)	$	269		$	53		$	25		$	(118	)	$	229
	Net income attributable to noncontrolling interests	(13		)	—			—			—			(13		)
	Net income (loss) attributable to partners	$	256		$	53		$	25		$	(118	)	$	216
	Non-cash derivative mark-to-market (c)	$	20		$	—		$	1		$	—		$	21
	Capital expenditures	$	468		$	12		$	4		$	—		$	484
	Acquisitions net of cash acquired	$	715		$	30		$	—		$	—		$	745
	Investments in unconsolidated affiliates	$	115		$	43		$	—		$	—		$	158
	Year Ended December 31, 2011:
		Natural Gas			NGL			Wholesale			Other			Eliminations (f)			Total
		Services (d)			Logistics			Propane
								Logistics
		(Millions)
	Total operating revenue	$	3,102		$	57		$	633		$	—		$	(2	)	$	3,790
	Gross margin (a)	$	532		$	52		$	51		$	—		$	—		$	635
	Operating and maintenance expense	(161		)	(16		)	(15		)	—			—			(192		)
	Depreciation and amortization expense	(124		)	(8		)	(3		)	—			—			(135		)
	General and administrative expense	—			—			—			(76		)	—			(76		)
	Earnings from unconsolidated affiliates	23			—			—			—			—			23
	Other operating income	—			1			—			—			—			1
	Interest expense	—			—			—			(34		)	—			(34		)
	Income tax expense (b)	—			—			—			(1		)	—			(1		)
Net income (loss)	270			29			33			(111		)	—			221
Net income attributable to noncontrolling interests	(30		)	—			—			—			—			(30		)
Net income (loss) attributable to partners	$	240		$	29		$	33		$	(111	)	$	—		$	191
Non-cash derivative mark-to-market (c)	$	42		$	—		$	—		$	(2	)	$	—		$	40
Capital expenditures	$	372		$	9		$	4		$	—		$	—		$	385
Acquisitions net of cash acquired	$	122		$	30		$	—		$	—		$	—		$	152
Investments in unconsolidated affiliates	$	8		$	—		$	—		$	—		$	—		$	8
	December 31,
	2013			2012			2011
	(Millions)
Segment long-term assets:
Natural Gas Services (d)	$	3,303		$	2,748		$	2,214
NGL Logistics	555			340			250
Wholesale Propane Logistics	106			105			104
Other (e)	100			84			14
Total long-term assets	4,064			3,277			2,582
Current assets (d)	503			368			373
Total assets	$	4,567		$	3,645		$	2,955
(a)	Gross margin consists of total operating revenues, including commodity derivative activity, less purchases of natural gas, propane and NGLs. Gross margin is viewed as a non-GAAP measure under the rules of the SEC, but is included as a supplemental disclosure because it is a primary performance measure used by management as it represents the results of product sales versus product purchases. As an indicator of our operating performance, gross margin should not be considered an alternative to, or more meaningful than, net income or cash flow as determined in accordance with GAAP. Our gross margin may not be comparable to a similarly titled measure of another company because other entities may not calculate gross margin in the same manner.
(b)	For the year ended December 31, 2011, income tax expense relates primarily to the Texas margin tax and the Michigan business tax. The Michigan business tax was repealed in 2012; accordingly, income tax expense for the years ended December 31, 2013 and 2012 relates primarily to the Texas margin tax.
(c)	Non-cash commodity derivative mark-to-market is included in segment gross margin, along with cash settlements for our commodity derivative contracts.
(d)	The segment information as of and for the years ended December 31, 2013, 2012 and 2011, includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas. Transfers of net assets between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information, similar to the pooling method.
(e)	Other long-term assets not allocable to segments consist of unrealized gains on derivative instruments, corporate leasehold improvements and other long-term assets.
(f)	Represents intersegment revenues consisting of sales of NGLs by Marysville in our NGL Logistics segment to our Wholesale Propane Logistics segment.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2013
Supplemental Cash Flow Elements [Abstract]	'
Supplemental Cash Flow Information	'
	Supplemental Cash Flow Information
		Year Ended December 31,
		2013		2012			2011
		(Millions)
	Cash paid for interest and income taxes:
	Cash paid for interest, net of amounts capitalized	$	40	$	23		$	17
	Cash paid for income taxes, net of income tax refunds	$	1	$	1		$	30
	Non-cash investing and financing activities:
	Property, plant and equipment acquired with accounts payable	$	27	$	47		$	34
	Other non-cash additions of property, plant and equipment	$	1	$	8		$	3
	Non-cash change in parent advances	$	—	$	(115	)	$	5
	Accounts payable related to equity issuance costs	$	1	$	—		$	—

Quarterly_Financial_Data_Unaud

Quarterly Financial Data (Unaudited)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Quarterly Financial Data (Unaudited)	'
	Quarterly Financial Data (Unaudited)
	Our consolidated results of operations by quarter for the years ended December 31, 2013 and 2012 were as follows (millions, except per unit amounts):
	2013	First (a)			Second (a)			Third (a)			Fourth (a)			Year Ended December 31, 2013 (a)
	Total operating revenues	$	749		$	792		$	689		821			3,051
	Operating income	$	65		$	117		$	14		48			244
	Net income	$	60		$	111		$	6		40			217
	Net income attributable to noncontrolling interests	$	(3	)	$	(4	)	$	(3	)	(7	)		(17	)
	Net income (loss) attributable to partners	$	57		$	107		$	3		33			200
	Net income (loss) allocable to limited partners	$	31		$	86		$	(20	)	8			105
	Basic and diluted net income (loss) per limited partner unit	$	0.48		$	1.11		$	(0.24	)	0.09			1.34
	(a)Our consolidated results of operations have been adjusted to retrospectively include the historical results of the Lucerne 1 plant for all periods presented.
	2012	First (a)			Second (a)			Third (a)			Fourth (a)				Year Ended December 31, 2012 (a)
	Total operating revenues	$	855		$	680		$	618		$	671			$	2,824
	Operating income	$	52		$	99		$	13		$	82			$	246
	Net income	$	44		$	90		$	14		$	81			$	229
	Net income attributable to noncontrolling interests	$	(4	)	$	(2	)	$	(2	)	$	(5	)		$	(13	)
	Net income attributable to partners	$	40		$	88		$	12		$	76			$	216
	Net income (loss) allocable to limited partners	$	12		$	69		$	(9	)	$	52			$	124
	Basic and diluted net income (loss) per limited partner unit	$	0.26		$	1.33		$	(0.16	)	$	0.87			$	2.28
	(a)Our consolidated results of operations have been adjusted to retrospectively include the historical results of the Lucerne 1 plant for all periods presented.

Supplementary_Information_Cond

Supplementary Information - Condensed Consolidating Financial Information	3 Months Ended																		12 Months Ended
	Mar. 31, 2014																		Dec. 31, 2013
Condensed Financial Information Disclosure [Abstract]	'																		'
Supplementary Information - Condensed Consolidating Financial Information	'																		'
	Supplementary Information — Condensed Consolidating Statements of Cash Flows																		Supplementary Information — Condensed Consolidating Financial Information
																			The following condensed consolidating financial information presents the results of operations, financial position and cash flows of DCP Midstream Partners, LP, or parent guarantor, DCP Midstream Operating LP, or subsidiary issuer, which is a 100% owned subsidiary, and non-guarantor subsidiaries, as well as the consolidating adjustments necessary to present DCP Midstream Partners, LP’s results on a consolidated basis. In conjunction with the universal shelf registration statement on Form S-3 filed with the SEC on June 14, 2012, the parent guarantor has agreed to fully and unconditionally guarantee securities of the subsidiary issuer. For the purpose of the following financial information, investments in subsidiaries are reflected in accordance with the equity method of accounting. The financial information may not necessarily be indicative of results of operations, cash flows, or financial position had the subsidiaries operated as independent entities.
	Subsequent to the issuance of the March 31, 2014 financial statements, management determined that intercompany transfers between the parent guarantor and the non-guarantor subsidiaries, as well as the subsidiary issuer and the non-guarantor subsidiaries, should be classified as investing activities by the parent guarantor and subsidiary issuer and financing activities by the non-guarantor subsidiaries, within the condensed consolidating statements of cash flows. The intercompany transfers had previously been reported as operating activities by the parent guarantor, subsidiary issuer and non-guarantor subsidiaries. The classification of these intercompany transfers has been corrected in the condensed consolidating financial statements for the periods ended March 31, 2014, and 2013. This correction has no impact on the condensed consolidated statement of cash flows for all periods presented. These amounts have been included within the line item “intercompany transfers” in investing and financing activities within the condensed consolidating statements of cash flows.
		Condensed Consolidating Statement of Cash Flows
		Three Months Ended March 31, 2014 (a)																		Condensed Consolidating Balance Sheet
		Parent			Subsidiary			Non-Guarantor			Consolidating		Consolidated							December 31, 2013 (a)
		Guarantor			Issuer			Subsidiaries			Adjustments									Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
		(Millions)																		Guarantor			Issuer			Subsidiaries				Adjustments
	OPERATING ACTIVITIES																			(Millions)
	Net cash (used in) provided by operating activities	—			(11	)		157			—		146						ASSETS
																			Current assets:
	INVESTING ACTIVITIES:																		Cash and cash equivalents	$	—		$	—		$	12			$	—			$	12
	Intercompany transfers	(591	)		(365	)		—			956		—
																			Accounts receivable, net	—			—			342				—				342
	Capital expenditures	—			—			(63	)		—		(63	)
																			Inventories	—			—			67				—				67
	Acquisitions, net of cash acquired	—			—			(100	)		—		(100	)
																			Other	—			—			82				—				82
	Acquisition of unconsolidated affiliates	—			—			(669	)		—		(669	)
																			Total current assets	—			—			503				—				503
	Investments in unconsolidated affiliates	—			—			(65	)		—		(65	)
																			Property, plant and equipment, net	—			—			3,046				—				3,046
	Other	—			—			1			—		1
																			Goodwill and intangible assets, net	—			—			283				—				283
	Net cash (used in) provided by investing activities	(591	)		(365	)		(896	)		956		(896	)
																			Advances receivable — consolidated subsidiaries	1,805			1,683			—				(3,488		)		—
	FINANCING ACTIVITIES:
	Intercompany transfers	—			—			956			(956	)	—						Investments in consolidated subsidiaries	181			426			—				(607		)		—
	Proceeds from long-term debt	—			719			—			—		719						Investments in unconsolidated affiliates	—			—			627				—				627
	Payments of commercial paper, net	—			(314	)		—			—		(314	)					Other long-term assets	—			12			96				—				108
	Payments of deferred financing costs	—			(6	)		—			—		(6	)					Total assets	$	1,986		$	2,121		$	4,555			$	(4,095	)		$	4,567
	Excess purchase price over acquired interests and commodity hedges	—			—			(14	)		—		(14	)					LIABILITIES AND EQUITY
																			Accounts payable and other current liabilities	$	1		$	350		$	372			$	—			$	723
	Proceeds from issuance of common units, net of offering costs	677			—			—			—		677
																			Advances payable — consolidated subsidiaries	—			—			3,488				(3,488		)		—
	Net change in advances to predecessor from DCP Midstream, LLC	—			—			(6	)		—		(6	)
																			Long-term debt	—			1,590			—				—				1,590
	Distributions to limited partners and general partner	(86	)		—			—			—		(86	)
																			Other long-term liabilities	—			—			41				—				41
	Distributions to noncontrolling interests	—			—			(10	)		—		(10	)
																			Total liabilities	1			1,940			3,901				(3,488		)		2,354
	Purchase of additional interest in a subsidiary	—			—			(198	)		—		(198	)
																			Commitments and contingent liabilities
	Contributions from noncontrolling interests	—			—			3			—		3
																			Equity:
	Net cash provided by (used in) financing activities	591			399			731			(956	)	765						Partners’ equity:
																			Predecessor equity	—			—			40				—				40
	Net change in cash and cash equivalents	—			23			(8	)		—		15
																			Net equity	1,985			187			391				(607		)		1,956
	Cash and cash equivalents, beginning of period	—			—			12			—		12
																			Accumulated other comprehensive loss	—			(6		)	(5		)		—				(11		)
	Cash and cash equivalents, end of period	—			23			4			—		27
																			Total partners’ equity	1,985			181			426				(607		)		1,985
																			Noncontrolling interests	—			—			228				—				228
	(a)	The financial information for the three months ended March 31, 2014 includes the results of our Lucerne 1 plant, a transfer of net assets between entities under common control that was accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																			Total equity	1,985			181			654				(607		)		2,213
																			Total liabilities and equity	$	1,986		$	2,121		$	4,555			$	(4,095	)		$	4,567
		Condensed Consolidating Statements of Cash Flows
		Three Months Ended March 31, 2013 (a)
		Parent				Subsidiary				Non-Guarantor			Consolidating			Consolidated
		Guarantor				Issuer				Subsidiaries			Adjustments						(a)	The financial information as of December 31, 2013 includes the results of our Lucerne 1 plant and an 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
		(Millions)
	OPERATING ACTIVITIES
Net cash (used in) provided by operating activities	$	—			$	(1	)		$	159		$	(6	)	$	152
																			Condensed Consolidating Balance Sheet
INVESTING ACTIVITIES:																			December 31, 2012 (a)
Intercompany transfers	(440		)		(72		)		—			512			—				Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																			Guarantor			Issuer			Subsidiaries				Adjustments
Capital expenditures	—				—				(101		)	—			(101		)		(Millions)
																		ASSETS
Acquisitions, net of cash acquired	—				—				(481		)	—			(481		)	Current assets:
																		Cash and cash equivalents	$	—		$	3		$	2			$	(3	)		$	2
Investments in unconsolidated affiliates	—				—				(26		)	—			(26		)
																		Accounts receivable, net	—			—			239				—				239
Net cash (used in) provided by investing activities	(440		)		(72		)		(608		)	512			(608		)
																		Inventories	—			—			76				—				76
FINANCING ACTIVITIES:
Intercompany transfers	—				—				512			(512		)	—			Other	—			—			51				—				51
Proceeds from long-term debt	—				809				—			—			809			Total current assets	—			3			368				(3		)		368
Payments of long-term debt	—				(690		)		—			—			(690		)	Property, plant and equipment, net	—			—			2,592				—				2,592
Payment of deferred financing costs	—				(4		)		—			—			(4		)	Goodwill and intangible assets, net	—			—			291				—				291
Proceeds from issuance of common units, net of offering costs	494				—				—			—			494			Advances receivable — consolidated subsidiaries	873			1,424			—				(2,297		)		—
Excess purchase price over acquired assets	—				—				(94		)	—			(94		)	Investments in consolidated subsidiaries	574			770			—				(1,344		)		—
Net change in advances to predecessor from DCP Midstream, LLC	—				—				22			—			22			Investments in unconsolidated affiliates	—			—			304				—				304
Distributions to common unitholders and general partner	(54		)		—				—			—			(54		)	Other long-term assets	—			11			79				—				90
Distributions to noncontrolling interests	—				—				(5		)	—			(5		)	Total assets	$	1,447		$	2,208		$	3,634			$	(3,644	)		$	3,645
Contributions from noncontrolling interests	—				—				15			—			15			LIABILITIES AND EQUITY
																		Accounts payable and other current liabilities	$	—		$	12		$	336			$	(3	)		$	345
Distributions to DCP Midstream, LLC	—				—				(3		)	—			(3		)
																		Advances payable — consolidated subsidiaries	—			—			2,297				(2,297		)		—
Contributions from DCP Midstream, LLC	—				—				1			—			1
																		Long-term debt	—			1,620			—				—				1,620
Net cash provided by (used in) financing activities	440				115				448			(512		)	491
																		Other long-term liabilities	—			2			42				—				44
Net change in cash and cash equivalents	—				42				(1		)	(6		)	35
																		Total liabilities	—			1,634			2,675				(2,300		)		2,009
Cash and cash equivalents, beginning of period	—				3				2			(3		)	2
																		Commitments and contingent liabilities
Cash and cash equivalents, end of period	$	—			$	45			$	1		$	(9	)	$	37
																		Equity:
																		Partners’ equity:
																		Predecessor equity	—			—			399				—				399
(a)	The financial information during the three months ended March 31, 2013 includes the results of our Lucerne 1 plant and an 80% interest in the Eagle Ford system. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																		Net equity	1,447			584			376				(1,344		)		1,063
The parent guarantor, subsidiary issuer and non-guarantor subsidiaries participate in a cash pooling program, whereby cash balances are generally swept daily between the parent guarantor and the non-guarantor subsidiaries bank accounts and those of the subsidiary issuer.
																		Accumulated other comprehensive loss	—			(10		)	(5		)		—				(15		)
The changes to the previously reported amounts are summarized as follows:
																		Total partners’ equity	1,447			574			770				(1,344		)		1,447
																		Noncontrolling interests	—			—			189				—				189
	Parent				Subsidiary				Non-Guarantor			Consolidating			Consolidated
	Guarantor				Issuer				Subsidiaries			Adjustments						Total equity	1,447			574			959				(1,344		)		1,636
	(Millions)
Three Months Ended March 31, 2014																		Total liabilities and equity	$	1,447		$	2,208		$	3,634			$	(3,644	)		$	3,645
Net cash (used in) provided by operating activities	$	591			$	365			$	(956	)	$	—		$	—
Net cash (used in) provided by investing activities	$	(591	)		$	(365	)		$	—		$	956		$	—
																		(a)	The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
Net cash provided by (used in) financing activities	$	—			$	—			$	956		$	(956	)	$	—
Three Months Ended March 31, 2013
Net cash (used in) provided by operating activities	$	440			$	72			$	(512	)	$	—		$	—			Condensed Consolidating Statement of Operations
																			Year Ended December 31, 2013 (a)
Net cash (used in) provided by investing activities	$	(440	)		$	(72	)		$	—		$	512		$	—			Parent			Subsidiary			Non-				Consolidating				Consolidated
																			Guarantor			Issuer			Guarantor				Adjustments
Net cash provided by (used in) financing activities	$	—			$	—			$	512		$	(512	)	$	—									Subsidiaries
																			(Millions)
																		Operating revenues:
																		Sales of natural gas, propane, NGLs and condensate	$	—		$	—		$	2,763			$	—			$	2,763
																		Transportation, processing and other	—			—			271				—				271
																		Gains from commodity derivative activity, net	—			—			17				—				17
																		Total operating revenues	—			—			3,051				—				3,051
																		Operating costs and expenses:
																		Purchases of natural gas, propane and NGLs	—			—			2,426				—				2,426
																		Operating and maintenance expense	—			—			215				—				215
																		Depreciation and amortization expense	—			—			95				—				95
																		General and administrative expense	—			—			63				—				63
																		Other expense	—			—			8				—				8
																		Total operating costs and expenses	—			—			2,807				—				2,807
																		Operating income	—			—			244				—				244
																		Interest expense, net	—			(52		)	—				—				(52		)
																		Income from consolidated subsidiaries	200			252			—				(452		)		—
																		Earnings from unconsolidated affiliates	—			—			33				—				33
																		Income before income taxes	200			200			277				(452		)		225
																		Income tax expense	—			—			(8		)		—				(8		)
																		Net income	200			200			269				(452		)		217
																		Net income attributable to noncontrolling interests	—			—			(17		)		—				(17		)
																		Net income attributable to partners	$	200		$	200		$	252			$	(452	)		$	200
																		(a)	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																			Condensed Consolidating Statement of Comprehensive Income
																			Year Ended December 31, 2013 (a)
																			Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																			Guarantor			Issuer			Subsidiaries				Adjustments
																			(Millions)
																		Net income	$	200		$	200		$	269			$	(452	)		$	217
																		Other comprehensive income:
																		Reclassification of cash flow hedge losses into earnings	—			4			—				—				4
																		Other comprehensive income from consolidated subsidiaries	4			—			—				(4		)		—
																		Total other comprehensive income	4			4			—				(4		)		4
																		Total comprehensive income	204			204			269				(456		)		221
																		Total comprehensive income attributable to noncontrolling interests	—			—			(17		)		—				(17		)
																		Total comprehensive income attributable to partners	$	204		$	204		$	252			$	(456	)		$	204
																		(a)	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																			Condensed Consolidating Statement of Operations
																			Year Ended December 31, 2012 (a)
																			Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																			Guarantor			Issuer			Subsidiaries				Adjustments
																			(Millions)
																		Operating revenues:
																		Sales of natural gas, propane, NGLs and condensate	$	—		$	—		$	2,520			$	—			$	2,520
																		Transportation, processing and other	—			—			234				—				234
																		Gains from commodity derivative activity, net	—			—			70				—				70
																		Total operating revenues	—			—			2,824				—				2,824
																		Operating costs and expenses:
																		Purchases of natural gas, propane and NGLs	—			—			2,215				—				2,215
																		Operating and maintenance expense	—			—			197				—				197
																		Depreciation and amortization expense	—			—			91				—				91
																		General and administrative expense	—			—			75				—				75
																		Total operating costs and expenses	—			—			2,578				—				2,578
																		Operating income	—			—			246				—				246
																		Interest expense, net	—			(41		)	(1		)		—				(42		)
																		Earnings from unconsolidated affiliates	—			—			26				—				26
																		Income from consolidated subsidiaries	216			257			—				(473		)		—
																		Income before income taxes	216			216			271				(473		)		230
																		Income tax expense	—			—			(1		)		—				(1		)
																		Net income	216			216			270				(473		)		229
																		Net income attributable to noncontrolling interests	—			—			(13		)		—				(13		)
																		Net income attributable to partners	$	216		$	216		$	257			$	(473	)		$	216
																		(a)	The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																			Condensed Consolidating Statement of Comprehensive Income
																			Year Ended December 31, 2012 (a)
																			Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																			Guarantor			Issuer			Subsidiaries				Adjustments
																			(Millions)
																		Net income	$	216		$	216		$	270			$	(473	)		$	229
																		Other comprehensive loss:
																		Reclassification of cash flow hedge losses into earnings	—			10			—				—				10
																		Net unrealized losses on cash flow hedges	—			(1		)	—				—				(1		)
																		Other comprehensive income from consolidated subsidiaries	9			—			—				(9		)		—
																		Total other comprehensive income	9			9			—				(9		)		9
																		Total comprehensive income	225			225			270				(482		)		238
																		Total comprehensive income attributable to noncontrolling interests	—			—			(13		)		—				(13		)
																		Total comprehensive income attributable to partners	$	225		$	225		$	257			$	(482	)		$	225
																		(a)	The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																			Condensed Consolidating Statement of Operations
																			Year Ended December 31, 2011 (a)
																			Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																			Guarantor			Issuer			Subsidiaries				Adjustments
																			(Millions)
																		Operating revenues:
																		Sales of natural gas, propane, NGLs and condensate	$	—		$	—		$	3,574			$	—			$	3,574
																		Transportation, processing and other	—			—			208				—				208
																		Gains from commodity derivative activity, net	—			—			8				—				8
																		Total operating revenues	—			—			3,790				—				3,790
																		Operating costs and expenses:
																		Purchases of natural gas, propane and NGLs	—			—			3,155				—				3,155
																		Operating and maintenance expense	—			—			192				—				192
																		Depreciation and amortization expense	—			—			135				—				135
																		General and administrative expense	—			—			76				—				76
																		Other income	—			—			(1		)		—				(1		)
																		Total operating costs and expenses	—			—			3,557				—				3,557
																		Operating income	—			—			233				—				233
																		Interest expense	—			(33		)	(1		)		—				(34		)
																		Earnings from unconsolidated affiliates	—			—			23				—				23
																		Income from consolidated subsidiaries	191			224			—				(415		)		—
																		Income before income taxes	191			191			255				(415		)		222
																		Income tax expense	—			—			(1		)		—				(1		)
																		Net income	191			191			254				(415		)		221
																		Net income attributable to noncontrolling interests	—			—			(30		)		—				(30		)
																		Net income attributable to partners	$	191		$	191		$	224			$	(415	)		$	191
																		(a)	The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																			Condensed Consolidating Statement of Comprehensive Income
																			Year Ended December 31, 2011 (a)
																			Parent			Subsidiary			Non-Guarantor					Consolidating				Consolidated
																			Guarantor			Issuer			Subsidiaries					Adjustments
																			(Millions)
																		Net income	$	191		$	191		$	254				$	(415	)		$	221
																		Other comprehensive loss:
																		Reclassification of cash flow hedge losses into earnings	—			21			—					—				21
																		Net unrealized losses on cash flow hedges	—			(12		)	(3		)			—				(15		)
																		Other comprehensive income from consolidated subsidiaries	6			(3		)	—					(3		)		—
																		Total other comprehensive income	6			6			(3		)	—		(3		)		6
																		Total comprehensive income	197			197			251					(418		)		227
																		Total comprehensive income attributable to noncontrolling interests	—			—			(30		)			—				(30		)
																		Total comprehensive income attributable to partners	$	197		$	197		$	221				$	(418	)		$	197
																		(a)	The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																			Condensed Consolidating Statement of Cash Flows
																			Year Ended December 31, 2013 (a)
																			Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																			Guarantor			Issuer			Subsidiaries				Adjustments
																			(Millions)
																		OPERATING ACTIVITIES
																		Net cash (used in) provided by operating activities	$	—		$	(45	)	$	387			$	3			$	345
																		INVESTING ACTIVITIES:
																		Intercompany transfers	(806		)	(258		)	—				1,064				—
																		Capital expenditures	—			—			(363		)		—				(363		)
																		Acquisitions, net of cash acquired	—			—			(696		)		—				(696		)
																		Acquisition of unconsolidated affiliates	—			—			(86		)		—				(86		)
																		Investments in unconsolidated affiliates	—			—			(242		)		—				(242		)
																		Net cash (used in) provided by investing activities	(806		)	(258		)	(1,387		)		1,064				(1,387		)
																		FINANCING ACTIVITIES:
																		Intercompany transfers	—			—			1,064				(1,064		)		—
																		Proceeds from long-term debt	—			1,957			—				—				1,957
																		Payments of long-term debt	—			(1,988		)	—				—				(1,988		)
																		Proceeds from issuance of commercial paper	—			335			—				—				335
																		Payments of deferred financing costs	—			(4		)	—				—				(4		)
																		Excess purchase price over acquired interests and commodity hedges	—			—			(85		)		—				(85		)
																		Proceeds from issuance of common units, net of offering costs	1,083			—			—				—				1,083
																		Net change in advances to predecessor from DCP Midstream, LLC	—			—			11				—				11
																		Distributions to limited partners and general partner	(277		)	—			—				—				(277		)
																		Distributions to noncontrolling interests	—			—			(24		)		—				(24		)
																		Contributions from noncontrolling interests	—			—			46				—				46
																		Distributions to DCP Midstream, LLC	—			—			(3		)		—				(3		)
																		Contributions from DCP Midstream, LLC	—			—			1				—				1
																		Net cash provided by (used in) financing activities	806			300			1,010				(1,064		)		1,052
																		Net change in cash and cash equivalents	—			(3		)	10				3				10
																		Cash and cash equivalents, beginning of period	—			3			2				(3		)		2
																		Cash and cash equivalents, end of period	$	—		$	—		$	12			$	—			$	12
																		(a)	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																			Condensed Consolidating Statements of Cash Flows
																			Year Ended December 31, 2012 (a)
																			Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																			Guarantor			Issuer			Subsidiaries				Adjustments
																			(Millions)
																		OPERATING ACTIVITIES
																		Net cash (used in) provided by operating activities	$	—		$	(39	)	$	142			$	(1	)		$	102
																		INVESTING ACTIVITIES:
																		Intercompany transfers	(274		)	(827		)	—				1,101				—
																		Capital expenditures	—			—			(484		)		—				(484		)
																		Acquisitions, net of cash acquired	—			—			(745		)		—				(745		)
																		Investments in unconsolidated affiliates	—			—			(158		)		—				(158		)
																		Return of investment from unconsolidated affiliate	—			—			1				—				1
																		Proceeds from sale of assets	—			—			2				—				2
																		Net cash (used in) provided by investing activities	(274		)	(827		)	(1,384		)		1,101				(1,384		)
																		FINANCING ACTIVITIES:
																		Intercompany transfers	—			—			1,101				(1,101		)		—
																		Proceeds from long-term debt	—			2,665			—				—				2,665
																		Payments of long-term debt	—			(1,792		)	—				—				(1,792		)
																		Payment of deferred financing costs	—			(8		)	—				—				(8		)
																		Proceeds from issuance of common units, net of offering costs	455			—			—				—				455
																		Excess purchase price over acquired assets	—			—			(225		)		—				(225		)
																		Net change in advances to predecessor from DCP Midstream, LLC	—			—			336				—				336
																		Distributions to common unitholders and general partner	(181		)	—			—				—				(181		)
																		Distributions to noncontrolling interests	—			—			(9		)		—				(9		)
																		Contributions from noncontrolling interests	—			—			25				—				25
																		Contributions from DCP Midstream, LLC	—			—			10				—				10
																		Net cash provided by (used in) financing activities	274			865			1,238				(1,101		)		1,276
																		Net change in cash and cash equivalents	—			(1		)	(4		)		(1		)		(6		)
																		Cash and cash equivalents, beginning of year	—			4			6				(2		)		8
																		Cash and cash equivalents, end of year	$	—		$	3		$	2			$	(3	)		$	2
																		(a)	The financial information during the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																			Condensed Consolidating Statements of Cash Flows
																			Year Ended December 31, 2011 (a)
																			Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																			Guarantor			Issuer			Subsidiaries				Adjustments
																			(Millions)
																		OPERATING ACTIVITIES
																		Net cash (used in) provided by operating activities	$	—		$	(31	)	$	448			$	—			$	417
																		INVESTING ACTIVITIES:
																		Intercompany transfers	(38		)	(62		)	—				100				—
																		Capital expenditures	—			—			(385		)		—				(385		)
																		Acquisitions, net of cash acquired	—			—			(152		)		—				(152		)
																		Investments in unconsolidated affiliates	—			—			(8		)		—				(8		)
																		Return of investment from unconsolidated affiliate	—			—			2				—				2
																		Proceeds from sale of assets	—			—			5				—				5
																		Net cash (used in) provided by investing activities	(38		)	(62		)	(538		)		100				(538		)
																		FINANCING ACTIVITIES:
																		Intercompany transfers	—			—			100				(100		)		—
																		Proceeds from debt	—			1,524			—				—				1,524
																		Payments of debt	—			(1,425		)	—				—				(1,425		)
																		Payment of deferred financing costs	—			(4		)	—				—				(4		)
																		Proceeds from issuance of common units, net of offering costs	170			—			—				—				170
																		Excess purchase price over acquired unconsolidated affiliates	—			—			(36		)		—				(36		)
																		Net change in advances to predecessor from DCP Midstream, LLC	—			—			52				—				52
																		Distributions to common unitholders and general partner	(132		)	—			—				—				(132		)
																		Distributions to noncontrolling interests	—			—			(45		)		—				(45		)
																		Contributions from noncontrolling interests	—			—			18				—				18
																		Net cash provided by (used in) financing activities	38			95			89				(100		)		122
																		Net change in cash and cash equivalents	—			2			(1		)		—				1
																		Cash and cash equivalents, beginning of year	—			2			7				(2		)		7
																		Cash and cash equivalents, end of year	$	—		$	4		$	6			$	(2	)		$	8
																		(a)	The financial information as of December 31, 2011, includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfers occurred at the beginning of the period, and prior years were retrospectively adjusted to furnish comparative information similar to the pooling method.
																		The parent guarantor, subsidiary issuer and non-guarantor subsidiaries participate in a cash pooling program, whereby cash balances are generally swept daily between the parent guarantor and the non-guarantor subsidiaries bank accounts and those of the subsidiary issuer.
																		Subsequent to the issuance of the 2013 financial statements, management determined that intercompany transfers between the parent guarantor and the non-guarantor subsidiaries, as well as the subsidiary issuer and the non-guarantor subsidiaries, should be classified as investing activities by the parent guarantor and subsidiary issuer and financing activities by the non-guarantor subsidiaries, within the condensed consolidating statements of cash flows. The intercompany transfers had previously been reported as operating activities by the parent guarantor, subsidiary issuer and non-guarantor subsidiaries. The classification of these intercompany transfers has been corrected in the condensed consolidating financial statements for the years ended December 31, 2013, 2012 and 2011. This correction has no impact on the consolidated statement of cash flows for all years presented. These amounts have been included within the line item “intercompany transfers” in investing and financing activities within the condensed consolidating statements of cash flows. The changes to the previously reported amounts are summarized as follows:
																			Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																			Guarantor			Issuer			Subsidiaries				Adjustments
																			(Millions)
																		Year Ended December 31, 2013
																		Net cash (used in) provided by operating activities	$	806		$	258		$	(1,064	)		$	—			$	—
																		Net cash (used in) provided by investing activities	$	(806	)	$	(258	)	$	—			$	1,064			$	—
																		Net cash provided by (used in) financing activities	$	—		$	—		$	1,064			$	(1,064	)		$	—
																		Year Ended December 31, 2012
																		Net cash (used in) provided by operating activities	$	274		$	827		$	(1,101	)		$	—			$	—
																		Net cash (used in) provided by investing activities	$	(274	)	$	(827	)	$	—			$	1,101			$	—
																		Net cash provided by (used in) financing activities	$	—		$	—		$	1,101			$	(1,101	)		$	—
																		Year Ended December 31, 2011
																		Net cash (used in) provided by operating activities	$	38		$	62		$	(100	)		$	—			$	—
																		Net cash (used in) provided by investing activities	$	(38	)	$	(62	)	$	—			$	100			$	—
																		Net cash provided by (used in) financing activities	$	—		$	—		$	100			$	(100	)		$	—

Valuation_and_Qualifying_Accou

Valuation and Qualifying Accounts and Reserves	12 Months Ended
	Dec. 31, 2013
Valuation and Qualifying Accounts [Abstract]	'
Valuation and Qualifying Accounts and Reserves	'
	Valuation and Qualifying Accounts and Reserves
	Our valuation and qualifying accounts and reserves for the years ended December 31, 2013, 2012, and 2011 are as follows:
		Balance at Beginning of Period		Charged to Consolidated Statements of operations		Charged to		Deductions/Other			Balance at End of Period
						Other Accounts
		(Millions)
	December 31, 2013
	Environmental	$	2	$	1	$	—	$	(1	)	$	2
	Other (a)	1		—		—		—			1
		$	3	$	1	$	—	$	(1	)	$	3
	December 31, 2012
	Environmental	$	3	$	—	$	—	$	(1	)	$	2
	Other (a)	1		—		—		—			1
		$	4	$	—	$	—	$	(1	)	$	3
	December 31, 2011
	Environmental	$	3	$	—	$	—	$	—		$	3
	Litigation	1		—		—		(1		)	—
	Other (a)	—		1		—		—			1
		$	4	$	1	$	—	$	(1	)	$	4
	(a)	Principally consists of allowance for doubtful accounts, reserves against other long-term assets, which are included in other long-term assets, and other contingency liabilities, which are included in other current liabilities.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	Subsequent Events
	On January 28, 2014, we announced that the board of directors of the General Partner declared a quarterly distribution of $0.7325 per unit, payable on February 14, 2014 to unitholders of record on February 7, 2014.
	On February 25, 2014, we entered into various transaction documents with DCP Midstream, LLC and its affiliates for the contribution or acquisition of (i) the remaining 20% interest in DCP SC Texas GP; (ii) a 33.33% membership interest in each DCP Southern Hills Pipeline, LLC, which owns the Southern Hills pipeline, and DCP Sand Hills Pipeline, LLC, which owns the Sand Hills pipeline; (iii) the Lucerne 1 plant; and (iv) the Lucerne 2 plant. Total consideration for these transactions at closing was $1,220 million, subject to certain working capital and other customary adjustments. These transactions closed in March 2014. The Southern Hills pipeline is engaged in the business of transporting NGLs, and consists of approximately 800 miles of pipeline, with an expected capacity of 175 MBbls/d after completion of planned pump stations. The pipeline provides NGL takeaway service from the Midcontinent to fractionation facilities along the Texas Gulf Coast and the Mont Belvieu, Texas market hub.The Southern Hills pipeline began taking flows in the first quarter of 2013 and was placed into service in June 2013. The Sand Hills pipeline is also engaged in the business of transporting NGLs and consists of approximately 720 miles of pipeline, with an expected initial capacity of 200 MBbls/d after completion of pump stations, and possible further capacity increases with the installation of additional pump stations. The pipeline provides NGL takeaway service from the Permian and Eagle Ford basins to fractionation facilities along the Texas Gulf Coast and the Mont Belvieu, Texas market hub. The Sand Hills pipeline began taking flows in the fourth quarter of 2012 and was placed into service in June 2013.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Business Combinations	'
	Our predecessor operations consist of a 66.67% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business, which we acquired from DCP Midstream, LLC in March 2012, an 80% interest in the Eagle Ford system, of which we acquired 33.33% and 46.67% in November 2012 and March 2013, respectively, from DCP Midstream, LLC, and our 100% interest in DCP Lucerne 1 Plant, LLC, a 35 MMcf/d cryogenic natural gas processing plant located in Weld County, Colorado, or the Lucerne 1 plant, which we acquired from DCP Midstream, LLC in March 2014. Prior to our acquisition of the remaining 66.67% interest in Southeast Texas, we accounted for our initial 33.33% interest as an unconsolidated affiliate using the equity method. Subsequent to the March 2012 transaction, we own 100% of Southeast Texas which we account for as a consolidated subsidiary. Prior to our acquisition of the additional 46.67% interest in the Eagle Ford system in March 2013, we accounted for our initial 33.33% interest as an unconsolidated affiliate using the equity method. Subsequent to the March 2013 transaction, we own 80% of the Eagle Ford system which we account for as a consolidated subsidiary. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years were retrospectively adjusted to furnish comparative information, similar to the pooling method. Accordingly, our consolidated financial statements include the historical results of our 100% interest in Southeast Texas and the commodity derivative hedge instruments associated with the storage business, our 80% interest in the Eagle Ford system and our Lucerne 1 plant for all periods presented. We recognize transfers of net assets between entities under common control at DCP Midstream, LLC’s basis in the net assets contributed. The amount of the purchase price in excess or in deficit of DCP Midstream, LLC’s basis in the net assets is recognized as a reduction or an addition to limited partners’ equity. The financial statements of our predecessor have been prepared from the separate records maintained by DCP Midstream, LLC and may not necessarily be indicative of the conditions that would have existed or the results of operations if our predecessor had been operated as an unaffiliated entity. In addition, the results of operations for acquisitions accounted for as business combinations have been included in the consolidated financial statements since their respective acquisition dates.
Use of Estimates	'
	Use of Estimates - Conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and notes. Although these estimates are based on management’s best available knowledge of current and expected future events, actual results could differ from those estimates.
Cash and Cash Equivalents	'
	Cash and Cash Equivalents - We consider investments in highly liquid financial instruments purchased with an original stated maturity of 90 days or less and temporary investments of cash in short-term money market securities to be cash equivalents.
Inventories	'
	Inventories - Inventories, which consist primarily of NGLs and natural gas, are recorded at the lower of weighted-average cost or market value. Transportation costs are included in inventory.
Property, Plant and Equipment	'
	Property, Plant and Equipment - Property, plant and equipment are recorded at historical cost. The cost of maintenance and repairs, which are not significant improvements, are expensed when incurred. Depreciation is computed using the straight-line method over the estimated useful lives of the assets.
Goodwill and Intangible Assets	'
	Goodwill and Intangible Assets - Goodwill is the cost of an acquisition less the fair value of the net assets of the acquired business. We perform an annual impairment test of goodwill at the reporting unit level during the third quarter, and update the test during interim periods when we believe events or changes in circumstances indicate that we may not be able to recover the carrying value of a reporting unit. We primarily use a discounted cash flow analysis, supplemented by a market approach analysis, to perform the assessment. Key assumptions in the analysis include the use of an appropriate discount rate, terminal year multiples, and estimated future cash flows including an estimate of operating and general and administrative costs. In estimating cash flows, we incorporate current market information, as well as historical and other factors, into our forecasted commodity prices.
	Intangible assets consist of customer contracts, including commodity purchase, transportation and processing contracts, and related relationships. These intangible assets are amortized on a straight-line basis over the period of expected future benefit. Intangible assets are removed from the gross carrying amount and the total of accumulated amortization in the period in which they become fully amortized.
Long-Lived Assets	'
	Long-Lived Assets - We periodically evaluate whether the carrying value of long-lived assets, including intangible assets, has been impaired when circumstances indicate the carrying value of those assets may not be recoverable. This evaluation is based on undiscounted cash flow projections. The carrying amount is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. We consider various factors when determining if these assets should be evaluated for impairment, including but not limited to:
	•	significant adverse change in legal factors or business climate;
	•	a current-period operating or cash flow loss combined with a history of operating or cash flow losses, or a projection or forecast that demonstrates continuing losses associated with the use of a long-lived asset;
	•	an accumulation of costs significantly in excess of the amount originally expected for the acquisition or construction of a long-lived asset;
	•	significant adverse changes in the extent or manner in which an asset is used, or in its physical condition;
	•	a significant adverse change in the market value of an asset; or
	•	a current expectation that, more likely than not, an asset will be sold or otherwise disposed of before the end of its estimated useful life.
	If the carrying value is not recoverable, the impairment loss is measured as the excess of the asset’s carrying value over its fair value. We assess the fair value of long-lived assets using commonly accepted techniques, and may use more than one method, including, but not limited to, recent third party comparable sales and discounted cash flow models. Significant changes in market conditions resulting from events such as the condition of an asset or a change in management’s intent to utilize the asset would generally require management to reassess the cash flows related to the long-lived assets.
Asset Retirement Obligations	'
	Asset Retirement Obligations - Our asset retirement obligations relate primarily to the retirement of various gathering pipelines and processing facilities, obligations related to right-of-way easement agreements, and contractual leases for land use. We adjust our asset retirement obligation each quarter for any liabilities incurred or settled during the period, accretion expense and any revisions made to the estimated cash flows.
	Asset retirement obligations associated with tangible long-lived assets are recorded at fair value in the period in which they are incurred, if a reasonable estimate of fair value can be made, and added to the carrying amount of the associated asset. This additional carrying amount is then depreciated over the life of the asset. The liability is determined using a risk free interest rate, and accretes due to the passage of time based on the time value of money until the obligation is settled.
Investments in Unconsolidated Affiliates	'
	Investments in greater than 20% owned affiliates that are not variable interest entities and where we do not have the ability to exercise control, and investments in less than 20% owned affiliates where we have the ability to exercise significant influence, are accounted for using the equity method.
	Investments in Unconsolidated Affiliates - We use the equity method to account for investments in greater than 20% owned affiliates that are not variable interest entities and where we do not have the ability to exercise control, and investments in less than 20% owned affiliates where we have the ability to exercise significant influence.
	We evaluate our investments in unconsolidated affiliates for impairment whenever events or changes in circumstances indicate that the carrying value of such investments may have experienced a decline in value. When there is evidence of loss in value, we compare the estimated fair value of the investment to the carrying value of the investment to determine whether impairment has occurred. We assess the fair value of our investments in unconsolidated affiliates using commonly accepted techniques, and may use more than one method, including, but not limited to, recent third party comparable sales and discounted cash flow models. If the estimated fair value is considered to be permanently less than the carrying value, the excess of the carrying value over the estimated fair value is recognized as an impairment loss.
Unamortized Debt Expense	'
	Unamortized Debt Expense - Expenses incurred with the issuance of long-term debt are amortized over the term of the debt using the effective interest method. These expenses are recorded on the consolidated balance sheet as other long-term assets.
Noncontrolling Interest	'
	The consolidated financial statements include the accounts of the Partnership and all majority-owned subsidiaries where we have the ability to exercise control.
	Noncontrolling Interest - Noncontrolling interest represents any third party or affiliate interest in non-wholly owned entities that we consolidate. For financial reporting purposes, the assets and liabilities of these entities are consolidated with those of our own, with any third party or affiliate interest in our consolidated balance sheet amounts shown as noncontrolling interest in equity. Distributions to and contributions from noncontrolling interests represent cash payments to and cash contributions from, respectively, such third party and affiliate investors.
Accounting for Risk Management Activities and Financial Instruments	'
	Accounting for Risk Management Activities and Financial Instruments - Non-trading energy commodity derivatives are designated as either a hedge of a forecasted transaction or future cash flow (cash flow hedge), a hedge of a recognized asset, liability or firm commitment (fair value hedge), or normal purchases or normal sales. The remaining non-trading derivatives, which are related to asset-based activities for which the normal purchase or normal sale exception is not elected, are recorded at fair value in the consolidated balance sheets as unrealized gains or unrealized losses in derivative instruments, with changes in the fair value recognized in the consolidated statements of operations. For each derivative, the accounting method and presentation of gains and losses or revenue and expense in the consolidated statements of operations are as follows:
	Classification of Contract	Accounting Method	Presentation of Gains & Losses or Revenue & Expense
	Cash Flow Hedge	Hedge method (a)	Gross basis in the same consolidated statements of operations category as the related hedged item
	Fair Value Hedge	Hedge method (a)	Gross basis in the same consolidated statements of operations category as the related hedged item
	Normal Purchases or Normal Sales	Accrual method (b)	Gross basis upon settlement in the corresponding consolidated statements of operations category based on purchase or sale
	Other Non-Trading Derivative Activity	Mark-to-market method (c)	Net basis in gains and losses from commodity derivative activity
	______________
	(a)	Hedge method - An accounting method whereby the change in the fair value of the asset or liability is recorded in the consolidated balance sheets as unrealized gains or unrealized losses on derivative instruments. For cash flow hedges, there is no recognition in the consolidated statements of operations for the effective portion until the service is provided or the associated delivery period impacts earnings. For fair value hedges, the change in the fair value of the asset or liability, as well as the offsetting changes in value of the hedged item, are recognized in the consolidated statements of operations in the same category as the related hedged item.
	(b)	Accrual method - An accounting method whereby there is no recognition in the consolidated balance sheets or consolidated statements of operations for changes in fair value of a contract until the service is provided or the associated delivery period impacts earnings.
	(c)	Mark-to-market method - An accounting method whereby the change in the fair value of the asset or liability is recognized in the consolidated statements of operations in gains and losses from commodity derivative activity during the current period.
	Cash Flow and Fair Value Hedges - For derivatives designated as a cash flow hedge or a fair value hedge, we maintain formal documentation of the hedge. In addition, we formally assess both at the inception of the hedging relationship and on an ongoing basis, whether the hedge contract is highly effective in offsetting changes in cash flows or fair values of hedged items. All components of each derivative gain or loss are included in the assessment of hedge effectiveness, unless otherwise noted.
	The fair value of a derivative designated as a cash flow hedge is recorded in the consolidated balance sheets as unrealized gains or unrealized losses on derivative instruments. The change in fair value of the effective portion of a derivative designated as a cash flow hedge is recorded in partners’ equity in accumulated other comprehensive income, or AOCI, and the ineffective portion is recorded in the consolidated statements of operations. During the period in which the hedged transaction impacts earnings, amounts in AOCI associated with the hedged transaction are reclassified to the consolidated statements of operations in the same line item as the item being hedged. Hedge accounting is discontinued prospectively when it is determined that the derivative no longer qualifies as an effective hedge, or when it is probable that the hedged transaction will not occur. When hedge accounting is discontinued because the derivative no longer qualifies as an effective hedge, the derivative is subject to the mark-to-market accounting method prospectively. The derivative continues to be carried on the consolidated balance sheets at its fair value; however, subsequent changes in its fair value are recognized in current period earnings. Gains and losses related to discontinued hedges that were previously accumulated in AOCI will remain in AOCI until the hedged transaction impacts earnings, unless it is probable that the hedged transaction will not occur, in which case, the gains and losses that were previously deferred in AOCI will be immediately recognized in current period earnings.
	The fair value of a derivative designated as a fair value hedge is recorded for balance sheet purposes as unrealized gains or unrealized losses on derivative instruments. We recognize the gain or loss on the derivative instrument, as well as the offsetting loss or gain on the hedged item in earnings in the current period. All derivatives designated and accounted for as fair value hedges are classified in the same category as the item being hedged in the results of operations.
	Valuation - When available, quoted market prices or prices obtained through external sources are used to determine a contract’s fair value. For contracts with a delivery location or duration for which quoted market prices are not available, fair value is determined based on pricing models developed primarily from historical relationships with quoted market prices and the expected relationship with quoted market prices.
	Values are adjusted to reflect the credit risk inherent in the transaction as well as the potential impact of liquidating open positions in an orderly manner over a reasonable time period under current conditions. Changes in market prices and management estimates directly affect the estimated fair value of these contracts. Accordingly, it is reasonably possible that such estimates may change in the near term.
Revenue Recognition	'
	Revenue Recognition - We generate the majority of our revenues from gathering, compressing, treating, processing, transporting, storing and selling of natural gas, and producing, fractionating, transporting, storing and selling NGLs and recovering and selling condensate. Once natural gas is produced from wells, producers then seek to deliver the natural gas and its components to end-use markets. We realize revenues either by selling the residue natural gas, NGLs and condensate, or by receiving fees. We also generate revenue from transporting, storing and selling propane.
	We obtain access to commodities and provide our midstream services principally under contracts that contain a combination of one or more of the following arrangements:
	•	Fee-based arrangements - Under fee-based arrangements, we receive a fee or fees for one or more of the following services: gathering, compressing, treating, processing, transporting or storing natural gas; and fractionating, storing and transporting NGLs. Our fee-based arrangements include natural gas arrangements pursuant to which we obtain natural gas at the wellhead or other receipt points, at an index related price at the delivery point less a specified amount, generally the same as the transportation fees we would otherwise charge for transportation of natural gas from the wellhead location to the delivery point. The revenues we earn are directly related to the volume of natural gas or NGLs that flows through our systems and are not directly dependent on commodity prices. However, to the extent a sustained decline in commodity prices results in a decline in volumes, our revenues from these arrangements would be reduced.
	•	Percent-of-proceeds/liquids arrangements - Under percent-of-proceeds arrangements, we generally purchase natural gas from producers at the wellhead, or other receipt points, gather the wellhead natural gas through our gathering system, treat and process the natural gas, and then sell the resulting residue natural gas, NGLs and condensate based on index prices from published index market prices. We remit to the producers either an agreed-upon percentage of the actual proceeds that we receive from our sales of the residue natural gas, NGLs and condensate, or an agreed-upon percentage of the proceeds based on index related prices for the natural gas, NGLs and condensate, regardless of the actual amount of the sales proceeds we receive. We keep the difference between the proceeds received and the amount remitted back to the producer. Under percent-of-liquids arrangements, we do not keep any amounts related to residue natural gas proceeds and only keep amounts related to the difference between the proceeds received and the amount remitted back to the producer related to NGLs and condensate. Certain of these arrangements may also result in the producer retaining title to all or a portion of the residue natural gas and/or the NGLs, in lieu of us returning sales proceeds to the producer. Additionally, these arrangements may include fee-based components. Our revenues under percent-of-proceeds arrangements relate directly with the price of natural gas, NGLs and condensate. Our revenues under percent-of-liquids arrangements relate directly with the price of NGLs and condensate.
	•	Propane sales arrangements - Under propane sales arrangements, we generally purchase propane from natural gas processing plants and fractionation facilities, and crude oil refineries. We sell propane on a wholesale basis to propane distributors, who in turn resell to their customers. Our sales of propane are not contingent upon the resale of propane by propane distributors to their customers.
	Our marketing of natural gas and NGLs consists of physical purchases and sales, as well as positions in derivative instruments.
	We recognize revenues for sales and services under the four revenue recognition criteria, as follows:
	•	Persuasive evidence of an arrangement exists - Our customary practice is to enter into a written contract.
	•	Delivery - Delivery is deemed to have occurred at the time custody is transferred, or in the case of fee-based arrangements, when the services are rendered. To the extent we retain product as inventory, delivery occurs when the inventory is subsequently sold and custody is transferred to the third party purchaser.
	•	The fee is fixed or determinable - We negotiate the fee for our services at the outset of our fee-based arrangements. In these arrangements, the fees are nonrefundable. For other arrangements, the amount of revenue, based on contractual terms, is determinable when the sale of the applicable product has been completed upon delivery and transfer of custody.
	•	Collectability is reasonably assured - Collectability is evaluated on a customer-by-customer basis. New and existing customers are subject to a credit review process, which evaluates the customers’ financial position (for example, credit metrics, liquidity and credit rating) and their ability to pay. If collectability is not considered probable at the outset of an arrangement in accordance with our credit review process, revenue is not recognized until the cash is collected.
	We generally report revenues gross in the consolidated statements of operations, as we typically act as the principal in these transactions, take custody to the product, and incur the risks and rewards of ownership. We recognize revenues for non-trading commodity derivative activity net in the consolidated statements of operations as gains and losses from commodity derivative activity. These activities include mark-to-market gains and losses on energy trading contracts and the settlement of financial and physical energy trading contracts.
	Quantities of natural gas or NGLs over-delivered or under-delivered related to imbalance agreements with customers, producers or pipelines are recorded monthly as accounts receivable or accounts payable using current market prices or the weighted-average prices of natural gas or NGLs at the plant or system. These balances are settled with deliveries of natural gas or NGLs, or with cash.
Significant Customers	'
	Significant Customers - There were no third party customers that accounted for more than 10% of total operating revenues for the years ended December 31, 2013, 2012 and 2011. We had significant transactions with affiliates.
Environmental Expenditures	'
	Environmental Expenditures - Environmental expenditures are expensed or capitalized as appropriate, depending upon the future economic benefit. Expenditures that relate to an existing condition caused by past operations and that do not generate current or future revenue are expensed. Liabilities for these expenditures are recorded on an undiscounted basis when environmental assessments and/or clean-ups are probable and the costs can be reasonably estimated.
Equity-Based Compensation	'
	Equity-Based Compensation - Equity classified share-based compensation cost is measured at fair value, based on the closing common unit price at grant date, and is recognized as expense over the vesting period. Liability classified share-based compensation cost is remeasured at each reporting date at fair value, based on the closing common unit price, and is recognized as expense over the requisite service period. Compensation expense for awards with graded vesting provisions is recognized on a straight-line basis over the requisite service period of each separately vesting portion of the award. Awards granted to non-employees for acquiring, or in conjunction with selling, goods and services are measured at the estimated fair value of the goods or services, or the fair value of the award, whichever is more reliably measured.
Allowance for Doubtful Accounts	'
	Allowance for Doubtful Accounts - Management estimates the amount of required allowances for the potential non-collectability of accounts receivable generally based upon the number of days past due, past collection experience and consideration of other relevant factors. However, past experience may not be indicative of future collections and therefore additional charges could be incurred in the future to reflect differences between estimated and actual collections.
Income Taxes	'
	Income Taxes - We are structured as a master limited partnership which is a pass-through entity for federal income tax purposes. Our income tax expense includes certain jurisdictions, including state, local, franchise and margin taxes of the master limited partnership and subsidiaries. We follow the asset and liability method of accounting for income taxes. Under this method, deferred income taxes are recognized for the tax consequences of temporary differences between the financial statement carrying amounts and the tax basis of the assets and liabilities. Our taxable income or loss, which may vary substantially from the net income or loss reported in the consolidated statements of operations, is proportionately included in the federal returns of each partner.
Net Income or Loss Per Limited Partner Unit	'
	Net Income or Loss per Limited Partner Unit - Basic and diluted net income or loss per limited partner unit, or LPU, is calculated by dividing net income or loss allocable to limited partners, by the weighted-average number of outstanding LPUs during the period. Diluted net income or loss per limited partner unit is computed based on the weighted average number of units plus the effect of dilutive potential units outstanding during the period using the two-class method.
Capitalized Interest	'
	Capitalized Interest - We capitalize interest during construction of major projects. Interest is calculated on the monthly outstanding capital balance and ceases in the month that the asset is placed into service. We also capitalize interest on our equity method investments which are devoting substantially all efforts to establishing a new business and have not yet begun planned principal operations. Capitalization ceases when the investee commences planned principal operations. The rates used to calculate capitalized interest are the weighted-average cost of debt, including the impact of interest rate swaps.
Commodity Price Risk	'
	Cash Flow Protection Activities — We are exposed to the impact of market fluctuations in the prices of natural gas, NGLs and condensate as a result of our gathering, processing, sales and storage activities. For gathering, processing and storage services, we may receive cash or commodities as payment for these services, depending on the contract type. We enter into derivative financial instruments to mitigate a portion of the risk of weakening natural gas, NGL and condensate prices associated with our gathering, processing and sales activities, thereby stabilizing our cash flows. We have mitigated a significant portion of our expected commodity price risk associated with our gathering, processing and sales activities through 2017 with commodity derivative instruments. Our commodity derivative instruments used for our hedging program are a combination of direct NGL product, crude oil, and natural gas hedges. Due to the limited liquidity and tenor of the NGL derivative market, we have used crude oil swaps and costless collars to mitigate a portion of our commodity price exposure to NGLs. Historically, prices of NGLs have generally been related to crude oil prices; however, there are periods of time when NGL pricing may be at a greater discount to crude oil, resulting in additional exposure to NGL commodity prices. The relationship of NGLs to crude oil continues to be lower than historical relationships; however, a significant amount of our NGL hedges from 2014 through 2017 are direct product hedges. When our crude oil swaps become short-term in nature, we have periodically converted certain crude oil derivatives to NGL derivatives by entering into offsetting crude oil swaps while adding NGL swaps. Our crude oil and NGL transactions are primarily accomplished through the use of forward contracts that effectively exchange our floating price risk for a fixed price. We also utilize crude oil costless collars that minimize our floating price risk by establishing a fixed price floor and a fixed price ceiling. However, the type of instrument that we use to mitigate a portion of our risk may vary depending upon our risk management objective. These transactions are not designated as hedging instruments for accounting purposes and the change in fair value is reflected within our consolidated statements of operations as a gain or a loss on commodity derivative activity.
	Our Wholesale Propane Logistics segment is generally designed to establish stable margins by entering into supply arrangements that specify prices based on established floating price indices and by entering into sales agreements that provide for floating prices that are tied to our variable supply costs plus a margin. To the extent possible, we match the pricing of our supply portfolio to our sales portfolio in order to lock in value and reduce our overall commodity price risk. However, to the extent that we carry propane inventories or our sales and supply arrangements are not aligned, we are exposed to market variables and commodity price risk. We manage the commodity price risk of our supply portfolio and sales portfolio with both physical and financial transactions, including fixed price sales. While the majority of our sales and purchases in this segment are index-based, occasionally, we may enter into fixed price sales agreements in the event that a propane distributor desires to purchase propane from us on a fixed price basis. In such cases, we may manage this risk with derivatives that allow us to swap our fixed price risk to market index prices that are matched to our market index supply costs. In addition, we may use financial derivatives to manage the value of our propane inventories. These transactions are not designated as hedging instruments for accounting purposes and any change in fair value is reflected in the current period within our consolidated statements of operations as a gain or loss on commodity derivative activity.
	Our portfolio of commodity derivative activity is primarily accounted for using the mark-to-market method of accounting, whereby changes in fair value are recorded directly to the consolidated statements of operations; however, depending upon our risk profile and objectives, in certain limited cases, we may execute transactions that qualify for the hedge method of accounting.
	Natural Gas Storage and Pipeline Asset Based Commodity Derivative Program — Our natural gas storage and pipeline assets are exposed to certain risks including changes in commodity prices. We manage commodity price risk related to our natural gas storage and pipeline assets through our commodity derivative program. The commercial activities related to our natural gas storage and pipeline assets primarily consist of the purchase and sale of gas and associated time spreads and basis spreads.
	A time spread transaction is executed by establishing a long gas position at one point in time and establishing an equal short gas position at a different point in time. Time spread transactions allow us to lock in a margin supported by the injection, withdrawal, and storage capacity of our natural gas storage assets. We may execute basis spread transactions to mitigate the risk of sale and purchase price differentials across our system. A basis spread transaction allows us to lock in a margin on our physical purchases and sales of gas, including injections and withdrawals from storage. We typically use swaps to execute these transactions, which are not designated as hedging instruments and are recorded at fair value with changes in fair value recorded in the current period consolidated statements of operations. While gas held in our storage locations is recorded at the lower of average cost or market, the derivative instruments that are used to manage our storage facilities are recorded at fair value and any changes in fair value are currently recorded in our consolidated statements of operations. Even though we may have economically hedged our exposure and locked in a future margin, the use of lower-of-cost-or-market accounting for our physical inventory and the use of mark-to-market accounting for our derivative instruments may subject our earnings to market volatility.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Schedule of Derivatives, Accounting Method and Presentation	'
	For each derivative, the accounting method and presentation of gains and losses or revenue and expense in the consolidated statements of operations are as follows:
	Classification of Contract	Accounting Method	Presentation of Gains & Losses or Revenue & Expense
	Cash Flow Hedge	Hedge method (a)	Gross basis in the same consolidated statements of operations category as the related hedged item
	Fair Value Hedge	Hedge method (a)	Gross basis in the same consolidated statements of operations category as the related hedged item
	Normal Purchases or Normal Sales	Accrual method (b)	Gross basis upon settlement in the corresponding consolidated statements of operations category based on purchase or sale
	Other Non-Trading Derivative Activity	Mark-to-market method (c)	Net basis in gains and losses from commodity derivative activity
	______________
	(a)	Hedge method - An accounting method whereby the change in the fair value of the asset or liability is recorded in the consolidated balance sheets as unrealized gains or unrealized losses on derivative instruments. For cash flow hedges, there is no recognition in the consolidated statements of operations for the effective portion until the service is provided or the associated delivery period impacts earnings. For fair value hedges, the change in the fair value of the asset or liability, as well as the offsetting changes in value of the hedged item, are recognized in the consolidated statements of operations in the same category as the related hedged item.
	(b)	Accrual method - An accounting method whereby there is no recognition in the consolidated balance sheets or consolidated statements of operations for changes in fair value of a contract until the service is provided or the associated delivery period impacts earnings.
	(c)	Mark-to-market method - An accounting method whereby the change in the fair value of the asset or liability is recognized in the consolidated statements of operations in gains and losses from commodity derivative activity during the current period.

Acquisitions_Tables

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2013
Business Acquisition [Line Items]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	'
	The following table summarizes the aggregate consideration and fair value of the identifiable assets acquired and liabilities assumed in the acquisition of Crossroads as of the acquisition date:
		3-Jul-12
		(Millions)
	Aggregate consideration	$	63
	Accounts receivable	$	4
	Property, plant and equipment	63
	Investments in unconsolidated affiliates	6
	Other current liabilities	(4		)
	Other long-term liabilities	(6		)
	Total	$	63
Business Acquisition, Pro Forma Information	'
	The following tables present unaudited supplemental pro forma information for the consolidated statement of operations for the years ended December 31, 2012 and 2011, as if the acquisition of Crossroads had occurred at the beginning of the earliest period presented.
		Year Ended December 31, 2012
		DCP Midstream Partners, LP				Acquisition of			DCP Midstream Partners, LP Pro Forma
						Crossroads (a)
		(Millions)
	Total operating revenues	$	2,824			$	27		$	2,851
	Net income attributable to partners	$	216			$	2		$	218
	Less:
	Net income attributable to predecessor operations	(51		)		—			(51		)
	General partner’s interest in net income	(41		)		—			(41		)
	Net income allocable to limited partners	$	124			$	2		$	126
	Net income per limited partner unit - basic and diluted	$	2.28			$	0.03		$	2.31
	(a)	The year ended December 31, 2012 includes the financial results of Crossroads for the period from January 1, 2012 through July 2, 2012.
		Year Ended December 31, 2011
		DCP Midstream Partners, LP				Acquisition of			DCP Midstream Partners, LP Pro Forma
						Crossroads
		(Millions)
	Total operating revenues	$	3,790			$	114		$	3,904
	Net income attributable to partners	$	191			$	4		$	195
	Less:
	Net income attributable to predecessor operations	(91		)		—			(91		)
	General partner’s interest in net income	(25		)		—			(25		)
	Net income allocable to limited partners	$	75			$	4		$	79
	Net income per limited partner unit - basic	$	1.73			$	0.09		$	1.82
	Net income per limited partner unit - diluted	$	1.72			$	0.09		$	1.81
Income Statement [Member]	'
Business Acquisition [Line Items]	'
Schedule of Impact on Financial Statements Due to Acquisition	'
	The following table presents the previously reported consolidated statement of operations for the year ended December 31, 2012, adjusted for the acquisition of our Lucerne 1 plant from DCP Midstream, LLC:
	Year Ended December 31, 2012
		DCP				Consolidate Lucerne 1 plant			Consolidated DCP Midstream Partners, LP (As currently reported)
		Midstream
		Partners, LP
		(As previously
		reported on Form 10-K filed on 2/26/14)
		(Millions)
	Sales of natural gas, propane, NGLs and condensate	$	2,459			$	61		$	2,520
	Transportation, processing and other	232				2			234
	Losses from commodity derivative activity, net	70				—			70
	Total operating revenues	2,761				63			2,824
	Operating costs and expenses:
	Purchases of natural gas, propane and NGLs	2,177				38			2,215
	Operating and maintenance expense	193				4			197
	Depreciation and amortization expense	89				2			91
	General and administrative expense	74				1			75
	Total operating costs and expenses	2,533				45			2,578
	Operating income	228				18			246
	Interest expense	(42		)		—			(42		)
	Earnings from unconsolidated affiliates	26				—			26
	Income before income taxes	212				18			230
	Income tax expense	(1		)		—			(1		)
	Net income	211				18			229
	Net income attributable to noncontrolling interests	(13		)		—			(13		)
	Net income attributable to partners	$	198			$	18		$	216
	Year Ended December 31, 2011
	The results of our Lucerne 1 plant are included in the consolidated statement of operations for the year ended December 31, 2011. The following table presents the previously reported consolidated statement of operations for the year ended December 31, 2011 adjusted for the acquisition of our Lucerne 1 plant from DCP Midstream, LLC:
			DCP				Consolidate Lucerne 1 plant			Consolidated DCP Midstream Partners, LP (As currently reported)
			Midstream
			Partners, LP
			(As previously
			reported on Form 10-K filed on 2/26/14)
			(Millions)
	Sales of natural gas, propane, NGLs and condensate		$	3,487			$	87		$	3,574
	Transportation, processing and other		205				3			208
	Gains from commodity derivative activity, net		8				—			8
	Total operating revenues		3,700				90			3,790
	Operating costs and expenses:
	Purchases of natural gas, propane and NGLs		3,100				55			3,155
	Operating and maintenance expense		188				4			192
	Depreciation and amortization expense		133				2			135
	General and administrative expense		75				1			76
	Other income		(1		)		—			(1		)
	Total operating costs and expenses		3,495				62			3,557
	Operating income		205				28			233
	Interest expense		(34		)		—			(34		)
	Earnings from unconsolidated affiliates		23				—			23
	Income before income taxes		194				28			222
	Income tax expense		(1		)		—			(1		)
	Net income		193				28			221
	Net income attributable to noncontrolling interests		(30		)		—			(30		)
	Net income attributable to partners		$	163			$	28		$	191
Balance Sheet [Member]	'
Business Acquisition [Line Items]	'
Schedule of Impact on Financial Statements Due to Acquisition	'
	The following table presents the previously reported December 31, 2012 consolidated balance sheet, adjusted for the acquisition of our Lucerne 1 plant from DCP Midstream, LLC:
	As of December 31, 2012
		DCP				Consolidate Lucerne 1 plant			Consolidated DCP Midstream Partners, LP (As currently reported)
		Midstream
		Partners, LP
		(As previously
		reported on Form 10-K filed on 2/26/14)
		(Millions)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	2			$	—		$	2
	Accounts receivable	239				—			239
	Inventories	76				—			76
	Other	51				—			51
	Total current assets	368				—			368
	Property, plant and equipment, net	2,550				42			2,592
	Goodwill and intangible assets, net	291				—			291
	Investments in unconsolidated affiliates	304				—			304
	Other non-current assets	90				—			90
	Total assets	$	3,603			$	42		$	3,645
	LIABILITIES AND EQUITY
	Accounts payable and other current liabilities	$	345			$	—		$	345
	Long-term debt	1,620				—			1,620
	Other long-term liabilities	44				—			44
	Total liabilities	2,009				—			2,009
	Commitments and contingent liabilities
	Equity:
	Partners’ equity
	Net equity	1,420				42			1,462
	Accumulated other comprehensive loss	(15		)		—			(15		)
	Total partners’ equity	1,405				42			1,447
	Noncontrolling interests	189				—			189
	Total equity	1,594				42			1,636
	Total liabilities and equity	$	3,603			$	42		$	3,645

Agreements_and_Transactions_wi1

Agreements and Transactions with Affiliates (Tables)	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Schedule of Fees Incurred and Other Fees Paid	'
	ollowing is a summary of the fees we incurred under the Services and Omnibus Agreements, as well as other fees paid to DCP Midstream, LLC:
			Year Ended
			December 31,
			2013			2012		2011
			(Millions)
	Services/Omnibus Agreement		$	29		$	26	$	10
	Other fees — DCP Midstream, LLC		17			32		47
	Total — DCP Midstream, LLC		$	46		$	58	$	57
Summary of Transactions with Affiliates	'
	The following table summarizes our transactions with affiliates:
			Year Ended
			December 31,
			2013			2012		2011
			(Millions)
	DCP Midstream, LLC:
	Sales of natural gas, propane, NGLs and condensate		$	1,830		$	1,691	$	2,346
	Transportation, processing and other		$	60		$	52	$	30
	Purchases of natural gas, propane and NGLs		$	204		$	173	$	244
	Gains from commodity derivative activity, net		$	22		$	53	$	1
	Operating and maintenance expense		$	1		$	1	$	1
	General and administrative expense		$	46		$	58	$	57
	Phillips 66:
	Sales of natural gas, propane, NGLs and condensate		$	1		$	—	$	—
	ConocoPhillips (a):
	Sales of natural gas, propane, NGLs and condensate		$	—		$	9	$	57
	Transportation, processing and other		$	—		$	3	$	9
	Purchases of natural gas, propane and NGLs		$	—		$	67	$	139
	Spectra Energy:
	Purchases of natural gas, propane and NGLs		$	63		$	166	$	321
	Unconsolidated affiliates:
	Purchases of natural gas, propane and NGLs		$	—		$	2	$	6
	(a)	In connection with Phillips 66's separation from ConocoPhillips, ConocoPhillips is not considered to be a related party for periods after April 30, 2012 and Phillips 66 is considered a related party for periods starting May 1, 2012.
	We had balances with affiliates as follows:
		December 31,			December 31,
		2013			2012
		(Millions)
	DCP Midstream, LLC:
	Accounts receivable	$	211		$	132
	Accounts payable	$	37		$	66
	Unrealized gains on derivative instruments — current	$	79		$	48
	Unrealized gains on derivative instruments — long-term	$	81		$	64
	Unrealized losses on derivative instruments — current	$	18		$	(11	)
	Unrealized losses on derivative instruments — long-term	$	1		$	—
	Spectra Energy:
	Accounts receivable	$	1		$	—
	Accounts payable	$	6		$	5
	Unconsolidated affiliates:
	Accounts payable	$	—		$	1

Inventories_Tables

Inventories (Tables)	12 Months Ended
	Dec. 31, 2013
Inventory Disclosure [Abstract]	'
Schedule of Inventories	'
	Inventories were as follows:
		December 31,		December 31,
		2013		2012
		(Millions)
	Natural gas	$	38	$	22
	NGLs	29		54
	Total inventories	$	67	$	76

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Classification of Property, Plant and Equipment	'
	A summary of property, plant and equipment by classification is as follows:
		Depreciable	December 31,			December 31,
		Life	2013			2012
			(Millions)
	Gathering and transmission systems	20 — 50 Years	$	2,205		$	1,921
	Processing, storage, and terminal facilities	35 — 60 Years	1,645			1,154
	Other	3 —  30 Years	49			32
	Construction work in progress		310			561
	Property, plant and equipment		4,209			3,668
	Accumulated depreciation		(1,163		)	(1,076		)
	Property, plant and equipment, net		$	3,046		$	2,592

Goodwill_and_Intangible_Assets1

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of amortizable intangible assets	'
	The gross carrying amount and accumulated amortization of these intangible assets are included in the accompanying consolidated balance sheets as intangible assets, net, and are as follows:
		December 31,
		2013			2012
		(Millions)
	Gross carrying amount	$	164		$	164
	Accumulated amortization	(35		)	(27		)
	Intangible assets, net	$	129		$	137
Schedule of estimated future amortization expense	'
	Estimated future amortization for these intangible assets is as follows:
	Estimated Future Amortization
	(Millions)
	2014	$	8
	2015	8
	2016	8
	2017	8
	2018	8
	Thereafter	89
	Total	$	129

Investments_in_Unconsolidated_1

Investments in Unconsolidated Affiliates (Tables)	12 Months Ended
	Dec. 31, 2013
Equity Method Investments and Joint Ventures [Abstract]	'
Investments in Unconsolidated Affiliates	'
	The following table summarizes our investments in unconsolidated affiliates:
				Carrying Value as of
		Percentage		December 31,				December 31,
		Ownership		2013				2012
				(Millions)
	Discovery Producer Services LLC	40%		$	348			$	223
	Front Range Pipeline LLC	33.33%		134				—
	Texas Express Pipeline	10%		96				41
	Mont Belvieu Enterprise Fractionator	12.50%		26				19
	Mont Belvieu 1 Fractionator	20%		16				14
	CrossPoint Pipeline, LLC	50%		6				6
	Other	Various		1				1
	Total investments in unconsolidated affiliates			$	627			$	304
Earnings from Investments in Unconsolidated Affiliates	'
	Earnings from investments in unconsolidated affiliates were as follows:
		Year Ended December 31,
		2013				2012				2011
		(Millions)
	Mont Belvieu 1 Fractionator	$	19			$	6			$	—
	Mont Belvieu Enterprise Fractionator	14				5				—
	Discovery Producer Services LLC	1				15				23
	Texas Express	(1		)		—				—
	Total earnings from unconsolidated affiliates	$	33			$	26			$	23
Equity Method Investment Summarized Financial Information, Statement of Operations	'
	The following tables summarize the combined financial information of our investments in unconsolidated affiliates:
		Year Ended December 31,
		2013				2012				2011
		(Millions)
	Statements of operations:
	Operating revenue	$	484			$	293			$	213
	Operating expenses	$	298			$	190			$	163
	Net income	$	186			$	103			$	50
Equity Method Investment Summarized Financial Information, Balance Sheet	'
		December 31,				December 31,
		2013				2012
		(Millions)
	Balance sheets:
	Current assets	$	182			$	129
	Long-term assets	2,678				1,288
	Current liabilities	(276		)		(75		)
	Long-term liabilities	(37		)		(43		)
	Net assets	$	2,547			$	1,299

Fair_Value_Measurement_Tables

Fair Value Measurement (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Financial Instruments Carried at Fair Value	'
	The following table presents the financial instruments carried at fair value as of December 31, 2013 and December 31, 2012, by consolidated balance sheet caption and by valuation hierarchy, as described above:
		31-Dec-13												31-Dec-12
		Level 1			Level 2			Level 3			Total			Level 1		Level 2			Level 3			Total
											Carrying											Carrying
											Value											Value
		(Millions)
	Current assets (a):
	Commodity derivatives	$	—		$	14		$	65		$	79		$	—	$	9		$	40		$	49
	Short-term investments (b)	$	9		$	—		$	—		$	9		$	2	$	—		$	—		$	2
	Long-term assets (c):
	Commodity derivatives	$	—		$	12		$	75		$	87		$	—	$	5		$	65		$	70
	Current liabilities (d):
	Commodity derivatives	$	—		$	(26	)	$	—		$	(26	)	$	—	$	(26	)	$	(1	)	$	(27	)
	Interest rate derivatives	$	—		$	(2	)	$	—		$	(2	)	$	—	$	(4	)	$	—		$	(4	)
	Long-term liabilities (e):
	Commodity derivatives	$	—		$	(1	)	$	—		$	(1	)	$	—	$	(6	)	$	—		$	(6	)
	Interest rate derivatives	$	—		$	—		$	—		$	—		$	—	$	(2	)	$	—		$	(2	)
	(a)	Included in current unrealized gains on derivative instruments in our consolidated balance sheets.
	(b)	Includes short-term money market securities included in cash and cash equivalents in our consolidated balance sheets.
	(c)	Included in long-term unrealized gains on derivative instruments in our consolidated balance sheets.
	(d)	Included in current unrealized losses on derivative instruments in our consolidated balance sheets.
	(e)	Included in long-term unrealized losses on derivative instruments in our consolidated balance sheets.
Condensed Consolidated Balance Sheets for Derivative Financial Instruments	'
		Commodity Derivative Instruments
		Current			Long-			Current			Long-
		Assets			Term			Liabilities			Term
					Assets						Liabilities
		(Millions)
	Year ended December 31, 2013 (a):
	Beginning balance	$	40		$	65		$	(1	)	$	—
	Net realized and unrealized gains (losses) included in earnings (c)	42			(50		)	—			—
	Transfers into Level 3 (b)	—			—			—
	Transfers out of Level 3 (b)	(1		)	(2		)	1			—
	Settlements	(40		)	—			—			—
	Purchases	24			62			—			—
	Ending balance	$	65		$	75		$	—		$	—
	Net unrealized gains (losses) still held included in earnings (c)	$	41		$	(50	)	$	—		$	—
	Year ended December 31, 2012 (a):
	Beginning balance	$	1		$	1		$	(1	)	$	—
	Net realized and unrealized gains included in earnings (c)	14			2			—			—
	Transfers into Level 3 (b)	—			—			—			—
	Transfers out of Level 3 (b)	—			—			—			—
	Settlements	(2		)	—			—			—
	Purchases	27			62			—			—
	Ending balance	$	40		$	65		$	(1	)	$	—
	Net unrealized gains still held included in earnings (c)	$	13		$	2		$	—		$	—
	(a)	There were no issuances or sales of derivatives for the years ended December 31, 2013 and 2012.
	(b)	Amounts transferred in and amounts transferred out are reflected at fair value as of the end of the period.
	(c)	Represents the amount of total gains or losses for the year, included in gains or losses from commodity derivative activity, net, attributable to changes in unrealized gains or losses relating to assets and liabilities classified as Level 3.
Schedule of Valuation Processes	'
		31-Dec-13
	Product Group	Fair Value			Forward
					Curve Range
		(Millions)
	Assets
	NGLs	$	140		$0.27-$2.11		Per gallon

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Schedule of Debt	'
		December 31,			December 31,
		2013			2012
		(Millions)
	Commercial Paper
	Short-term borrowings, weighted-average interest rate of 1.14%	$	335		$	—
	Credit Agreement
	Revolving credit facility, weighted-average variable interest rate of 1.47%, as of December 31, 2012, due November 10, 2016 (a)	—			525
	Debt Securities
	Issued March 14, 2013, interest at 3.875% payable semi-annually, due March 15, 2023	500			—
	Issued November 27, 2012, interest at 2.50% payable semi-annually, due December 1, 2017	500			500
	Issued March 13, 2012, interest at 4.95% payable semi-annually, due April 1, 2022	350			350
	Issued September 30, 2010, interest at 3.25% payable semi-annually, due October 1, 2015	250			250
	Unamortized discount	(10		)	(5		)
	Total debt	1,925			1,620
	Short-term borrowings	(335		)	—
	Total long-term debt	$	1,590		$	1,620
	(a)	$150 million was swapped to a fixed rate obligation with fixed rates ranging from 2.94% to 2.99%, for a net effective rate of 2.25% on the $525 million of outstanding debt under our revolving credit facility as of December 31, 2012.
Future Maturities of Long-Term Debt	'
	The future maturities of long-term debt in the year indicated are as follows:
		Debt
		Maturities
		(Millions)
	2014	$	—
	2015	250
	2016	—
	2017	500
	2018	—
	Thereafter	850
		1,600
	Unamortized discount	(10		)
	Total	$	1,590

Risk_Management_and_Hedging_Ac1

Risk Management and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Summary of Gross and Net Amounts of Derivative Instruments	'
	The following summarizes the gross and net amounts of our derivative instruments:
		Gross Amounts				Amounts Not				Net				Gross Amounts				Amounts Not			Net
		of Assets and				Offset in the				Amount				of Assets and				Offset in the			Amount
		(Liabilities)				Balance Sheet -								(Liabilities)				Balance Sheet -
		Presented in the				Financial								Presented in the				Financial
		Balance Sheet				Instruments (a)								Balance Sheet				Instruments (a)
		31-Dec-13												31-Dec-12
	Assets:
	Commodity derivatives	$	166			$	(13	)		$	153			$	119			$	(10	)	$	109
	Interest rate derivatives	$	—			$	—			$	—			$	—			$	—		$	—
	Liabilities:
	Commodity derivatives	$	(27	)		$	13			$	(14	)		$	(33	)		$	10		$	(23	)
	Interest rate derivatives	$	(2	)		$	—			$	(2	)		$	(6	)		$	—		$	(6	)
	(a)	There is no cash collateral pledged or received against these positions.
Schedule of Designated and Non-Designated Derivative Instruments in Statement of Financial Position, Fair Value	'
	The fair value of our derivative instruments that are designated as hedging instruments and those that are marked-to-market each period, as well as the location of each within our consolidated balance sheets, by major category, is summarized as follows:
	Balance Sheet Line Item	December 31,				December 31,				Balance Sheet Line Item		December 31,				December 31,
		2013				2012						2013				2012
		(Millions)										(Millions)
	Derivative Assets Designated as Hedging Instruments:									Derivative Liabilities Designated as Hedging Instruments:
	Commodity derivatives:									Commodity derivatives:
	Unrealized gains on derivative instruments — current	$	—			$	—			Unrealized losses on derivative instruments — current		$	—			$	(3	)
	Unrealized gains on derivative instruments — long-term	—				—				Unrealized losses on derivative instruments — long-term		—				—
		$	—			$	—					$	—			$	(3	)
	Interest rate derivatives:									Interest rate derivatives:
	Unrealized gains on derivative instruments — current	$	—			$	—			Unrealized losses on derivative instruments — current		$	—			$	(4	)
	Unrealized gains on derivative instruments — long-term	—				—				Unrealized losses on derivative instruments — long-term		—				(2		)
		$	—			$	—					$	—			$	(6	)
	Derivative Assets Not Designated as Hedging Instruments:									Derivative Liabilities Not Designated as Hedging Instruments:
	Commodity derivatives:									Commodity derivatives:
	Unrealized gains on derivative instruments — current	$	79			$	49			Unrealized losses on derivative instruments — current		$	(26	)		$	(24	)
	Unrealized gains on derivative instruments — long-term	87				70				Unrealized losses on derivative instruments — long-term		(1		)		(6		)
		$	166			$	119					$	(27	)		$	(30	)
	Interest rate derivatives:									Interest rate derivatives:
	Unrealized gains on derivative instruments — current	$	—			$	—			Unrealized losses on derivative instruments — current		$	(2	)		$	—
	Unrealized gains on derivative instruments — long-term	—				—				Unrealized losses on derivative instruments — long-term		—				—
		$	—			$	—					$	(2	)		$	—
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss)	'
	The following summarizes the balance and activity within AOCI relative to our interest rate, commodity and foreign currency cash flow hedges as of and for the year ended December 31, 2013:
		Interest						Commodity				Foreign				Total
		Rate Cash						Cash Flow				Currency
		Flow						Hedges				Cash Flow
		Hedges										Hedges (a)
		(Millions)
	Net deferred (losses) gains in AOCI (beginning balance)	$	(10	)				$	(6	)		$	1			$	(15	)
	Losses reclassified from AOCI to earnings — effective portion	4				(b)		—				—				4
	Net deferred (losses) gains in AOCI (ending balance)	$	(6	)				$	(6	)		$	1			$	(11	)
	Deferred losses in AOCI expected to be reclassified into earnings over the next 12 months	$	(2	)				$	—			$	—			$	(2	)
	(a)	Relates to Discovery, our unconsolidated affiliate.
	(b)	Included in interest expense in our consolidated statements of operations.
Schedule of Derivatives Accounted for as Cash Flow Hedges	'
	The following table summarizes the impact on our consolidated balance sheet and consolidated statements of operations of our derivative instruments that are accounted for using the cash flow hedge method of accounting for the year ended December 31, 2012:
		(Losses) gains				Losses						Losses Recognized
		Recognized in				Reclassified						in Income on
		AOCI on				From AOCI to						Derivatives —
		Derivatives —				Earnings —						Ineffective Portion
		Effective Portion				Effective						and Amount
						Portion						Excluded From
												Effectiveness
												Testing
		(Millions)
	Interest rate derivatives	$	(1	)		$	(10	)		(a)		$	(2	)		(a) (b)
	Commodity derivatives	$	(1	)		$	—					$	—
	Foreign currency derivatives (c)	$	1			$	—					$	—
	(a)	Included in interest expense in our consolidated statements of operations.
	(b)	For the year ended December 31, 2012, less than $1 million of derivative losses were reclassified from AOCI to current period earnings as a result of the discontinuance of cash flow hedges related to certain forecasted transactions that are not probable of occurring.
	(c)	Relates to Discovery, our unconsolidated affiliate.
Schedule of Changes in Derivative Instruments Not Designated as Hedging Instruments	'
	The following summarizes these amounts and the location within the consolidated statements of operations that such amounts are reflected:
	Commodity Derivatives: Statements of Operations Line Item		Year Ended December 31,
			2013				2012				2011
		(Millions)
	Third party:
	Realized (losses) gains		$	(19	)		$	4			$	(36	)
	Unrealized gains		14				13				43
	(Losses) gains from commodity derivative activity, net		$	(5	)		$	17			$	7
	Affiliates:
	Realized gains		$	73			$	45			$	2
	Unrealized (losses) gains		(51		)		8				(1		)
	Gains from commodity derivative activity, net —affiliates		$	22			$	53			$	1
	Interest Rate Derivatives: Statements of Operations Line Item		Year Ended December 31,
			2013				2012				2011
		(Millions)
	Third party:
	Realized losses		$	(2	)		$	(7	)		$	(4	)
	Unrealized gains		2				7				5
	Interest expense		$	—			$	—			$	1
Schedule of Net Long or Short Positions Expected to be Realized	'
	The following tables represent, by commodity type, our net long or short positions that are expected to partially or entirely settle in each respective year. To the extent that we have long dated derivative positions that span multiple calendar years, the contract will appear in more than one line item in the tables below.
		31-Dec-13
		Crude Oil			Natural Gas			Natural Gas			Natural Gas
								Liquids			Basis Swaps
	Year of Expiration	Net (Short)			Net			Net			Net Long
		Position			(Short)			(Short)			Position
		(Bbls)			Position			Position			(MMbtu)
					(MMBtu)			(Bbls)
	2014	(690,945	)		(21,673,620	)		(5,171,910	)		21,415,000
	2015	(745,695	)		(9,458,975	)		(5,691,570	)		1,875,000
	2016	(561,922	)		(1,838,564	)		(813,267	)		—
		31-Dec-12
		Crude Oil			Natural Gas			Natural Gas			Natural Gas
								Liquids			Basis Swaps
	Year of Expiration	Net (Short)			Net (Short)			Net (Short)			Net Long
		Position			Position			Position			(Short)
		(Bbls)			(MMBtu)			(Bbls)			Position
											(Mmbtu)
	2013	(943,379	)		(8,887,980	)		(2,593,955	)		9,690,000
	2014	(584,365	)		(4,712,880	)		(2,584,930	)		(1,350,000	)
	2015	(401,865	)		(5,127,155	)		(2,491,250	)		—
	2016	(183,000	)		—			—			—

Partnership_Equity_and_Distrib1

Partnership Equity and Distributions (Tables)	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Cash Distribution	'
	The following table presents our cash distributions paid in 2013, 2012 and 2011:
	Payment Date	Per Unit		Total Cash
		Distribution		Distribution
				(Millions)
	November 14, 2013	$	0.72	$	82
	August 14, 2013	$	0.71	$	72
	May 15, 2013	$	0.7	$	69
	February 14, 2013	$	0.69	$	54
	November 14, 2012	$	0.68	$	53
	August 14, 2012	$	0.67	$	49
	May 15, 2012	$	0.66	$	43
	February 14, 2012	$	0.65	$	37
	November 14, 2011	$	0.64	$	35
	August 12, 2011	$	0.6325	$	34
	May 13, 2011	$	0.625	$	33
	February 14, 2011	$	0.6175	$	30

EquityBased_Compensation_Table

Equity-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Total Compensation Cost for Equity-Based Arrangements	'
	Total compensation cost for equity-based arrangements was as follows:
		Year Ended December 31,
		2013			2012			2011
		(Millions)
	Performance Phantom Units	$	1		$	1		$	5
	Phantom Units	—			—			—
	Restricted Phantom Units	1			1			2
	Total compensation cost	$	2		$	2		$	7
Performance Phantom Units [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Disclosure of Share-Based Compensation Arrangements by Share-Based Payment Award	'
	The following table presents information related to the PPUs:
		Units		Grant Date			Measurement
				Weighted-			Date Price
				Average Price			per Unit
				per Unit
	Outstanding at January 1, 2011	67,350		$	15.42
	Granted	10,580		$	41.8
	Vested	(50,720	)	$	10.05
	Forfeited	—		$	—
	Outstanding at December 31, 2011	27,210		$	35.69
	Granted (a)	11,740		$	39.31
	Vested	(20,100	)	$	34.57
	Forfeited	(7,760	)	$	38.97
	Outstanding at December 31, 2012	11,090		$	39.24
	Granted	11,450		$	40.88
	Vested (b)	(3,800	)	$	40.75
	Forfeited	(4,990	)	$	38.77
	Outstanding at December 31, 2013	13,750		$	40.36		$	50.33
	Expected to vest (c)	12,960		$	40.38		$	50.33
	(a)	Includes the impact of conversion of the underlying securities, in connection with Phillip 66's separation from ConocoPhillips, granted under the 2012 LTIP.
	(b)	The units vested at 150%.
	(c)	Based on our December 31, 2013 estimated achievement of specified performance targets, the performance estimate for units granted in both 2013 and 2012 is 100%. The estimated forfeiture rate for units granted in both 2013 and 2012 is 10%.
Fair Value of Units Vested and the Unit-Based Liabilities Paid for Unit Based Awards	'
	The following table presents the fair value of units vested and the unit-based liabilities paid related to PPUs, including the related DERs:
		Year Ended December 31,
		2013			2012			2011
		(Millions)
	Fair value of units vested	less than $1			$	1		$	5
	Unit-based liabilities paid	$	1		$	5		$	—
Phantom Units [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Disclosure of Share-Based Compensation Arrangements by Share-Based Payment Award	'
	The following table presents information related to the Phantom Units:
		Units		Grant Date			Measurement
				Weighted-			Date Price
				Average Price			per Unit
				per Unit
	Outstanding at January 1, 2011	—		$	—
	Granted	4,000		$	41.8
	Vested	(4,000	)	$	41.8
	Outstanding at December 31, 2011	—		$	—
	Granted	4,000		$	48.03
	Vested	(4,000	)	$	48.03
	Outstanding at December 31, 2012	—		$	—
	Granted	4,400		$	46.39
	Vested	(4,400	)	$	46.39
	Outstanding at December 31, 2013	—		$	—		$	—
Restricted Phantom Units [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Disclosure of Share-Based Compensation Arrangements by Share-Based Payment Award	'
	The following table presents information related to the RPUs:
		Units		Grant Date			Measurement
				Weighted-			Date Price
				Average Price			per Unit
				per Unit
	Outstanding at January 1, 2011	67,350		$	15.42
	Granted	10,580		$	41.8
	Vested	(58,600	)	$	12.97
	Forfeited	—		$	—
	Outstanding at December 31, 2011	19,330		$	37.27
	Granted (a)	11,740		$	39.31
	Vested	(19,060	)	$	37.31
	Forfeited	(7,760	)	$	43.27
	Outstanding at December 31, 2012	4,250		$	39.63
	Granted	11,590		$	41.94
	Vested	(1,950	)	$	41.8
	Forfeited	—		$	—
	Outstanding at December 31, 2013	13,890		$	41.25		$	50.33
	Expected to vest	13,351		$	41.38		$	50.3
	(a)	Includes the impact of conversion of the underlying securities, in connection with Phillip 66's separation from ConocoPhillips, granted under the 2012 LTIP.
Fair Value of Units Vested and the Unit-Based Liabilities Paid for Unit Based Awards	'
	The following table presents the fair value of units vested and the unit-based liabilities paid for unit based awards related to Restricted Phantom Units:
		Year Ended December 31,
		2013			2012			2011
		(Millions)
	Fair value of units vested	less than $1			$	1		$	3
	Unit-based liabilities paid	$	1		$	2		$	1

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Components of Income Tax Benefit (Expense)	'
	Income tax expense consists of the following:
		Year Ended December 31,
		2013			2012			2011
		(Millions)
	Current:
	Federal income tax expense	$	—		$	—		$	(29	)
	State income tax expense	(3		)	(1		)	(2		)
	Deferred:
	Federal income tax benefit	—			—			29
	State income tax (expense) benefit	(5		)	—			1
	Total income tax expense	$	(8	)	$	(1	)	$	(1	)

Commitments_and_Contingent_Lia1

Commitments and Contingent Liabilities Commitments and Contingent Liabilities (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	'
	Minimum rental payments under our various operating leases in the year indicated are as follows at December 31, 2013:
		(Millions)
	2014	$	16
	2015	14
	2016	12
	2017	10
	2018	9
	Thereafter	33
	Total minimum rental payments	$	94

Business_Segments_Tables

Business Segments (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segment Information	'
	The following tables set forth our segment information:
	Year Ended December 31, 2013:
		Natural Gas			NGL			Wholesale			Other			Total
		Services (d)			Logistics			Propane
								Logistics
		(Millions)
	Total operating revenue	$	2,598		$	73		$	380		$	—		$	3,051
	Gross margin (a)	$	501		$	72		$	52		—			$	625
	Operating and maintenance expense	(184		)	(16		)	(15		)	—			(215		)
	Depreciation and amortization expense	(87		)	(6		)	(2		)	—			(95		)
	General and administrative expense	—			—			—			(63		)	(63		)
	Other expense	(1		)	(3		)	(4		)	—			(8		)
	Earnings from unconsolidated affiliates	1			32			—			—			33
	Interest expense	—			—			—			(52		)	(52		)
	Income tax expense (b)	—			—			—			(8		)	(8		)
	Net income (loss)	$	230		$	79		$	31		$	(123	)	$	217
	Net income attributable to noncontrolling interests	(17		)	—			—			—			(17		)
	Net income (loss) attributable to partners	$	213		$	79		$	31		$	(123	)	$	200
	Non-cash derivative mark-to-market (c)	$	(36	)	$	—		$	(1	)	$	1		$	(36	)
	Non-cash lower of cost or market adjustments	$	2		$	—		$	2					$	4
	Capital expenditures	$	334		$	24		$	5		$	—		$	363
	Acquisition expenditures	$	696		$	86		$	—		$	—		$	782
	Investments in unconsolidated affiliates	$	133		$	109		$	—		$	—		$	242
	Year Ended December 31, 2012:
		Natural Gas			NGL			Wholesale			Other			Total
		Services (d)			Logistics			Propane
								Logistics
		(Millions)
	Total operating revenue	$	2,345		$	64		$	415		$	—		$	2,824
	Gross margin (a)	$	503		$	64		$	42		$	—		$	609
	Operating and maintenance expense	(166		)	(16		)	(15		)	—			(197		)
	Depreciation and amortization expense	(83		)	(6		)	(2		)	—			(91		)
	General and administrative expense	—			—			—			(75		)	(75		)
	Earnings from unconsolidated affiliates	15			11			—			—			26
	Interest expense	—			—			—			(42		)	(42		)
	Income tax expense (b)	—			—			—			(1		)	(1		)
	Net income (loss)	$	269		$	53		$	25		$	(118	)	$	229
	Net income attributable to noncontrolling interests	(13		)	—			—			—			(13		)
	Net income (loss) attributable to partners	$	256		$	53		$	25		$	(118	)	$	216
	Non-cash derivative mark-to-market (c)	$	20		$	—		$	1		$	—		$	21
	Capital expenditures	$	468		$	12		$	4		$	—		$	484
	Acquisitions net of cash acquired	$	715		$	30		$	—		$	—		$	745
	Investments in unconsolidated affiliates	$	115		$	43		$	—		$	—		$	158
	Year Ended December 31, 2011:
		Natural Gas			NGL			Wholesale			Other			Eliminations (f)			Total
		Services (d)			Logistics			Propane
								Logistics
		(Millions)
	Total operating revenue	$	3,102		$	57		$	633		$	—		$	(2	)	$	3,790
	Gross margin (a)	$	532		$	52		$	51		$	—		$	—		$	635
	Operating and maintenance expense	(161		)	(16		)	(15		)	—			—			(192		)
	Depreciation and amortization expense	(124		)	(8		)	(3		)	—			—			(135		)
	General and administrative expense	—			—			—			(76		)	—			(76		)
	Earnings from unconsolidated affiliates	23			—			—			—			—			23
	Other operating income	—			1			—			—			—			1
	Interest expense	—			—			—			(34		)	—			(34		)
	Income tax expense (b)	—			—			—			(1		)	—			(1		)
	Net income (loss)	270			29			33			(111		)	—			221
	Net income attributable to noncontrolling interests	(30		)	—			—			—			—			(30		)
	Net income (loss) attributable to partners	$	240		$	29		$	33		$	(111	)	$	—		$	191
	Non-cash derivative mark-to-market (c)	$	42		$	—		$	—		$	(2	)	$	—		$	40
	Capital expenditures	$	372		$	9		$	4		$	—		$	—		$	385
	Acquisitions net of cash acquired	$	122		$	30		$	—		$	—		$	—		$	152
Investments in unconsolidated affiliates	$	8		$	—		$	—		$	—		$	—		$	8
	December 31,
	2013			2012			2011
	(Millions)
Segment long-term assets:
Natural Gas Services (d)	$	3,303		$	2,748		$	2,214
NGL Logistics	555			340			250
Wholesale Propane Logistics	106			105			104
Other (e)	100			84			14
Total long-term assets	4,064			3,277			2,582
Current assets (d)	503			368			373
Total assets	$	4,567		$	3,645		$	2,955
(a)	Gross margin consists of total operating revenues, including commodity derivative activity, less purchases of natural gas, propane and NGLs. Gross margin is viewed as a non-GAAP measure under the rules of the SEC, but is included as a supplemental disclosure because it is a primary performance measure used by management as it represents the results of product sales versus product purchases. As an indicator of our operating performance, gross margin should not be considered an alternative to, or more meaningful than, net income or cash flow as determined in accordance with GAAP. Our gross margin may not be comparable to a similarly titled measure of another company because other entities may not calculate gross margin in the same manner.
(b)	For the year ended December 31, 2011, income tax expense relates primarily to the Texas margin tax and the Michigan business tax. The Michigan business tax was repealed in 2012; accordingly, income tax expense for the years ended December 31, 2013 and 2012 relates primarily to the Texas margin tax.
(c)	Non-cash commodity derivative mark-to-market is included in segment gross margin, along with cash settlements for our commodity derivative contracts.
(d)	The segment information as of and for the years ended December 31, 2013, 2012 and 2011, includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas. Transfers of net assets between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information, similar to the pooling method.
(e)	Other long-term assets not allocable to segments consist of unrealized gains on derivative instruments, corporate leasehold improvements and other long-term assets.
(f)	Represents intersegment revenues consisting of sales of NGLs by Marysville in our NGL Logistics segment to our Wholesale Propane Logistics segment.

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2013
Supplemental Cash Flow Elements [Abstract]	'
Summary of Supplemental Cash Flow Information	'
		Year Ended December 31,
		2013		2012			2011
		(Millions)
	Cash paid for interest and income taxes:
	Cash paid for interest, net of amounts capitalized	$	40	$	23		$	17
	Cash paid for income taxes, net of income tax refunds	$	1	$	1		$	30
	Non-cash investing and financing activities:
	Property, plant and equipment acquired with accounts payable	$	27	$	47		$	34
	Other non-cash additions of property, plant and equipment	$	1	$	8		$	3
	Non-cash change in parent advances	$	—	$	(115	)	$	5
	Accounts payable related to equity issuance costs	$	1	$	—		$	—

Quarterly_Financial_Data_Unaud1

Quarterly Financial Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule of Quarterly Consolidated Results of Operations	'
	Our consolidated results of operations by quarter for the years ended December 31, 2013 and 2012 were as follows (millions, except per unit amounts):
	2013	First (a)			Second (a)			Third (a)			Fourth (a)			Year Ended December 31, 2013 (a)
	Total operating revenues	$	749		$	792		$	689		821			3,051
	Operating income	$	65		$	117		$	14		48			244
	Net income	$	60		$	111		$	6		40			217
	Net income attributable to noncontrolling interests	$	(3	)	$	(4	)	$	(3	)	(7	)		(17	)
	Net income (loss) attributable to partners	$	57		$	107		$	3		33			200
	Net income (loss) allocable to limited partners	$	31		$	86		$	(20	)	8			105
	Basic and diluted net income (loss) per limited partner unit	$	0.48		$	1.11		$	(0.24	)	0.09			1.34
	(a)Our consolidated results of operations have been adjusted to retrospectively include the historical results of the Lucerne 1 plant for all periods presented.
	2012	First (a)			Second (a)			Third (a)			Fourth (a)				Year Ended December 31, 2012 (a)
	Total operating revenues	$	855		$	680		$	618		$	671			$	2,824
	Operating income	$	52		$	99		$	13		$	82			$	246
	Net income	$	44		$	90		$	14		$	81			$	229
	Net income attributable to noncontrolling interests	$	(4	)	$	(2	)	$	(2	)	$	(5	)		$	(13	)
	Net income attributable to partners	$	40		$	88		$	12		$	76			$	216
	Net income (loss) allocable to limited partners	$	12		$	69		$	(9	)	$	52			$	124
	Basic and diluted net income (loss) per limited partner unit	$	0.26		$	1.33		$	(0.16	)	$	0.87			$	2.28

Supplementary_Information_Cond1

Supplementary Information - Condensed Consolidating Financial Information (Tables)	3 Months Ended																		12 Months Ended
	Mar. 31, 2014																		Dec. 31, 2013
Condensed Financial Information Disclosure [Abstract]	'																		'
Condensed Consolidating Balance Sheets	'																		'
																				Condensed Consolidating Balance Sheet
																				December 31, 2013 (a)
																				Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																				Guarantor			Issuer			Subsidiaries				Adjustments
																				(Millions)
																			ASSETS
																			Current assets:
																			Cash and cash equivalents	$	—		$	—		$	12			$	—			$	12
																			Accounts receivable, net	—			—			342				—				342
																			Inventories	—			—			67				—				67
																			Other	—			—			82				—				82
																			Total current assets	—			—			503				—				503
																			Property, plant and equipment, net	—			—			3,046				—				3,046
																			Goodwill and intangible assets, net	—			—			283				—				283
																			Advances receivable — consolidated subsidiaries	1,805			1,683			—				(3,488		)		—
																			Investments in consolidated subsidiaries	181			426			—				(607		)		—
																			Investments in unconsolidated affiliates	—			—			627				—				627
																			Other long-term assets	—			12			96				—				108
																			Total assets	$	1,986		$	2,121		$	4,555			$	(4,095	)		$	4,567
																			LIABILITIES AND EQUITY
																			Accounts payable and other current liabilities	$	1		$	350		$	372			$	—			$	723
																			Advances payable — consolidated subsidiaries	—			—			3,488				(3,488		)		—
																			Long-term debt	—			1,590			—				—				1,590
																			Other long-term liabilities	—			—			41				—				41
																			Total liabilities	1			1,940			3,901				(3,488		)		2,354
																			Commitments and contingent liabilities
																			Equity:
																			Partners’ equity:
																			Predecessor equity	—			—			40				—				40
																			Net equity	1,985			187			391				(607		)		1,956
																			Accumulated other comprehensive loss	—			(6		)	(5		)		—				(11		)
																			Total partners’ equity	1,985			181			426				(607		)		1,985
																			Noncontrolling interests	—			—			228				—				228
																			Total equity	1,985			181			654				(607		)		2,213
																			Total liabilities and equity	$	1,986		$	2,121		$	4,555			$	(4,095	)		$	4,567
																			(a)	The financial information as of December 31, 2013 includes the results of our Lucerne 1 plant and an 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																				Condensed Consolidating Balance Sheet
																				December 31, 2012 (a)
																				Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																				Guarantor			Issuer			Subsidiaries				Adjustments
																				(Millions)
																			ASSETS
																			Current assets:
																			Cash and cash equivalents	$	—		$	3		$	2			$	(3	)		$	2
																			Accounts receivable, net	—			—			239				—				239
																			Inventories	—			—			76				—				76
																			Other	—			—			51				—				51
																			Total current assets	—			3			368				(3		)		368
																			Property, plant and equipment, net	—			—			2,592				—				2,592
																			Goodwill and intangible assets, net	—			—			291				—				291
																			Advances receivable — consolidated subsidiaries	873			1,424			—				(2,297		)		—
																			Investments in consolidated subsidiaries	574			770			—				(1,344		)		—
																			Investments in unconsolidated affiliates	—			—			304				—				304
																			Other long-term assets	—			11			79				—				90
																			Total assets	$	1,447		$	2,208		$	3,634			$	(3,644	)		$	3,645
																			LIABILITIES AND EQUITY
																			Accounts payable and other current liabilities	$	—		$	12		$	336			$	(3	)		$	345
																			Advances payable — consolidated subsidiaries	—			—			2,297				(2,297		)		—
																			Long-term debt	—			1,620			—				—				1,620
																			Other long-term liabilities	—			2			42				—				44
																			Total liabilities	—			1,634			2,675				(2,300		)		2,009
																			Commitments and contingent liabilities
																			Equity:
Partners’ equity:
Predecessor equity	—			—			399				—				399
Net equity	1,447			584			376				(1,344		)		1,063
Accumulated other comprehensive loss	—			(10		)	(5		)		—				(15		)
Total partners’ equity	1,447			574			770				(1,344		)		1,447
Noncontrolling interests	—			—			189				—				189
Total equity	1,447			574			959				(1,344		)		1,636
Total liabilities and equity	$	1,447		$	2,208		$	3,634			$	(3,644	)		$	3,645
(a)	The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
Condensed Consolidating Statements of Operations	'																		'
																				Condensed Consolidating Statement of Operations
																				Year Ended December 31, 2013 (a)
																				Parent			Subsidiary			Non-				Consolidating				Consolidated
																				Guarantor			Issuer			Guarantor				Adjustments
																										Subsidiaries
																				(Millions)
																			Operating revenues:
																			Sales of natural gas, propane, NGLs and condensate	$	—		$	—		$	2,763			$	—			$	2,763
																			Transportation, processing and other	—			—			271				—				271
																			Gains from commodity derivative activity, net	—			—			17				—				17
																			Total operating revenues	—			—			3,051				—				3,051
																			Operating costs and expenses:
																			Purchases of natural gas, propane and NGLs	—			—			2,426				—				2,426
																			Operating and maintenance expense	—			—			215				—				215
																			Depreciation and amortization expense	—			—			95				—				95
																			General and administrative expense	—			—			63				—				63
																			Other expense	—			—			8				—				8
																			Total operating costs and expenses	—			—			2,807				—				2,807
																			Operating income	—			—			244				—				244
																			Interest expense, net	—			(52		)	—				—				(52		)
																			Income from consolidated subsidiaries	200			252			—				(452		)		—
																			Earnings from unconsolidated affiliates	—			—			33				—				33
																			Income before income taxes	200			200			277				(452		)		225
																			Income tax expense	—			—			(8		)		—				(8		)
																			Net income	200			200			269				(452		)		217
																			Net income attributable to noncontrolling interests	—			—			(17		)		—				(17		)
																			Net income attributable to partners	$	200		$	200		$	252			$	(452	)		$	200
																			(a)	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																				Condensed Consolidating Statement of Operations
																				Year Ended December 31, 2011 (a)
																				Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																				Guarantor			Issuer			Subsidiaries				Adjustments
																				(Millions)
																			Operating revenues:
																			Sales of natural gas, propane, NGLs and condensate	$	—		$	—		$	3,574			$	—			$	3,574
																			Transportation, processing and other	—			—			208				—				208
																			Gains from commodity derivative activity, net	—			—			8				—				8
																			Total operating revenues	—			—			3,790				—				3,790
																			Operating costs and expenses:
																			Purchases of natural gas, propane and NGLs	—			—			3,155				—				3,155
																			Operating and maintenance expense	—			—			192				—				192
																			Depreciation and amortization expense	—			—			135				—				135
																			General and administrative expense	—			—			76				—				76
																			Other income	—			—			(1		)		—				(1		)
																			Total operating costs and expenses	—			—			3,557				—				3,557
																			Operating income	—			—			233				—				233
																			Interest expense	—			(33		)	(1		)		—				(34		)
																			Earnings from unconsolidated affiliates	—			—			23				—				23
																			Income from consolidated subsidiaries	191			224			—				(415		)		—
																			Income before income taxes	191			191			255				(415		)		222
																			Income tax expense	—			—			(1		)		—				(1		)
																			Net income	191			191			254				(415		)		221
																			Net income attributable to noncontrolling interests	—			—			(30		)		—				(30		)
																			Net income attributable to partners	$	191		$	191		$	224			$	(415	)		$	191
																			(a)	The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																				Condensed Consolidating Statement of Operations
																				Year Ended December 31, 2012 (a)
																				Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																				Guarantor			Issuer			Subsidiaries				Adjustments
																				(Millions)
																			Operating revenues:
																			Sales of natural gas, propane, NGLs and condensate	$	—		$	—		$	2,520			$	—			$	2,520
																			Transportation, processing and other	—			—			234				—				234
Gains from commodity derivative activity, net	—			—			70				—				70
Total operating revenues	—			—			2,824				—				2,824
Operating costs and expenses:
Purchases of natural gas, propane and NGLs	—			—			2,215				—				2,215
Operating and maintenance expense	—			—			197				—				197
Depreciation and amortization expense	—			—			91				—				91
General and administrative expense	—			—			75				—				75
Total operating costs and expenses	—			—			2,578				—				2,578
Operating income	—			—			246				—				246
Interest expense, net	—			(41		)	(1		)		—				(42		)
Earnings from unconsolidated affiliates	—			—			26				—				26
Income from consolidated subsidiaries	216			257			—				(473		)		—
Income before income taxes	216			216			271				(473		)		230
Income tax expense	—			—			(1		)		—				(1		)
Net income	216			216			270				(473		)		229
Net income attributable to noncontrolling interests	—			—			(13		)		—				(13		)
Net income attributable to partners	$	216		$	216		$	257			$	(473	)		$	216
(a)	The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
Condensed Consolidating Statements of Comprehensive Income	'																		'
																				Condensed Consolidating Statement of Comprehensive Income
																				Year Ended December 31, 2013 (a)
																				Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																				Guarantor			Issuer			Subsidiaries				Adjustments
																				(Millions)
																			Net income	$	200		$	200		$	269			$	(452	)		$	217
																			Other comprehensive income:
																			Reclassification of cash flow hedge losses into earnings	—			4			—				—				4
																			Other comprehensive income from consolidated subsidiaries	4			—			—				(4		)		—
																			Total other comprehensive income	4			4			—				(4		)		4
																			Total comprehensive income	204			204			269				(456		)		221
																			Total comprehensive income attributable to noncontrolling interests	—			—			(17		)		—				(17		)
																			Total comprehensive income attributable to partners	$	204		$	204		$	252			$	(456	)		$	204
																			(a)	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																				Condensed Consolidating Statement of Comprehensive Income
																				Year Ended December 31, 2012 (a)
																				Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																				Guarantor			Issuer			Subsidiaries				Adjustments
																				(Millions)
																			Net income	$	216		$	216		$	270			$	(473	)		$	229
																			Other comprehensive loss:
																			Reclassification of cash flow hedge losses into earnings	—			10			—				—				10
																			Net unrealized losses on cash flow hedges	—			(1		)	—				—				(1		)
																			Other comprehensive income from consolidated subsidiaries	9			—			—				(9		)		—
																			Total other comprehensive income	9			9			—				(9		)		9
																			Total comprehensive income	225			225			270				(482		)		238
																			Total comprehensive income attributable to noncontrolling interests	—			—			(13		)		—				(13		)
																			Total comprehensive income attributable to partners	$	225		$	225		$	257			$	(482	)		$	225
																			(a)	The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																				Condensed Consolidating Statement of Comprehensive Income
																				Year Ended December 31, 2011 (a)
																				Parent			Subsidiary			Non-Guarantor					Consolidating				Consolidated
																				Guarantor			Issuer			Subsidiaries					Adjustments
																				(Millions)
																			Net income	$	191		$	191		$	254				$	(415	)		$	221
																			Other comprehensive loss:
																			Reclassification of cash flow hedge losses into earnings	—			21			—					—				21
																			Net unrealized losses on cash flow hedges	—			(12		)	(3		)			—				(15		)
																			Other comprehensive income from consolidated subsidiaries	6			(3		)	—					(3		)		—
																			Total other comprehensive income	6			6			(3		)	—		(3		)		6
																			Total comprehensive income	197			197			251					(418		)		227
																			Total comprehensive income attributable to noncontrolling interests	—			—			(30		)			—				(30		)
																			Total comprehensive income attributable to partners	$	197		$	197		$	221				$	(418	)		$	197
																			(a)	The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
Condensed Consolidating Statements of Cash Flows	'																		'
		Condensed Consolidating Statement of Cash Flows																		Condensed Consolidating Statement of Cash Flows
		Three Months Ended March 31, 2014 (a)																		Year Ended December 31, 2013 (a)
		Parent			Subsidiary			Non-Guarantor			Consolidating		Consolidated							Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
		Guarantor			Issuer			Subsidiaries			Adjustments									Guarantor			Issuer			Subsidiaries				Adjustments
		(Millions)																		(Millions)
	OPERATING ACTIVITIES																		OPERATING ACTIVITIES
	Net cash (used in) provided by operating activities	—			(11	)		157			—		146						Net cash (used in) provided by operating activities	$	—		$	(45	)	$	387			$	3			$	345
	INVESTING ACTIVITIES:																		INVESTING ACTIVITIES:
	Intercompany transfers	(591	)		(365	)		—			956		—						Intercompany transfers	(806		)	(258		)	—				1,064				—
	Capital expenditures	—			—			(63	)		—		(63	)					Capital expenditures	—			—			(363		)		—				(363		)
	Acquisitions, net of cash acquired	—			—			(100	)		—		(100	)					Acquisitions, net of cash acquired	—			—			(696		)		—				(696		)
	Acquisition of unconsolidated affiliates	—			—			(669	)		—		(669	)					Acquisition of unconsolidated affiliates	—			—			(86		)		—				(86		)
	Investments in unconsolidated affiliates	—			—			(65	)		—		(65	)					Investments in unconsolidated affiliates	—			—			(242		)		—				(242		)
	Other	—			—			1			—		1						Net cash (used in) provided by investing activities	(806		)	(258		)	(1,387		)		1,064				(1,387		)
	Net cash (used in) provided by investing activities	(591	)		(365	)		(896	)		956		(896	)					FINANCING ACTIVITIES:
																			Intercompany transfers	—			—			1,064				(1,064		)		—
	FINANCING ACTIVITIES:
	Intercompany transfers	—			—			956			(956	)	—						Proceeds from long-term debt	—			1,957			—				—				1,957
	Proceeds from long-term debt	—			719			—			—		719						Payments of long-term debt	—			(1,988		)	—				—				(1,988		)
	Payments of commercial paper, net	—			(314	)		—			—		(314	)					Proceeds from issuance of commercial paper	—			335			—				—				335
	Payments of deferred financing costs	—			(6	)		—			—		(6	)					Payments of deferred financing costs	—			(4		)	—				—				(4		)
	Excess purchase price over acquired interests and commodity hedges	—			—			(14	)		—		(14	)					Excess purchase price over acquired interests and commodity hedges	—			—			(85		)		—				(85		)
	Proceeds from issuance of common units, net of offering costs	677			—			—			—		677						Proceeds from issuance of common units, net of offering costs	1,083			—			—				—				1,083
	Net change in advances to predecessor from DCP Midstream, LLC	—			—			(6	)		—		(6	)					Net change in advances to predecessor from DCP Midstream, LLC	—			—			11				—				11
	Distributions to limited partners and general partner	(86	)		—			—			—		(86	)					Distributions to limited partners and general partner	(277		)	—			—				—				(277		)
	Distributions to noncontrolling interests	—			—			(10	)		—		(10	)					Distributions to noncontrolling interests	—			—			(24		)		—				(24		)
	Purchase of additional interest in a subsidiary	—			—			(198	)		—		(198	)					Contributions from noncontrolling interests	—			—			46				—				46
	Contributions from noncontrolling interests	—			—			3			—		3						Distributions to DCP Midstream, LLC	—			—			(3		)		—				(3		)
	Net cash provided by (used in) financing activities	591			399			731			(956	)	765						Contributions from DCP Midstream, LLC	—			—			1				—				1
	Net change in cash and cash equivalents	—			23			(8	)		—		15						Net cash provided by (used in) financing activities	806			300			1,010				(1,064		)		1,052
	Cash and cash equivalents, beginning of period	—			—			12			—		12						Net change in cash and cash equivalents	—			(3		)	10				3				10
	Cash and cash equivalents, end of period	—			23			4			—		27						Cash and cash equivalents, beginning of period	—			3			2				(3		)		2
																			Cash and cash equivalents, end of period	$	—		$	—		$	12			$	—			$	12
	(a)	The financial information for the three months ended March 31, 2014 includes the results of our Lucerne 1 plant, a transfer of net assets between entities under common control that was accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
																			(a)	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
		Condensed Consolidating Statements of Cash Flows
		Three Months Ended March 31, 2013 (a)
		Parent				Subsidiary				Non-Guarantor			Consolidating			Consolidated				Condensed Consolidating Statements of Cash Flows
		Guarantor				Issuer				Subsidiaries			Adjustments							Year Ended December 31, 2012 (a)
		(Millions)																		Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
	OPERATING ACTIVITIES																			Guarantor			Issuer			Subsidiaries				Adjustments
	Net cash (used in) provided by operating activities	$	—			$	(1	)		$	159		$	(6	)	$	152			(Millions)
																			OPERATING ACTIVITIES
	INVESTING ACTIVITIES:																		Net cash (used in) provided by operating activities	$	—		$	(39	)	$	142			$	(1	)		$	102
	Intercompany transfers	(440		)		(72		)		—			512			—
																			INVESTING ACTIVITIES:
	Capital expenditures	—				—				(101		)	—			(101		)	Intercompany transfers	(274		)	(827		)	—				1,101				—
	Acquisitions, net of cash acquired	—				—				(481		)	—			(481		)	Capital expenditures	—			—			(484		)		—				(484		)
	Investments in unconsolidated affiliates	—				—				(26		)	—			(26		)	Acquisitions, net of cash acquired	—			—			(745		)		—				(745		)
	Net cash (used in) provided by investing activities	(440		)		(72		)		(608		)	512			(608		)	Investments in unconsolidated affiliates	—			—			(158		)		—				(158		)
	FINANCING ACTIVITIES:																		Return of investment from unconsolidated affiliate	—			—			1				—				1
	Intercompany transfers	—				—				512			(512		)	—
																			Proceeds from sale of assets	—			—			2				—				2
	Proceeds from long-term debt	—				809				—			—			809
																			Net cash (used in) provided by investing activities	(274		)	(827		)	(1,384		)		1,101				(1,384		)
	Payments of long-term debt	—				(690		)		—			—			(690		)
																			FINANCING ACTIVITIES:
	Payment of deferred financing costs	—				(4		)		—			—			(4		)	Intercompany transfers	—			—			1,101				(1,101		)		—
	Proceeds from issuance of common units, net of offering costs	494				—				—			—			494			Proceeds from long-term debt	—			2,665			—				—				2,665
	Excess purchase price over acquired assets	—				—				(94		)	—			(94		)	Payments of long-term debt	—			(1,792		)	—				—				(1,792		)
	Net change in advances to predecessor from DCP Midstream, LLC	—				—				22			—			22			Payment of deferred financing costs	—			(8		)	—				—				(8		)
	Distributions to common unitholders and general partner	(54		)		—				—			—			(54		)	Proceeds from issuance of common units, net of offering costs	455			—			—				—				455
	Distributions to noncontrolling interests	—				—				(5		)	—			(5		)	Excess purchase price over acquired assets	—			—			(225		)		—				(225		)
Contributions from noncontrolling interests	—				—				15			—			15			Net change in advances to predecessor from DCP Midstream, LLC	—			—			336				—				336
Distributions to DCP Midstream, LLC	—				—				(3		)	—			(3		)	Distributions to common unitholders and general partner	(181		)	—			—				—				(181		)
Contributions from DCP Midstream, LLC	—				—				1			—			1			Distributions to noncontrolling interests	—			—			(9		)		—				(9		)
Net cash provided by (used in) financing activities	440				115				448			(512		)	491			Contributions from noncontrolling interests	—			—			25				—				25
Net change in cash and cash equivalents	—				42				(1		)	(6		)	35			Contributions from DCP Midstream, LLC	—			—			10				—				10
Cash and cash equivalents, beginning of period	—				3				2			(3		)	2			Net cash provided by (used in) financing activities	274			865			1,238				(1,101		)		1,276
Cash and cash equivalents, end of period	$	—			$	45			$	1		$	(9	)	$	37		Net change in cash and cash equivalents	—			(1		)	(4		)		(1		)		(6		)
																		Cash and cash equivalents, beginning of year	—			4			6				(2		)		8
(a)	The financial information during the three months ended March 31, 2013 includes the results of our Lucerne 1 plant and an 80% interest in the Eagle Ford system. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.																	Cash and cash equivalents, end of year	$	—		$	3		$	2			$	(3	)		$	2
The parent guarantor, subsidiary issuer and non-guarantor subsidiaries participate in a cash pooling program, whereby cash balances are generally swept daily between the parent guarantor and the non-guarantor subsidiaries bank accounts and those of the subsidiary issuer.
The changes to the previously reported amounts are summarized as follows:																		(a)	The financial information during the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
	Parent				Subsidiary				Non-Guarantor			Consolidating			Consolidated				Condensed Consolidating Statements of Cash Flows
	Guarantor				Issuer				Subsidiaries			Adjustments							Year Ended December 31, 2011 (a)
	(Millions)																		Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
Three Months Ended March 31, 2014																			Guarantor			Issuer			Subsidiaries				Adjustments
Net cash (used in) provided by operating activities	$	591			$	365			$	(956	)	$	—		$	—			(Millions)
																		OPERATING ACTIVITIES
Net cash (used in) provided by investing activities	$	(591	)		$	(365	)		$	—		$	956		$	—		Net cash (used in) provided by operating activities	$	—		$	(31	)	$	448			$	—			$	417
Net cash provided by (used in) financing activities	$	—			$	—			$	956		$	(956	)	$	—		INVESTING ACTIVITIES:
																		Intercompany transfers	(38		)	(62		)	—				100				—
Three Months Ended March 31, 2013
Net cash (used in) provided by operating activities	$	440			$	72			$	(512	)	$	—		$	—		Capital expenditures	—			—			(385		)		—				(385		)
Net cash (used in) provided by investing activities	$	(440	)		$	(72	)		$	—		$	512		$	—		Acquisitions, net of cash acquired	—			—			(152		)		—				(152		)
Net cash provided by (used in) financing activities	$	—			$	—			$	512		$	(512	)	$	—		Investments in unconsolidated affiliates	—			—			(8		)		—				(8		)
																		Return of investment from unconsolidated affiliate	—			—			2				—				2
																		Proceeds from sale of assets	—			—			5				—				5
																		Net cash (used in) provided by investing activities	(38		)	(62		)	(538		)		100				(538		)
																		FINANCING ACTIVITIES:
																		Intercompany transfers	—			—			100				(100		)		—
																		Proceeds from debt	—			1,524			—				—				1,524
																		Payments of debt	—			(1,425		)	—				—				(1,425		)
																		Payment of deferred financing costs	—			(4		)	—				—				(4		)
																		Proceeds from issuance of common units, net of offering costs	170			—			—				—				170
																		Excess purchase price over acquired unconsolidated affiliates	—			—			(36		)		—				(36		)
																		Net change in advances to predecessor from DCP Midstream, LLC	—			—			52				—				52
																		Distributions to common unitholders and general partner	(132		)	—			—				—				(132		)
																		Distributions to noncontrolling interests	—			—			(45		)		—				(45		)
																		Contributions from noncontrolling interests	—			—			18				—				18
																		Net cash provided by (used in) financing activities	38			95			89				(100		)		122
																		Net change in cash and cash equivalents	—			2			(1		)		—				1
																		Cash and cash equivalents, beginning of year	—			2			7				(2		)		7
																		Cash and cash equivalents, end of year	$	—		$	4		$	6			$	(2	)		$	8
																		(a)	The financial information as of December 31, 2011, includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfers occurred at the beginning of the period, and prior years were retrospectively adjusted to furnish comparative information similar to the pooling method.
																		The parent guarantor, subsidiary issuer and non-guarantor subsidiaries participate in a cash pooling program, whereby cash balances are generally swept daily between the parent guarantor and the non-guarantor subsidiaries bank accounts and those of the subsidiary issuer.
																		Subsequent to the issuance of the 2013 financial statements, management determined that intercompany transfers between the parent guarantor and the non-guarantor subsidiaries, as well as the subsidiary issuer and the non-guarantor subsidiaries, should be classified as investing activities by the parent guarantor and subsidiary issuer and financing activities by the non-guarantor subsidiaries, within the condensed consolidating statements of cash flows. The intercompany transfers had previously been reported as operating activities by the parent guarantor, subsidiary issuer and non-guarantor subsidiaries. The classification of these intercompany transfers has been corrected in the condensed consolidating financial statements for the years ended December 31, 2013, 2012 and 2011. This correction has no impact on the consolidated statement of cash flows for all years presented. These amounts have been included within the line item “intercompany transfers” in investing and financing activities within the condensed consolidating statements of cash flows. The changes to the previously reported amounts are summarized as follows:
																			Parent			Subsidiary			Non-Guarantor				Consolidating				Consolidated
																			Guarantor			Issuer			Subsidiaries				Adjustments
																			(Millions)
																		Year Ended December 31, 2013
																		Net cash (used in) provided by operating activities	$	806		$	258		$	(1,064	)		$	—			$	—
																		Net cash (used in) provided by investing activities	$	(806	)	$	(258	)	$	—			$	1,064			$	—
																		Net cash provided by (used in) financing activities	$	—		$	—		$	1,064			$	(1,064	)		$	—
																		Year Ended December 31, 2012
																		Net cash (used in) provided by operating activities	$	274		$	827		$	(1,101	)		$	—			$	—
																		Net cash (used in) provided by investing activities	$	(274	)	$	(827	)	$	—			$	1,101			$	—
																		Net cash provided by (used in) financing activities	$	—		$	—		$	1,101			$	(1,101	)		$	—
																		Year Ended December 31, 2011
																		Net cash (used in) provided by operating activities	$	38		$	62		$	(100	)		$	—			$	—
																		Net cash (used in) provided by investing activities	$	(38	)	$	(62	)	$	—			$	100			$	—
																		Net cash provided by (used in) financing activities	$	—		$	—		$	100			$	(100	)		$	—

Valuation_and_Qualifying_Accou1

Valuation and Qualifying Accounts and Reserves (Tables)	12 Months Ended
	Dec. 31, 2013
Valuation and Qualifying Accounts [Abstract]	'
Schedule of Valuation and Qualifying Accounts Reserves	'
	Our valuation and qualifying accounts and reserves for the years ended December 31, 2013, 2012, and 2011 are as follows:
		Balance at Beginning of Period		Charged to Consolidated Statements of operations		Charged to		Deductions/Other			Balance at End of Period
						Other Accounts
		(Millions)
	December 31, 2013
	Environmental	$	2	$	1	$	—	$	(1	)	$	2
	Other (a)	1		—		—		—			1
		$	3	$	1	$	—	$	(1	)	$	3
	December 31, 2012
	Environmental	$	3	$	—	$	—	$	(1	)	$	2
	Other (a)	1		—		—		—			1
		$	4	$	—	$	—	$	(1	)	$	3
	December 31, 2011
	Environmental	$	3	$	—	$	—	$	—		$	3
	Litigation	1		—		—		(1		)	—
	Other (a)	—		1		—		—			1
		$	4	$	1	$	—	$	(1	)	$	4
	(a)	Principally consists of allowance for doubtful accounts, reserves against other long-term assets, which are included in other long-term assets, and other contingency liabilities, which are included in other current liabilities.

Description_of_Business_and_Ba1

Description of Business and Basis of Presentation - Additional Information (Detail)

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Mar. 28, 2013

Dec. 31, 2013

Dec. 31, 2012

Mar. 31, 2014

Mar. 31, 2013

Mar. 26, 2013

Mar. 14, 2013

Nov. 30, 2012

Feb. 29, 2012

Mar. 28, 2014

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Mar. 31, 2012

Mar. 13, 2012

Feb. 29, 2012

Dec. 31, 2013

Investments in Greater Than 20% [Member]

Investments in Less Than 20% [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Lucerne 1 [Member]

Eagle Plant [Member]

Collbran Valley Gas Gathering [Member]

Discovery Producer Services LLC [Member]

Mont Belvieu Enterprise Fractionator [Member]

Mont Belvieu 1 Fractionator [Member]

Front Range Pipeline [Member]

Phillips 66 [Member]

Spectra Energy [Member]

DCP Midstream, LLC [Member]

Southeast Texas [Member]

Southeast Texas [Member]

Southeast Texas [Member]

Southeast Texas [Member]

Southeast Texas [Member]

Texas Express [Member]

MMcf

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest percentage in subsidiary

'

'

'

80.00%

80.00%

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

100.00%

'

'

'

10.00%

Ownership interest percentage

'

20.00%

20.00%

'

'

'

'

'

33.33%

'

'

33.33%

'

100.00%

75.00%

40.00%

12.50%

20.00%

33.33%

'

'

'

'

'

'

'

'

'

Ownership interest acquired

'

'

'

46.67%

46.67%

33.33%

20.00%

46.67%

'

46.67%

33.33%

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

66.67%

66.67%

33.33%

'

Capacity

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest percentage by parent

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

50.00%

23.00%

'

'

'

'

'

'

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Schedule of Derivatives, Accounting Method and Presentation) (Detail)	12 Months Ended
	Dec. 31, 2013
Cash Flow Hedge [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Classification of Contract	'Cash Flow Hedge
Accounting Method	'Hedge method (a)	[1]
Presentation of Gains & Losses or Revenue & Expense	'Gross basis in the same consolidated statements of operations category as the related hedged item
Fair Value Hedge [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Classification of Contract	'Fair Value Hedge
Accounting Method	'Hedge method (a)	[1]
Presentation of Gains & Losses or Revenue & Expense	'Gross basis in the same consolidated statements of operations category as the related hedged item
Normal Purchases Or Normal Sales [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Classification of Contract	'Normal Purchases or Normal Sales
Accounting Method	'Accrual method (b)	[2]
Presentation of Gains & Losses or Revenue & Expense	'Gross basis upon settlement in the corresponding consolidated statements of operations category based on purchase or sale
Non-Trading Derivative Activity [Member]	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Classification of Contract	'Other Non-Trading Derivative Activity
Accounting Method	'Mark-to-market method (c)	[3]
Presentation of Gains & Losses or Revenue & Expense	'Net basis in gains and losses from commodity derivative activity
[1]	Hedge method - An accounting method whereby the change in the fair value of the asset or liability is recorded in the consolidated balance sheets as unrealized gains or unrealized losses on derivative instruments. For cash flow hedges, there is no recognition in the consolidated statements of operations for the effective portion until the service is provided or the associated delivery period impacts earnings. For fair value hedges, the change in the fair value of the asset or liability, as well as the offsetting changes in value of the hedged item, are recognized in the consolidated statements of operations in the same category as the related hedged item.
[2]	Accrual method - An accounting method whereby there is no recognition in the consolidated balance sheets or consolidated statements of operations for changes in fair value of a contract until the service is provided or the associated delivery period impacts earnings.
[3]	Mark-to-market method - An accounting method whereby the change in the fair value of the asset or liability is recognized in the consolidated statements of operations in gains and losses from commodity derivative activity during the current period.

Summary_of_Significant_Account4

Summary of Significant Accounting Policies (Significant Customers) (Detail)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	Customer	Customer	Customer
Summary Of Significant Accounting Policies [Line Items]	'	'	'
Customers that accounted for total operating revenues	10.00%	10.00%	10.00%
Significant customers	0	0	0
Wholesale Propane Logistics [Member]	'	'	'
Summary Of Significant Accounting Policies [Line Items]	'	'	'
Significant customers	'	1	1

Summary_of_Significant_Account5

Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Environmental Expenditures) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Accounting Policies [Abstract]	'	'
Current accrued environmental loss contingencies	$1	$1
Noncurrent accrued environmental loss contingencies	$1	$1

Acquisitions_Additional_Inform

Acquisitions - Additional Information (Detail) (USD $)

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

0 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

In Millions, except Share data, unless otherwise specified

Mar. 14, 2013

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Feb. 25, 2014

Mar. 31, 2014

Mar. 31, 2013

Aug. 05, 2013

Feb. 26, 2014

Aug. 05, 2013

Dec. 31, 2013

Mar. 28, 2013

Mar. 14, 2013

Mar. 31, 2013

Nov. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Mar. 31, 2014

Mar. 26, 2013

Feb. 29, 2012

Mar. 28, 2013

Jul. 03, 2012

Dec. 31, 2012

Jul. 03, 2012

Jul. 03, 2012

Jul. 03, 2012

Mar. 28, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Contractual Processing Arrangement [Member]

Texas Express [Member]

Subsequent Event [Member]

DCP Southern Hills Pipeline LLC [Member]

Dcp Midstream Lp [Member]

LaSalle Plant [Member]

LaSalle Plant [Member]

Front Range [Member]

Front Range [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Crossroads System [Member]

Crossroads System [Member]

Crossroads System [Member]

Crossroads System [Member]

Crossroads System [Member]

Lucerne 1 [Member]

Lucerne 1 [Member]

Lucerne 1 [Member]

Lucerne 1 [Member]

MMcf

Subsequent Event [Member]

bbl

Goliad Plant [Member]

MMcf

Gas Gathering Pipeline [Member]

Ngl Pipeline [Member]

Residue Gas Pipeline [Member]

MMcf

MMcf

mi

mi

mi

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenues

'

$821

$689

$792

$749

$671

$618

$680

$855

$3,051

[1]

$2,824

[2]

$3,790

[3]

$5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$71

[4]

$63

[4]

$90

[4]

Aggregate consideration for acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,220

'

'

209

'

86

'

626

'

'

'

'

'

'

'

'

'

63

'

'

'

'

0

'

'

'

Capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

Expected capacity per day

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

160

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

33.33%

'

'

'

33.33%

'

46.67%

46.67%

46.67%

33.33%

46.67%

33.33%

20.00%

'

'

46.67%

'

'

'

'

50.00%

100.00%

'

'

'

Ownership interest percentage in subsidiary

'

'

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

80.00%

'

'

'

80.00%

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Term of ship or pay arrangement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Term of plant dedication arrangement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investments in unconsolidated affiliates

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

87

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commodity price hedge period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

490

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior notes interest rate percentage

3.88%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Term of outstanding debt

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Remaining consideration financed through issuance of common units, value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

125

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of common units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,789,739

'

2,789,739

1,912,663

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

LLC and the amount paid cash on hand

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reimbursement for DCP Midstream, LLC

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50

'

'

'

'

'

'

'

'

'

Incremental Amount Included In Contribution Made

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

23

'

'

'

'

'

'

'

'

'

Excess purchase price over acquired assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

203

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minority interests ownership percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

33.33%

33.33%

'

'

'

'

'

'

'

'

'

'

Pipeline length

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8

20

11

'

'

'

'

Cryogenic processing plant capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

80

'

'

'

'

'

'

'

'

Revenues of acquiree

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

22

'

'

'

'

'

'

'

Earnings (loss) of acquiree

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1

'

'

'

'

'

'

'

[1]

The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[2]

The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[3]

The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[4]

{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmZkYjQ4M2U0NmU4ZTQ1MWNhMDFjMThlMmQ5NGE4N2E1fFRleHRTZWxlY3Rpb246QzNFQTQ2N0FGM0M2QTZBRTcyNjlGNzE1MjcxRkM4NTYM}

Acquisitions_Schedule_of_Impac

Acquisitions - Schedule of Impact on Financial Statements Due to Acquisition, Balance Sheets (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013		Mar. 31, 2013	Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
In Millions, unless otherwise specified
Current assets:	'	'		'	'		'		'
Cash and cash equivalents	$27	$12	[1]	$37	$2	[1],[2],[3]	$8	[2]	$7
Accounts receivable	'	342		'	239		'		'
Inventories	'	67		'	76	[3]	'		'
Other	'	82		'	51	[3]	'		'
Total current assets	'	503	[4]	'	368	[3],[4]	373	[4]	'
Property, plant and equipment, net	'	3,046		'	2,592	[3]	'		'
Goodwill and intangible assets, net	'	283		'	291	[3]	'		'
Investments in unconsolidated affiliates	'	627		'	304	[3]	'		'
Other non-current assets	'	108		'	90	[3]	'		'
Total assets	'	4,567		'	3,645	[3]	2,955		'
LIABILITIES AND EQUITY	'	'		'	'		'		'
Accounts payable and other current liabilities	'	723		'	345		'		'
Long-term debt	'	1,590		'	1,620	[3]	'		'
Other long-term liabilities	'	41		'	44	[3]	'		'
Total liabilities	'	2,354		'	2,009	[3]	'		'
Commitments and contingent liabilities	'	'		'	'		'		'
Equity:	'	'		'	'		'		'
Net equity	'	1,996		'	1,462		'		'
Accumulated other comprehensive loss	'	-11		'	-15	[3]	'		'
Total partners' equity	'	1,985		'	1,447	[3]	'		'
Noncontrolling interests	'	228		'	189	[3]	'		'
Total equity	'	2,213		'	1,636	[3]	1,605		1,460
Total liabilities and equity	'	4,567		'	3,645	[3]	'		'
Lucerne 1 [Member]	'	'		'	'		'		'
Current assets:	'	'		'	'		'		'
Cash and cash equivalents	'	0	[5]	'	0	[5]	'		'
Accounts receivable	'	0	[5]	'	0	[5]	'		'
Inventories	'	0	[5]	'	0	[5]	'		'
Other	'	0	[5]	'	0	[5]	'		'
Total current assets	'	0	[5]	'	0	[5]	'		'
Property, plant and equipment, net	'	41	[5]	'	42	[5]	'		'
Goodwill and intangible assets, net	'	0	[5]	'	0	[5]	'		'
Investments in unconsolidated affiliates	'	0	[5]	'	0	[5]	'		'
Other non-current assets	'	0	[5]	'	0	[5]	'		'
Total assets	'	41	[5]	'	42	[5]	'		'
LIABILITIES AND EQUITY	'	'		'	'		'		'
Accounts payable and other current liabilities	'	1	[5]	'	0	[5]	'		'
Long-term debt	'	0	[5]	'	0	[5]	'		'
Other long-term liabilities	'	0	[5]	'	0	[5]	'		'
Total liabilities	'	1	[5]	'	0	[5]	'		'
Equity:	'	'		'	'		'		'
Net equity	'	40	[5]	'	42	[5]	'		'
Accumulated other comprehensive loss	'	0	[5]	'	0	[5]	'		'
Total partners' equity	'	40	[5]	'	42	[5]	'		'
Noncontrolling interests	'	0	[5]	'	0	[5]	'		'
Total equity	'	40	[5]	'	42	[5]	'		'
Total liabilities and equity	'	41	[5]	'	42	[5]	'		'
DCP Midstream Partners, LP (as Previously Reported 2/26/14) [Member]	'	'		'	'		'		'
Current assets:	'	'		'	'		'		'
Cash and cash equivalents	'	12		'	2		'		'
Accounts receivable	'	342		'	239		'		'
Inventories	'	67		'	76		'		'
Other	'	82		'	51		'		'
Total current assets	'	503		'	368		'		'
Property, plant and equipment, net	'	3,005		'	2,550		'		'
Goodwill and intangible assets, net	'	283		'	291		'		'
Investments in unconsolidated affiliates	'	627		'	304		'		'
Other non-current assets	'	108		'	90		'		'
Total assets	'	4,526		'	3,603		'		'
LIABILITIES AND EQUITY	'	'		'	'		'		'
Accounts payable and other current liabilities	'	722		'	345		'		'
Long-term debt	'	1,590		'	1,620		'		'
Other long-term liabilities	'	41		'	44		'		'
Total liabilities	'	2,353		'	2,009		'		'
Commitments and contingent liabilities	'	'		'	'		'		'
Equity:	'	'		'	'		'		'
Net equity	'	1,956		'	1,420		'		'
Accumulated other comprehensive loss	'	-11		'	-15		'		'
Total partners' equity	'	1,945		'	1,405		'		'
Noncontrolling interests	'	228		'	189		'		'
Total equity	'	2,173		'	1,594		'		'
Total liabilities and equity	'	$4,526		'	$3,603		'		'
[1]	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[2]	The financial information during the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[3]	The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[4]	The segment information as of and for the years ended December 31, 2013, 2012 and 2011, includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas. Transfers of net assets between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information, similar to the pooling method.
[5]	{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmZkYjQ4M2U0NmU4ZTQ1MWNhMDFjMThlMmQ5NGE4N2E1fFRleHRTZWxlY3Rpb246RUY5QzM0OThBQTg3ODkwNDBCMTVGNzE1MjZCNzBBNDQM}

Acquisitions_Schedule_of_Impac1

Acquisitions - Schedule of Impact on Financial Statements Due to Acquisition, Balance Sheets (Parenthetical) (Detail) (Eagle Ford System [Member])	Mar. 26, 2013	Feb. 29, 2012
Eagle Ford System [Member]	'	'
Condensed Financial Statements, Captions [Line Items]	'	'
Ownership interest percentage	33.33%	33.33%

Acquisitions_Schedule_of_Impac2

Acquisitions - Schedule of Impact on Financial Statements Due to Acquisition, Statement of Operations (Detail) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Sales of natural gas, propane, NGLs and condensate

'

'

'

'

'

'

'

'

$2,763

[1]

$2,520

[2]

$3,574

[3]

Transportation, processing and other

'

'

'

'

'

'

'

'

271

[1]

234

[2]

208

[3]

Gains from commodity derivative activity, net

'

'

'

'

'

'

'

'

17

[1]

70

[2]

8

[3]

Total operating revenues

821

689

792

749

671

618

680

855

3,051

[1]

2,824

[2]

3,790

[3]

Operating costs and expenses

'

'

'

'

'

'

'

'

'

'

'

Purchases of natural gas, propane and NGLs

'

'

'

'

'

'

'

'

2,426

[1]

2,215

[2]

3,155

[3]

Operating and maintenance expense

'

'

'

'

'

'

'

'

215

[1]

197

[2]

192

[3]

Depreciation and amortization expense

'

'

'

'

'

'

'

'

95

[1]

91

[2]

135

[3]

General and administrative expense

'

'

'

'

'

'

'

'

63

[1]

75

[2]

76

[3]

Other expense (income)

'

'

'

'

'

'

'

'

8

[1]

0

-1

[3]

Total operating costs and expenses

'

'

'

'

'

'

'

'

2,807

[1]

2,578

[2]

3,557

[3]

Operating income

48

14

117

65

82

13

99

52

244

[1]

246

[2]

233

[3]

Interest expense

'

'

'

'

'

'

'

'

-52

[1]

-42

[2]

-34

[3]

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

33

[1]

26

[2]

23

[3]

Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest

'

'

'

'

'

'

'

'

225

[1]

230

[2]

222

[3]

Income tax expense

'

'

'

'

'

'

'

'

-8

[1],[4]

-1

[2],[4]

-1

[3],[4]

Net income

40

6

111

60

81

14

90

44

217

[1]

229

[2]

221

[3]

Net income attributable to noncontrolling interests

-7

-3

-4

-3

-5

-2

-2

-4

-17

[1]

-13

[2]

-30

[3]

Net income attributable to partners

33

3

107

57

76

12

88

40

200

[1]

216

[2]

191

[3]

Eagle Ford System [Member]

'

'

'

'

'

'

'

'

'

'

'

Operating costs and expenses

'

'

'

'

'

'

'

'

'

'

'

General and administrative expense

'

'

'

'

'

'

'

'

14

'

27

Lucerne 1 [Member]

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Sales of natural gas, propane, NGLs and condensate

'

'

'

'

'

'

'

'

68

[5]

61

[5]

87

[5]

Transportation, processing and other

'

'

'

'

'

'

'

'

3

[5]

2

[5]

3

[5]

Gains from commodity derivative activity, net

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Total operating revenues

'

'

'

'

'

'

'

'

71

[5]

63

[5]

90

[5]

Operating costs and expenses

'

'

'

'

'

'

'

'

'

'

'

Purchases of natural gas, propane and NGLs

'

'

'

'

'

'

'

'

45

[5]

38

[5]

55

[5]

Operating and maintenance expense

'

'

'

'

'

'

'

'

4

[5]

4

[5]

4

[5]

Depreciation and amortization expense

'

'

'

'

'

'

'

'

2

[5]

2

[5]

2

[5]

General and administrative expense

'

'

'

'

'

'

'

'

1

[5]

1

[5]

1

[5]

Other expense (income)

'

'

'

'

'

'

'

'

0

[5]

'

0

[5]

Total operating costs and expenses

'

'

'

'

'

'

'

'

52

[5]

45

[5]

62

[5]

Operating income

'

'

'

'

'

'

'

'

19

[5]

18

[5]

28

[5]

Interest expense

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest

'

'

'

'

'

'

'

'

19

[5]

18

[5]

28

[5]

Income tax expense

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Net income

'

'

'

'

'

'

'

'

19

[5]

18

[5]

28

[5]

Net income attributable to noncontrolling interests

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Net income attributable to partners

'

'

'

'

'

'

'

'

19

[5]

18

[5]

28

[5]

DCP Midstream Partners, LP (as Previously Reported 2/26/14) [Member]

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Sales of natural gas, propane, NGLs and condensate

'

'

'

'

'

'

'

'

2,695

2,459

3,487

Transportation, processing and other

'

'

'

'

'

'

'

'

268

232

205

Gains from commodity derivative activity, net

'

'

'

'

'

'

'

'

17

70

8

Total operating revenues

'

'

'

'

'

'

'

'

2,980

2,761

3,700

Operating costs and expenses

'

'

'

'

'

'

'

'

'

'

'

Purchases of natural gas, propane and NGLs

'

'

'

'

'

'

'

'

2,381

2,177

3,100

Operating and maintenance expense

'

'

'

'

'

'

'

'

211

193

188

Depreciation and amortization expense

'

'

'

'

'

'

'

'

93

89

133

General and administrative expense

'

'

'

'

'

'

'

'

62

74

75

Other expense (income)

'

'

'

'

'

'

'

'

8

'

-1

Total operating costs and expenses

'

'

'

'

'

'

'

'

2,755

2,533

3,495

Operating income

'

'

'

'

'

'

'

'

225

228

205

Interest expense

'

'

'

'

'

'

'

'

-52

-42

-34

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

33

26

23

Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest

'

'

'

'

'

'

'

'

206

212

194

Income tax expense

'

'

'

'

'

'

'

'

-8

-1

-1

Net income

'

'

'

'

'

'

'

'

198

211

193

Net income attributable to noncontrolling interests

'

'

'

'

'

'

'

'

-17

-13

-30

Net income attributable to partners

'

'

'

'

'

'

'

'

$181

$198

$163

[1]

The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[2]

The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[3]

The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[4]

For the year ended December 31, 2011, income tax expense relates primarily to the Texas margin tax and the Michigan business tax. The Michigan business tax was repealed in 2012; accordingly, income tax expense for the years ended December 31, 2013 and 2012 relates primarily to the Texas margin tax.

[5]

{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmZkYjQ4M2U0NmU4ZTQ1MWNhMDFjMThlMmQ5NGE4N2E1fFRleHRTZWxlY3Rpb246QzNFQTQ2N0FGM0M2QTZBRTcyNjlGNzE1MjcxRkM4NTYM}

Acquisitions_Schedule_of_Impac3

Acquisitions - Schedule of Impact on Financial Statements Due to Acquisition, Statement of Operations (Parenthetical) (Detail) (Eagle Ford System [Member])	Mar. 26, 2013	Feb. 29, 2012
Eagle Ford System [Member]	'	'
Condensed Financial Statements, Captions [Line Items]	'	'
Ownership interest percentage	33.33%	33.33%

Acquisitions_Assets_Acquired_a

Acquisitions - Assets Acquired and Liabilities Assumed (Details) (Crossroads System [Member], USD $)	0 Months Ended
In Millions, unless otherwise specified	Jul. 03, 2012
Crossroads System [Member]	'
Business Acquisition [Line Items]	'
Aggregate consideration	$63
Accounts receivable	4
Property, plant and equipment	63
Investments in unconsolidated affiliates	6
Other current liabilities	-4
Other long-term liabilities	-6
Total	$63

Acquisitions_Pro_Forma_Details

Acquisitions - Pro Forma (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, except Per Share data, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Net income attributable to partners

$33

$3

$107

$57

$76

$12

$88

$40

$200

[1]

$216

[2]

$191

[3]

Net income attributable to predecessor operations

'

'

'

'

'

'

'

'

-25

-51

-91

General partner's interest in net income

'

'

'

'

'

'

'

'

-70

-41

-25

Net income allocable to limited partners

8

-20

86

31

52

-9

69

12

105

124

75

Dcp Midstream Lp [Member]

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total operating revenues

'

'

'

'

'

'

'

'

'

2,824

3,790

Net income attributable to partners

'

'

'

'

'

'

'

'

'

216

191

Net income attributable to predecessor operations

'

'

'

'

'

'

'

'

'

-51

-91

General partner's interest in net income

'

'

'

'

'

'

'

'

'

-41

-25

Net income allocable to limited partners

'

'

'

'

'

'

'

'

'

124

75

Net income per limited partner unit - basic and diluted (in dollars per share)

'

'

'

'

'

'

'

'

'

$2.28

'

Net income per limited partner unit - basic (in dollars per share)

'

'

'

'

'

'

'

'

'

'

$1.73

Net income per limited partner unit - diluted (in dollars per share)

'

'

'

'

'

'

'

'

'

'

$1.72

Crossroads System [Member]

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total operating revenues

'

'

'

'

'

'

'

'

'

27

[4]

114

Net income attributable to partners

'

'

'

'

'

'

'

'

'

2

[4]

4

Net income allocable to limited partners

'

'

'

'

'

'

'

'

'

2

[4]

4

Net income per limited partner unit - basic and diluted (in dollars per share)

'

'

'

'

'

'

'

'

'

$0.03

[4]

'

Net income per limited partner unit - basic (in dollars per share)

'

'

'

'

'

'

'

'

'

'

$0.09

Net income per limited partner unit - diluted (in dollars per share)

'

'

'

'

'

'

'

'

'

'

$0.09

Dcp Midstream Partners Lp Pro Forma [Member]

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total operating revenues

'

'

'

'

'

'

'

'

'

2,851

3,904

Net income attributable to partners

'

'

'

'

'

'

'

'

'

218

195

Net income attributable to predecessor operations

'

'

'

'

'

'

'

'

'

-51

-91

General partner's interest in net income

'

'

'

'

'

'

'

'

'

-41

-25

Net income allocable to limited partners

'

'

'

'

'

'

'

'

'

$126

$79

Net income per limited partner unit - basic and diluted (in dollars per share)

'

'

'

'

'

'

'

'

'

$2.31

'

Net income per limited partner unit - basic (in dollars per share)

'

'

'

'

'

'

'

'

'

'

$1.82

Net income per limited partner unit - diluted (in dollars per share)

'

'

'

'

'

'

'

'

'

'

$1.81

[1]

The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[2]

The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[3]

The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[4]

The year ended December 31, 2012 includes the financial results of Crossroads for the period from January 1, 2012 through July 2, 2012.

Agreements_and_Transactions_wi2

Agreements and Transactions with Affiliates - Additional Information (Detail) (USD $)

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Apr. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

Lucerne 1 [Member]

Lucerne 1 [Member]

Lucerne 1 [Member]

Texas Express Pipeline [Member]

Spectra Energy [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Southeast Texas [Member]

Southeast Texas [Member]

Southeast Texas [Member]

LaSalle Plant [Member]

East Texas System [Member]

East Texas System [Member]

East Texas System [Member]

DJ Basin NGL Fractionators [Member]

DJ Basin NGL Fractionators [Member]

MBbls

gal

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Services agreement

'

'

'

'

'

'

'

'

$29

$26

$10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General and administrative expenses incurred

'

'

'

'

'

'

'

'

63

[1]

75

[2]

76

[3]

1

2

1

1

[4]

1

[4]

1

[4]

'

'

14

'

27

'

3

10

'

'

'

8

'

'

Other fees - DCP Midstream, LLC

'

'

'

'

'

'

'

'

17

32

47

'

'

'

'

'

'

'

'

'

27

'

'

'

'

'

'

'

'

'

'

Contributions from DCP Midstream, LLC

'

'

'

1

'

'

'

'

1

[1]

10

[5]

0

'

'

'

'

'

'

'

'

'

'

'

3

5

'

'

1

5

18

'

'

Length of processing agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'15 years

'

'

'

'

'

Percent of plant capacity used to calculate fixed demand charge

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

75.00%

'

'

'

'

'

Fees received under processing agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6

'

'

'

'

'

Natural Gas Propane Ngls Condensate Revenue

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Transportation Processing And Other To Affiliates

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Settlement Receivable

'

'

'

'

'

'

'

'

'

'

'

'

'

7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8

'

'

Net income attributable to noncontrolling interests

7

3

4

3

5

2

2

4

17

[1]

13

[2]

30

[3]

'

'

5

0

[4]

0

[4]

0

[4]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Transportation agreement (in MBbls per day)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20

'

'

'

'

'

'

'

'

'

'

'

'

'

Terms of agreement

'

'

'

'

'

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating and maintenance expense

'

'

'

'

'

'

'

'

$215

[1]

$197

[2]

$192

[3]

'

'

'

$4

[4]

$4

[4]

$4

[4]

'

'

'

'

'

'

'

'

'

'

'

'

$1

$1

Propane supply agreement (in gallons per year)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

185,000,000

'

'

'

'

'

'

'

'

'

'

'

'

[1]

The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[2]

The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[3]

The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[4]

{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmZkYjQ4M2U0NmU4ZTQ1MWNhMDFjMThlMmQ5NGE4N2E1fFRleHRTZWxlY3Rpb246QzNFQTQ2N0FGM0M2QTZBRTcyNjlGNzE1MjcxRkM4NTYM}

[5]

The financial information during the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Agreements_and_Transactions_wi3

Agreements and Transactions with Affiliates - Schedule of Fees Incurred and Other Fees Paid (Detail) (USD $)

12 Months Ended

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Services/Omnibus Agreement

$29

$26

$10

'

'

'

'

'

'

Other fees - DCP Midstream, LLC

17

32

47

'

'

'

'

'

'

Total - DCP Midstream, LLC

$63

[1]

$75

[2]

$76

[3]

$1

$2

$1

$46

$58

$57

[1]

The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[2]

The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[3]

The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Agreements_and_Transactions_wi4

Agreements and Transactions with Affiliates - Transactions with Affiliates (Detail) (USD $)

12 Months Ended

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

Affiliated Entity [Member]

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

DCP Midstream, LLC [Member]

Phillips 66 [Member]

Phillips 66 [Member]

Phillips 66 [Member]

ConocoPhillips [Member]

ConocoPhillips [Member]

ConocoPhillips [Member]

Spectra Energy [Member]

Spectra Energy [Member]

Spectra Energy [Member]

Unconsolidated Affiliates [Member]

Unconsolidated Affiliates [Member]

Unconsolidated Affiliates [Member]

Commodity Derivatives [Member]

Commodity Derivatives [Member]

Commodity Derivatives [Member]

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Sales of natural gas, propane, NGLs and condensate

$2,763

[1]

$2,520

[2]

$3,574

[3]

'

'

'

$1,830

$1,691

$2,346

'

'

'

$1

$0

$0

$0

[4]

$9

[4]

$57

[4]

'

'

'

'

'

'

Transportation, processing and other

271

[1]

234

[2]

208

[3]

'

'

'

60

52

30

'

'

'

'

'

'

0

[4]

3

[4]

9

[4]

'

'

'

'

'

'

Purchases of natural gas, propane and NGLs

2,426

[1]

2,215

[2]

3,155

[3]

'

'

'

204

173

244

'

'

'

'

'

'

0

[4]

67

[4]

139

[4]

63

166

321

0

2

6

Gains from commodity derivative activity, net

17

[1]

70

[2]

8

[3]

'

'

'

'

'

'

22

53

1

'

'

'

'

'

'

'

'

'

'

'

'

Operating and maintenance expense

215

[1]

197

[2]

192

[3]

'

'

'

1

1

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General and administrative expense

$63

[1]

$75

[2]

$76

[3]

$1

$2

$1

$46

$58

$57

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[2]

The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[3]

The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[4]

In connection with Phillips 66's separation from ConocoPhillips, ConocoPhillips is not considered to be a related party for periods after April 30, 2012 and Phillips 66 is considered a related party for periods starting May 1, 2012.

Agreements_and_Transactions_wi5

Agreements and Transactions with Affiliates - Balances with Affiliates (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Related Party Transaction [Line Items]	'	'
Accounts receivable	$212	$132
Accounts payable	43	72
DCP Midstream, LLC [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts receivable	211	132
Accounts payable	37	66
Unrealized gains on derivative instruments - current	79	48
Unrealized gains on derivative instruments - long-term	81	64
Unrealized losses on derivative instruments - current	18	-11
Unrealized losses on derivative instruments - long-term	1	0
Spectra Energy [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts receivable	1	0
Accounts payable	6	5
Unconsolidated Affiliates [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts payable	$0	$1

Inventories_Schedule_of_Invent

Inventories - Schedule of Inventories (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Components Of Inventory [Line Items]	'	'
Total inventories	$67	$76	[1]
Natural Gas [Member]	'	'
Components Of Inventory [Line Items]	'	'
Total inventories	38	22
Natural Gas Liquids [Member]	'	'
Components Of Inventory [Line Items]	'	'
Total inventories	$29	$54
[1]	The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Inventories_Additional_Informa

Inventories - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Inventory Disclosure [Abstract]	'	'
Inventory Write-down	$4	$19

Property_Plant_and_Equipment_C

Property, Plant and Equipment - Classification of Property, Plant and Equipment (Detail) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

In Millions, unless otherwise specified

Gathering and Transmission Systems [Member]

Gathering and Transmission Systems [Member]

Gathering and Transmission Systems [Member]

Gathering and Transmission Systems [Member]

Processing, Storage, and Terminal Facilities [Member]

Processing, Storage, and Terminal Facilities [Member]

Processing, Storage, and Terminal Facilities [Member]

Processing, Storage, and Terminal Facilities [Member]

Other Energy Equipment [Member]

Other Energy Equipment [Member]

Other Energy Equipment [Member]

Other Energy Equipment [Member]

Construction Work In Progress [Member]

Construction Work In Progress [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Property, Plant and Equipment [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Depreciable life of property, plant and equipment

'

'

'

'

'20 years

'50 years

'

'

'35 years

'60 years

'

'

'3 years

'30 years

'

'

Property, plant and equipment

$4,209

$3,668

$2,205

$1,921

'

'

$1,645

$1,154

'

'

$49

$32

'

'

$310

$561

Accumulated depreciation

-1,163

-1,076

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Property, plant and equipment, net

$3,046

$2,592

[1]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Property_Plant_and_Equipment_A

Property, Plant and Equipment - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Property, Plant and Equipment [Line Items]	'		'	'
Interest capitalized on construction projects	$11		$7	$2
Basic earnings per share adjustment, pro forma	'		$0.95	'
Depreciation expense	87		83	127
Other expense (income)	8	[1]	0	-1	[2]
Accretion expense (benefit) (less than $1mil for the year ended 2012)	1		-1	1
Property and Equipment [Member]	'		'	'
Property, Plant and Equipment [Line Items]	'		'	'
Reduction in depreciation expense	'		52	'
Asset retirement obligations	$24		$23	'
[1]	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[2]	The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Goodwill_and_Intangible_Assets2

Goodwill and Intangible Assets - Narrative (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Goodwill [Line Items]	'	'
Goodwill	$154	$154
Wholesale Propane Logistics [Member]	'	'
Goodwill [Line Items]	'	'
Goodwill	37	37
Natural Gas Services [Member]	'	'
Goodwill [Line Items]	'	'
Goodwill	82	82
NGL Logistics [Member]	'	'
Goodwill [Line Items]	'	'
Goodwill	$35	$35

Goodwill_and_Intangible_Assets3

Goodwill and Intangible Assets - Intangible Assets (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Goodwill and Intangible Assets Disclosure [Abstract]	'	'	'
Gross carrying amount	$164	$164	'
Accumulated amortization	-35	-27	'
Total	129	137	'
Amortization expense	$8	$8	$8
Minimum [Member]	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'
Remaining amortization period	'8 years	'	'
Maximum [Member]	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'
Remaining amortization period	'22 years	'	'
Weighted Average [Member]	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'
Remaining amortization period	'17 years	'	'

Goodwill_and_Intangible_Assets4

Goodwill and Intangible Assets - Future Amortization (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Goodwill and Intangible Assets Disclosure [Abstract]	'	'
2014	$8	'
2015	8	'
2016	8	'
2017	8	'
2018	8	'
Thereafter	89	'
Total	$129	$137

Recovered_Sheet1

Investments In Unconsolidated Affiliates - Investments In Unconsolidated Affiliates (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Investments in and Advances to Affiliates [Line Items]	'	'
Investments in unconsolidated affiliates	$627	$304
Discovery Producer Services LLC [Member]	'	'
Investments in and Advances to Affiliates [Line Items]	'	'
Ownership interest percentage	40.00%	'
Investments in unconsolidated affiliates	348	223
Front Range Pipeline LLC [Member]	'	'
Investments in and Advances to Affiliates [Line Items]	'	'
Ownership interest percentage	33.33%	'
Investments in unconsolidated affiliates	134	0
Texas Express Pipeline [Member]	'	'
Investments in and Advances to Affiliates [Line Items]	'	'
Ownership interest percentage	10.00%	'
Investments in unconsolidated affiliates	96	41
Mont Belvieu Enterprise Fractionator [Member]	'	'
Investments in and Advances to Affiliates [Line Items]	'	'
Ownership interest percentage	12.50%	'
Investments in unconsolidated affiliates	26	19
Mont Belvieu 1 Fractionator [Member]	'	'
Investments in and Advances to Affiliates [Line Items]	'	'
Ownership interest percentage	20.00%	'
Investments in unconsolidated affiliates	16	14
CrossPoint Pipeline, LLC [Member]	'	'
Investments in and Advances to Affiliates [Line Items]	'	'
Ownership interest percentage	50.00%	'
Investments in unconsolidated affiliates	6	6
Other [Member]	'	'
Investments in and Advances to Affiliates [Line Items]	'	'
Ownership interest percentage description	'Various	'
Investments in unconsolidated affiliates	$1	$1

Recovered_Sheet2

Investments In Unconsolidated Affiliates - Additional Information (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Discovery Producer Services LLC [Member]	'	'
Investments in and Advances to Affiliates [Line Items]	'	'
Carrying amount of the investment and the underlying equity (deficit)	($28)	($30)
Front Range Pipeline LLC [Member]	'	'
Investments in and Advances to Affiliates [Line Items]	'	'
Carrying amount of the investment and the underlying equity (deficit)	4	'
Texas Express Pipeline [Member]	'	'
Investments in and Advances to Affiliates [Line Items]	'	'
Carrying amount of the investment and the underlying equity (deficit)	3	'
Mont Belvieu 1 Fractionator [Member]	'	'
Investments in and Advances to Affiliates [Line Items]	'	'
Carrying amount of the investment and the underlying equity (deficit)	-5	-6
Maximum [Member] | Texas Express Pipeline [Member]	'	'
Investments in and Advances to Affiliates [Line Items]	'	'
Carrying amount of the investment and the underlying equity (deficit)	'	$1

Investments_in_Unconsolidated_2

Investments in Unconsolidated Affiliates - Earnings from Investments in Unconsolidated Affiliates (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Investments in and Advances to Affiliates [Line Items]	'		'		'
Earnings from unconsolidated affiliates	$33	[1]	$26	[2]	$23	[3]
Mont Belvieu 1 Fractionator [Member]	'		'		'
Investments in and Advances to Affiliates [Line Items]	'		'		'
Earnings from unconsolidated affiliates	19		6		0
Mont Belvieu Enterprise Fractionator [Member]	'		'		'
Investments in and Advances to Affiliates [Line Items]	'		'		'
Earnings from unconsolidated affiliates	14		5		0
Discovery Producer Services LLC [Member]	'		'		'
Investments in and Advances to Affiliates [Line Items]	'		'		'
Earnings from unconsolidated affiliates	1		15		23
Texas Express [Member]	'		'		'
Investments in and Advances to Affiliates [Line Items]	'		'		'
Earnings from unconsolidated affiliates	($1)		$0		$0
[1]	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[2]	The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[3]	The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Investments_in_Unconsolidated_3

Investments in Unconsolidated Affiliates - Equity Method Investment Summarized Financial Information, Statement of Operations (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Equity Method Investments and Joint Ventures [Abstract]	'	'	'
Operating revenue	$484	$293	$213
Operating expenses	298	190	163
Net income	$186	$103	$50

Investments_in_Unconsolidated_4

Investments in Unconsolidated Affiliates - Equity Method Investment Summarized Financial Information, Balance Sheet (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Equity Method Investments and Joint Ventures [Abstract]	'	'
Current assets	$182	$129
Long-term assets	2,678	1,288
Current liabilities	-276	-75
Long-term liabilities	-37	-43
Net assets	$2,547	$1,299

Fair_Value_Measurement_Financi

Fair Value Measurement - Financial Instruments Carried at Fair Value (Detail) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	($28)		($31)
Commodity Derivative [Member] | Current Assets [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	79	[1]	49	[1]
Short-term investments	9	[1],[2]	2	[1],[2]
Commodity Derivative [Member] | Long-Term Assets [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	87	[3]	70	[3]
Commodity Derivative [Member] | Current Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	-26	[4]	-27	[4]
Commodity Derivative [Member] | Long-Term Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	-1	[5]	-6	[5]
Interest Rate Derivatives [Member] | Current Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Interest rate derivatives	-2	[4]	-4	[4]
Interest Rate Derivatives [Member] | Long-Term Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Interest rate derivatives	0	[5]	-2	[5]
Level 1 [Member] | Commodity Derivative [Member] | Current Assets [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	0	[1]	0	[1]
Short-term investments	9	[1],[2]	2	[1],[2]
Level 1 [Member] | Commodity Derivative [Member] | Long-Term Assets [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	0	[3]	0	[3]
Level 1 [Member] | Commodity Derivative [Member] | Current Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	0	[4]	0	[4]
Level 1 [Member] | Commodity Derivative [Member] | Long-Term Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	0	[5]	0	[5]
Level 1 [Member] | Interest Rate Derivatives [Member] | Current Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Interest rate derivatives	0	[4]	0	[4]
Level 1 [Member] | Interest Rate Derivatives [Member] | Long-Term Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Interest rate derivatives	0	[5]	0	[5]
Level 2 [Member] | Commodity Derivative [Member] | Current Assets [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	14	[1]	9	[1]
Short-term investments	0	[1],[2]	0	[1],[2]
Level 2 [Member] | Commodity Derivative [Member] | Long-Term Assets [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	12	[3]	5	[3]
Level 2 [Member] | Commodity Derivative [Member] | Current Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	-26	[4]	-26	[4]
Level 2 [Member] | Commodity Derivative [Member] | Long-Term Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	-1	[5]	-6	[5]
Level 2 [Member] | Interest Rate Derivatives [Member] | Current Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Interest rate derivatives	-2	[4]	-4	[4]
Level 2 [Member] | Interest Rate Derivatives [Member] | Long-Term Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Interest rate derivatives	0	[5]	-2	[5]
Level 3 [Member] | Commodity Derivative [Member] | Current Assets [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	65	[1]	40	[1]
Short-term investments	0	[1],[2]	0	[1],[2]
Level 3 [Member] | Commodity Derivative [Member] | Long-Term Assets [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	75	[3]	65	[3]
Level 3 [Member] | Commodity Derivative [Member] | Current Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	0	[4]	-1	[4]
Level 3 [Member] | Commodity Derivative [Member] | Long-Term Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Commodity derivatives	0	[5]	0	[5]
Level 3 [Member] | Interest Rate Derivatives [Member] | Current Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Interest rate derivatives	0	[4]	0	[4]
Level 3 [Member] | Interest Rate Derivatives [Member] | Long-Term Liabilities [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Interest rate derivatives	$0	[5]	$0	[5]
[1]	Included in current unrealized gains on derivative instruments in our consolidated balance sheets.
[2]	Includes short-term money market securities included in cash and cash equivalents in our consolidated balance sheets.
[3]	Included in long-term unrealized gains on derivative instruments in our consolidated balance sheets.
[4]	Included in current unrealized losses on derivative instruments in our consolidated balance sheets.
[5]	Included in long-term unrealized losses on derivative instruments in our consolidated balance sheets.

Fair_Value_Measurement_Condens

Fair Value Measurement - Condensed Consolidated Balance Sheets for Derivative Financial Instruments (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Current Assets [Member]	'		'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'		'
Beginning balance	$40	[1]	$1	[1]
Net realized and unrealized gains (losses) included in earnings	42	[1],[2]	14	[1],[2]
Transfers into Level 3	0	[1],[3]	0	[1],[3]
Transfers out of Level 3	-1	[1],[3]	0	[1],[3]
Settlements	-40	[1]	-2	[1]
Purchases	24	[1]	27	[1]
Ending balance	65	[1]	40	[1]
Net unrealized gains still held included in earnings	41	[1],[2]	13	[1],[2]
Long-Term Assets [Member]	'		'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'		'
Beginning balance	65	[1]	1	[1]
Net realized and unrealized gains (losses) included in earnings	-50	[1],[2]	2	[1],[2]
Transfers into Level 3	0	[1],[3]	0	[1],[3]
Transfers out of Level 3	-2	[1],[3]	0	[1],[3]
Settlements	0	[1]	0	[1]
Purchases	62	[1]	62	[1]
Ending balance	75	[1]	65	[1]
Net unrealized gains still held included in earnings	-50	[1],[2]	2	[1],[2]
Current Liabilities [Member]	'		'
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'		'
Beginning balance	-1	[1]	-1	[1]
Net realized and unrealized (losses) gains included in earnings	0	[1],[2]	0	[1],[2]
Transfers into Level 3	0	[1],[3]	0	[1],[3]
Transfers out of Level 3	1	[1],[3]	0	[1],[3]
Settlements	0	[1]	0	[1]
Purchases	0	[1]	0	[1]
Ending balance	0	[1]	-1	[1]
Net unrealized gains (losses) still held included in earnings	0	[1],[2]	0	[1],[2]
Long-Term Liabilities [Member]	'		'
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'		'
Beginning balance	0	[1]	0	[1]
Net realized and unrealized (losses) gains included in earnings	0	[1],[2]	0	[1],[2]
Transfers into Level 3	'		0	[1],[3]
Transfers out of Level 3	0	[1],[3]	0	[1],[3]
Settlements	0	[1]	0	[1]
Purchases	0	[1]	0	[1]
Ending balance	0	[1]	0	[1]
Net unrealized gains (losses) still held included in earnings	$0	[1],[2]	$0	[1],[2]
[1]	There were no issuances or sales of derivatives for the years ended December 31, 2013 and 2012.
[2]	Represents the amount of total gains or losses for the year, included in gains or losses from commodity derivative activity, net, attributable to changes in unrealized gains or losses relating to assets and liabilities classified as Level 3.
[3]	Amounts transferred in and amounts transferred out are reflected at fair value as of the end of the period.

Fair_Value_Measurement_Schedul

Fair Value Measurement - Schedule of Valuation Processes (Detail) (Fair Value, Inputs, Level 3 [Member], Market Approach Valuation Technique [Member], Derivative Financial Instruments, Assets [Member], Natural Gas Liquids [Member], USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]	'
Fair Value, Assets	$140
Minimum [Member]	'
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]	'
Forward Curve Range	0.27
Maximum [Member]	'
Fair Value Inputs Assets And Liabilities Quantitative Information [Line Items]	'
Forward Curve Range	2.11

Fair_Value_Measurement_Additio

Fair Value Measurement - Additional Information (Detail) (USD $)

Mar. 14, 2013

Dec. 31, 2013

Mar. 14, 2013

Dec. 31, 2013

Dec. 31, 2012

Nov. 27, 2012

Dec. 31, 2013

Dec. 31, 2012

Mar. 13, 2012

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2010

Dec. 31, 2012

In Millions, unless otherwise specified

Senior Notes, 3.875% Due 2023 [Member]

Senior Notes, 3.875% Due 2023 [Member]

Senior Notes, 2.50% Due 2017 [Member]

Senior Notes, 2.50% Due 2017 [Member]

Senior Notes, 2.50% Due 2017 [Member]

Senior Notes, 4.95% Due 2022 [Member]

Senior Notes, 4.95% Due 2022 [Member]

Senior Notes, 4.95% Due 2022 [Member]

Senior Notes, 3.25% Due 2015 [Member]

Senior Notes, 3.25% Due 2015 [Member]

Senior Notes, 3.25% Due 2015 [Member]

Credit Agreement [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Carrying value of outstanding balances

'

'

'

'

'

'

'

'

'

'

'

'

$525

Senior notes interest rate percentage

3.88%

3.88%

3.88%

2.50%

'

2.50%

4.95%

'

4.95%

3.25%

'

3.25%

'

Debt Instrument, Carrying Amount

'

494

'

497

500

'

349

350

'

250

250

'

'

Debt Instrument, Fair Value

'

$461

'

$500

'

'

$354

$374

'

$258

$259

'

'

Debt_Schedule_of_LongTerm_Debt

Debt - Schedule of Long-Term Debt (Detail) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Mar. 14, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Nov. 27, 2012

Dec. 31, 2013

Dec. 31, 2012

Mar. 13, 2012

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Senior Notes, 3.875% Due 2023 [Member]

Senior Notes, 3.875% Due 2023 [Member]

Senior Notes, 3.875% Due 2023 [Member]

Senior Notes, 2.50% Due 2017 [Member]

Senior Notes, 2.50% Due 2017 [Member]

Senior Notes, 2.50% Due 2017 [Member]

Senior Notes, 4.95% Due 2022 [Member]

Senior Notes, 4.95% Due 2022 [Member]

Senior Notes, 4.95% Due 2022 [Member]

Senior Notes, 3.25% Due 2015 [Member]

Senior Notes, 3.25% Due 2015 [Member]

Senior Notes, 3.25% Due 2015 [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Credit Agreement [Member]

Credit Agreement [Member]

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Short-term borrowings

$335,000,000

$0

'

'

'

'

'

'

'

'

'

'

'

'

$335,000,000

$0

'

'

Revolving credit facility, weighted-average variable interest rate of 1.47%, as of December 31, 2012, due November 10, 2016 (a)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

[1]

525,000,000

[1]

Debt Securities Issued Amount

'

'

500,000,000

500,000,000

0

500,000,000

500,000,000

500,000,000

350,000,000

350,000,000

350,000,000

250,000,000

250,000,000

250,000,000

'

'

'

'

Unamortized discount

-10,000,000

-5,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total debt

1,925,000,000

1,620,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long-term debt

$1,590,000,000

$1,620,000,000

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

$150 million was swapped to a fixed rate obligation with fixed rates ranging from 2.94% to 2.99%, for a net effective rate of 2.25% on the $525 million of outstanding debt under our revolving credit facility as of December 31, 2012.

[2]

The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Debt_Schedule_of_LongTerm_Debt1

Debt - Schedule of Long-Term Debt (Parenthetical) (Detail) (USD $)

Mar. 14, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Mar. 14, 2013

Dec. 31, 2013

Nov. 27, 2012

Dec. 31, 2013

Mar. 13, 2012

Dec. 31, 2013

Sep. 30, 2010

In Millions, unless otherwise specified

Credit Agreement [Member]

Credit Agreement [Member]

Commercial Paper [Member]

Minimum [Member]

Maximum [Member]

Senior Notes, 3.875% Due 2023 [Member]

Senior Notes, 3.875% Due 2023 [Member]

Senior Notes, 2.50% Due 2017 [Member]

Senior Notes, 2.50% Due 2017 [Member]

Senior Notes, 4.95% Due 2022 [Member]

Senior Notes, 4.95% Due 2022 [Member]

Senior Notes, 3.25% Due 2015 [Member]

Senior Notes, 3.25% Due 2015 [Member]

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted-average variable interest rate

'

'

'

1.47%

1.14%

'

'

'

'

'

'

'

'

'

'

Line of credit facility, maturity date

'

'

10-Nov-16

'

'

'

'

'

'

'

'

'

'

'

'

Interest payable semi-annually

3.88%

'

'

'

'

'

'

3.88%

3.88%

2.50%

2.50%

4.95%

4.95%

3.25%

3.25%

Maturity date

'

'

'

'

'

'

'

15-Mar-23

'

1-Dec-17

'

1-Apr-22

'

1-Oct-15

'

Derivative, Amount of Hedged Item

'

$150

'

'

'

'

'

'

'

'

'

'

'

'

'

Net interest rate

'

'

'

2.25%

'

2.94%

2.99%

'

'

'

'

'

'

'

'

Fair value of outstanding balances

'

'

$0

[1]

$525

[1]

'

'

'

'

'

'

'

'

'

'

'

[1]

$150 million was swapped to a fixed rate obligation with fixed rates ranging from 2.94% to 2.99%, for a net effective rate of 2.25% on the $525 million of outstanding debt under our revolving credit facility as of December 31, 2012.

Debt_Additional_Information_De

Debt - Additional Information (Detail) (USD $)

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

Mar. 14, 2013

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 14, 2013

Dec. 31, 2013

Dec. 31, 2012

Nov. 27, 2012

Dec. 31, 2013

Dec. 31, 2012

Mar. 13, 2012

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2010

Dec. 31, 2013

Dec. 31, 2012

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2013

Mar. 28, 2013

Mar. 14, 2013

Dec. 31, 2012

Nov. 30, 2012

Dec. 31, 2013

Mar. 31, 2012

Mar. 13, 2012

Feb. 29, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Senior Notes, 3.875% Due 2023 [Member]

Senior Notes, 3.875% Due 2023 [Member]

Senior Notes, 3.875% Due 2023 [Member]

Senior Notes, 2.50% Due 2017 [Member]

Senior Notes, 2.50% Due 2017 [Member]

Senior Notes, 2.50% Due 2017 [Member]

Senior Notes, 4.95% Due 2022 [Member]

Senior Notes, 4.95% Due 2022 [Member]

Senior Notes, 4.95% Due 2022 [Member]

Senior Notes, 3.25% Due 2015 [Member]

Senior Notes, 3.25% Due 2015 [Member]

Senior Notes, 3.25% Due 2015 [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Southeast Texas [Member]

Southeast Texas [Member]

Southeast Texas [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Credit Agreement [Member]

London Interbank Offered Rate (LIBOR) [Member]

Federal Funds Effective Swap Rate [Member]

London Interbank Offered Rate (LIBOR) Market Index [Member]

Credit Agreement [Member]

Credit Agreement [Member]

Senior Notes, 3.875% Due 2023 [Member]

Credit Agreement [Member]

Credit Agreement [Member]

Credit Agreement [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity

'

'

'

$1,000,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Short-term borrowings

'

'

'

335,000,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

335,000,000

0

'

'

'

'

'

'

Line of credit facility, maturity date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10-Nov-16

'

'

'

'

'

Letters of credit issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

'

'

'

1,000,000

'

Letters of credit outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

1,200,000

Unused capacity under the credit agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

664,000,000

'

'

'

'

'

Variable rate basis spread

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.25%

0.50%

1.00%

'

'

Basis spread determined by credit rating

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.25%

'

'

'

'

'

Commitment fee percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.25%

'

'

'

'

'

Maximum leverage ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

'

'

'

'

'

Temporary maximum leverage ratio post-acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.5

'

'

'

'

'

Senior notes issued

'

'

'

'

'

'

500,000,000

500,000,000

0

500,000,000

500,000,000

500,000,000

350,000,000

350,000,000

350,000,000

250,000,000

250,000,000

250,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior notes interest rate percentage

3.88%

'

'

'

'

'

3.88%

3.88%

'

2.50%

2.50%

'

4.95%

4.95%

'

3.25%

3.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Term of outstanding debt

'10 years

'

'

'

'

'

'10 years

'

'

'5 years

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maturity date

'

'

'

'

'

'

'

15-Mar-23

'

'

1-Dec-17

'

'

1-Apr-22

'

'

1-Oct-15

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from long-term debt

'

719,000,000

809,000,000

1,957,000,000

[1]

2,665,000,000

[2]

1,524,000,000

490,000,000

'

'

494,000,000

'

'

346,000,000

'

'

248,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Underwriters' fees

'

'

'

'

'

'

$10,000,000

'

'

$6,000,000

'

'

$4,000,000

'

'

$2,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20.00%

46.67%

46.67%

46.67%

46.67%

33.33%

33.33%

46.67%

66.67%

66.67%

33.33%

'

'

'

'

'

'

'

'

First payment date

'

'

'

'

'

'

'

15-Sep-13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[2]

The financial information during the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Debt_Future_Maturities_of_Long

Debt - Future Maturities of Long-Term Debt (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Maturities of Long-term Debt [Abstract]	'	'
2014	$0	'
2015	250	'
2016	0	'
2017	500	'
2018	0	'
Thereafter	850	'
Total principal	1,600	'
Unamortized discount	-10	-5
Total	$1,590	$1,620	[1]
[1]	The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Risk_Management_and_Hedging_Ac2

Risk Management and Hedging Activities - Additional Information (Detail) (USD $)	12 Months Ended	1 Months Ended				1 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Aug. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Mar. 30, 2012	Mar. 13, 2012
		Interest Rate Derivatives [Member]	Interest Rate Derivatives [Member]	Interest Rate Derivatives [Member]	Interest Rate Derivatives [Member]	Forward Starting Interest Rate Swap [Member]	Forward Starting Interest Rate Swap [Member]
				Minimum [Member]	Maximum [Member]
Derivative [Line Items]	'	'	'	'	'	'	'
Base gas hedge fair value	$3	'	'	'	'	'	'
Notional value of derivative	150	'	'	70	80	'	195
Interest rate swap agreements reprice every thirty days	'30 days	'	'	'	'	'	'
Effective fixed-rates lower range	2.94%	'	'	'	'	'	'
Effective fixed-rates higher range	2.99%	'	'	'	'	'	'
Deferred loss recognized	'	3	'	'	'	5	'
Derivative settlement amount	'	'	'	'	'	7	'
Derivative net liability position	8	'	150	'	'	'	'
Reduce in net liability due to offset of contract	6	'	'	'	'	'	'
Liability on interest rate swap	$2	'	'	'	'	'	'

Risk_Management_and_Hedging_Ac3

Risk Management and Hedging Activities - Summary of Gross and Net Amounts of Derivative Instruments (Detail) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Fair Values Of Financial Assets And Liabilities Including Derivative Financial Instruments [Line Items]	'		'
Gross Amounts of Liabilities Presented in the Balance Sheet	($28)		($31)
Commodity Derivatives [Member]	'		'
Fair Values Of Financial Assets And Liabilities Including Derivative Financial Instruments [Line Items]	'		'
Gross Amounts of Assets Presented in the Balance Sheet	166		119
Amounts Not Offset in the Balance Sheet - Financial Instruments	-13	[1]	-10	[1]
Net Amount, Assets	153		109
Gross Amounts of Liabilities Presented in the Balance Sheet	-27		-33
Amounts Not Offset in the Balance Sheet - Financial Instruments	13	[1]	10	[1]
Net Amount, Liabilities	14		23
Interest rate derivative [Member]	'		'
Fair Values Of Financial Assets And Liabilities Including Derivative Financial Instruments [Line Items]	'		'
Gross Amounts of Assets Presented in the Balance Sheet	0		'
Amounts Not Offset in the Balance Sheet - Financial Instruments	0	[1]	'	[1]
Net Amount, Assets	0		'
Gross Amounts of Liabilities Presented in the Balance Sheet	-2		-6
Amounts Not Offset in the Balance Sheet - Financial Instruments	0	[1]	'	[1]
Net Amount, Liabilities	$2		$6
[1]	There is no cash collateral pledged or received against these positions.

Risk_Management_and_Hedging_Ac4

Risk Management and Hedging Activities - Schedule of Designated and Non-Designated Derivative Instruments in Statement of Financial Position, Fair Value (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Derivative Asset [Abstract]	'	'
Unrealized gains on derivative instruments - current	$79	$49
Unrealized gains on derivative instruments - long-term	87	70
Derivative Liability [Abstract]	'	'
Unrealized losses on derivative instruments - long-term	-1	-8
Derivative liabilities, fair value, total	-28	-31
Commodity Derivatives [Member] | Derivative Asset Designated as Hedging Instruments [Member]	'	'
Derivative Asset [Abstract]	'	'
Unrealized gains on derivative instruments - current	0	'
Unrealized gains on derivative instruments - long-term	0	'
Derivative assets, fair value, total	0	'
Commodity Derivatives [Member] | Derivative Asset Not Designated As Hedging Instruments [Member]	'	'
Derivative Asset [Abstract]	'	'
Unrealized gains on derivative instruments - current	79	49
Unrealized gains on derivative instruments - long-term	87	70
Derivative assets, fair value, total	166	119
Commodity Derivatives [Member] | Derivative Liabilities Designated as Hedging Instruments [Member]	'	'
Derivative Liability [Abstract]	'	'
Unrealized gains on derivative instruments - current	0	3
Unrealized losses on derivative instruments - long-term	'	'
Derivative liabilities, fair value, total	0	-3
Commodity Derivatives [Member] | Derivative Liabilities Not Designated As Hedging Instruments [Member]	'	'
Derivative Liability [Abstract]	'	'
Unrealized gains on derivative instruments - current	26	24
Unrealized losses on derivative instruments - long-term	-1	-6
Derivative liabilities, fair value, total	-27	-30
Interest Rate Derivatives [Member] | Derivative Asset Designated as Hedging Instruments [Member]	'	'
Derivative Asset [Abstract]	'	'
Unrealized gains on derivative instruments - current	0	'
Unrealized gains on derivative instruments - long-term	0	'
Derivative assets, fair value, total	0	'
Interest Rate Derivatives [Member] | Derivative Asset Not Designated As Hedging Instruments [Member]	'	'
Derivative Asset [Abstract]	'	'
Unrealized gains on derivative instruments - current	0	0
Unrealized gains on derivative instruments - long-term	0	0
Derivative assets, fair value, total	0	0
Interest Rate Derivatives [Member] | Derivative Liabilities Designated as Hedging Instruments [Member]	'	'
Derivative Liability [Abstract]	'	'
Unrealized gains on derivative instruments - current	0	4
Unrealized losses on derivative instruments - long-term	0	-2
Derivative liabilities, fair value, total	0	-6
Interest Rate Derivatives [Member] | Derivative Liabilities Not Designated As Hedging Instruments [Member]	'	'
Derivative Liability [Abstract]	'	'
Unrealized gains on derivative instruments - current	2	0
Unrealized losses on derivative instruments - long-term	0	0
Derivative liabilities, fair value, total	($2)	$0

Risk_Management_and_Hedging_Ac5

Risk Management and Hedging Activities - Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) (Detail) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

In Millions, unless otherwise specified

Interest Rate Derivatives [Member]

Commodity Derivatives [Member]

Foreign Currency Derivatives [Member]

Cash Flow Hedge [Member]

Cash Flow Hedge [Member]

Cash Flow Hedge [Member]

Cash Flow Hedge [Member]

Interest Rate Derivatives [Member]

Commodity Derivatives [Member]

Foreign Currency Derivatives [Member]

Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]

'

'

'

'

'

'

'

'

'

Net deferred (losses) gains in AOCI (beginning balance)

($11)

($15)

[1]

'

'

'

($15)

($10)

($6)

$1

[2]

Gains (losses) recognized in AOCI on derivatives - effective portion

'

'

-10

[3]

'

'

[2]

4

4

[3]

0

0

[2]

Net deferred losses in AOCI (ending balance)

-11

-15

[1]

'

'

'

-11

-6

-6

1

[2]

Deferred losses in AOCI expected to be reclassified into earnings over the next 12 months

'

'

'

'

'

($2)

($2)

$0

$0

[2]

[1]

The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[2]

Relates to Discovery, our unconsolidated affiliate.

[3]

Included in interest expense in our consolidated statements of operations.

Risk_Management_and_Hedging_Ac6

Risk Management and Hedging Activities - Schedule of Derivatives Accounted for as Cash Flow Hedges (Parenthetical) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Interest Rate Derivatives [Member]	'	'
Derivative [Line Items]	'	'
Losses Recognized in Income on Derivatives - Ineffective Portion and Amount Excluded From Effectiveness Testing	'	$2	[1],[2]
Gain/Loss Reclassified From AOCI to Earnings-Discontinuance	'	1
Commodity Derivatives [Member]	'	'
Derivative [Line Items]	'	'
Losses Recognized in Income on Derivatives - Ineffective Portion and Amount Excluded From Effectiveness Testing	1	'
Gain/Loss Reclassified From AOCI to Earnings-Discontinuance	$1	'
[1]	Included in interest expense in our consolidated statements of operations.
[2]	For the year ended December 31, 2012, less than $1 million of derivative losses were reclassified from AOCI to current period earnings as a result of the discontinuance of cash flow hedges related to certain forecasted transactions that are not probable of occurring.

Risk_Management_and_Hedging_Ac7

Risk Management and Hedging Activities - Schedule of Derivatives Accounted for as Cash Flow Hedges (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Interest Rate Derivatives [Member]	'	'
Derivative [Line Items]	'	'
Losses Recognized in AOCI on Derivatives - Effective Portion	'	($1)
Losses Reclassified From AOCI to Earnings-Effective Portion	'	-10	[1]
Losses Recognized in Income on Derivatives - Ineffective Portion and Amount Excluded From Effectiveness Testing	'	-2	[1],[2]
Commodity Derivatives [Member]	'	'
Derivative [Line Items]	'	'
Losses Recognized in AOCI on Derivatives - Effective Portion	'	-1
Losses Reclassified From AOCI to Earnings-Effective Portion	'	'
Losses Recognized in Income on Derivatives - Ineffective Portion and Amount Excluded From Effectiveness Testing	-1	'
Foreign Currency Derivatives [Member]	'	'
Derivative [Line Items]	'	'
Losses Recognized in AOCI on Derivatives - Effective Portion	'	1	[3]
Losses Reclassified From AOCI to Earnings-Effective Portion	'	'	[3]
Losses Recognized in Income on Derivatives - Ineffective Portion and Amount Excluded From Effectiveness Testing	'	'	[3]
[1]	Included in interest expense in our consolidated statements of operations.
[2]	For the year ended December 31, 2012, less than $1 million of derivative losses were reclassified from AOCI to current period earnings as a result of the discontinuance of cash flow hedges related to certain forecasted transactions that are not probable of occurring.
[3]	Relates to Discovery, our unconsolidated affiliate.

Risk_Management_and_Hedging_Ac8

Risk Management and Hedging Activities - Schedule of Changes in Derivative Instruments not Designated as Hedging Instruments (Detail) (Derivative Assets Not Designated As Hedging Instruments [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Affiliates [Member] | Commodity Derivatives [Member]	'	'	'
Derivative [Line Items]	'	'	'
Realized	$73	$45	$2
Unrealized	-51	8	-1
(Losses) gains from commodity derivative activity, net	22	53	1
Third Party [Member] | Commodity Derivatives [Member]	'	'	'
Derivative [Line Items]	'	'	'
Realized	-19	4	-36
Unrealized	14	13	43
(Losses) gains from commodity derivative activity, net	-5	17	7
Third Party [Member] | Interest Rate Derivatives [Member]	'	'	'
Derivative [Line Items]	'	'	'
Realized	-2	-7	-4
Unrealized	2	7	5
(Losses) gains from commodity derivative activity, net	'	'	$1

Risk_Management_and_Hedging_Ac9

Risk Management and Hedging Activities - Schedule of Net Long or Short Positions Expected to be Realized (Detail)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
	bbl	bbl
Crude Oil [Member]	'	'
Net (Short) Position, Volume [Abstract]	'	'
Net (Short) Position (Bbls), 2013	'	-943,379
Net (Short) Position (Bbls), 2014	-690,945	-584,365
Net (Short) Position (Bbls), 2015	-745,695	-401,865
Net (Short) Position (Bbls), 2016	-561,922	-183,000
Natural Gas [Member]	'	'
Derivative [Line Items]	'	'
Net Long (Short) Position (MMBtu), 2013	'	-8,887,980
Net Long (Short) Position (MMBtu), 2014	-21,673,620	-4,712,880
Net Long (Short) Position (MMBtu), 2015	-9,458,975	-5,127,155
Net Long (Short) Position (MMBtu), 2016	-1,838,564	0
Natural Gas Liquids [Member]	'	'
Net (Short) Position, Volume [Abstract]	'	'
Net (Short) Position (Bbls), 2013	'	2,593,955
Net (Short) Position (Bbls), 2014	-5,171,910	-2,584,930
Net (Short) Position (Bbls), 2015	-5,691,570	-2,491,250
Net (Short) Position (Bbls), 2016	-813,267	0
Natural Gas Basis Swaps [Member]	'	'
Derivative [Line Items]	'	'
Net Long (Short) Position (MMBtu), 2013	'	9,690,000
Net Long (Short) Position (MMBtu), 2014	21,415,000	-1,350,000
Net Long (Short) Position (MMBtu), 2015	1,875,000	0
Net Long (Short) Position (MMBtu), 2016	0	0

Partnership_Equity_and_Distrib2

Partnership Equity and Distributions - Additional Information (Detail) (USD $)

0 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

1 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

In Millions, except Share data, unless otherwise specified

Mar. 14, 2013

Jul. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Mar. 31, 2012

Feb. 29, 2012

Mar. 31, 2011

Feb. 28, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Nov. 27, 2012

Dec. 31, 2013

Mar. 28, 2013

Mar. 31, 2013

Nov. 30, 2012

Mar. 31, 2014

Dec. 31, 2013

Mar. 14, 2013

Dec. 31, 2012

Jul. 31, 2012

Mar. 31, 2012

Mar. 13, 2012

Feb. 29, 2012

Jan. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2011

Aug. 31, 2013

Mar. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jun. 30, 2013

Distribution Stage First [Member]

Distribution Stage Second [Member]

Distribution Stage Third [Member]

Distribution Stage Thereafter [Member]

Senior Notes, 2.50% Due 2017 [Member]

Senior Notes, 2.50% Due 2017 [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Mont Belvieu Fractionators [Member]

Southeast Texas [Member]

Southeast Texas [Member]

Southeast Texas [Member]

East Texas System [Member]

General Partner [Member]

2011 Equity Distribution Agreement [Member]

2011 Equity Distribution Agreement [Member]

Limited Partners [Member]

Limited Partners [Member]

Limited Partners [Member]

2013 Equity Distribution Agreement [Member]

2013 Equity Distribution Agreement [Member]

Eagle Ford System [Member]

Partnership Equity And Distribution [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common units issued

'

'

89,045,139

61,346,058

5,148,500

30,701

3,596,636

8,399

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,408,547

'

9,000,000

12,650,000

'

1,839,430

'

Proceeds from issuance of common stock

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$67

'

'

'

'

$87

'

Offering costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

1

'

Maximum aggregate offering amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

150

'

'

'

212

'

Price per common unit

'

'

'

'

$47.42

'

$40.55

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$50.04

$40.63

'

'

'

Net proceeds

'

'

'

'

234

'

140

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

434

494

'

'

'

Offer value of common stock remaining available for sale

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300

Consideration financed through issuance of common units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,789,739

2,789,739

1,912,663

'

'

'

'

1,536,098

1,000,417

'

'

727,520

'

'

'

'

'

'

'

'

Ownership interest acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

46.67%

46.67%

33.33%

20.00%

46.67%

46.67%

33.33%

'

66.67%

66.67%

33.33%

49.90%

'

'

'

'

'

33.33%

'

'

Units sold in private placement

'

4,989,802

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Units Sold Under private placement price per unit

'

$35.55

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of private placement

'

$174

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior notes interest rate percentage

3.88%

'

'

'

'

'

'

'

'

'

'

'

2.50%

2.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Term of outstanding debt

'10 years

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partnership deadline for distributions (in days)

'

'

'45 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General partner ownership interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.00%

'

'

'

'

'

'

'

Limited partner ownership interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.00%

'

'

'

'

'

'

'

Distribution unitholders and general partner per unit

'

'

'

'

'

'

'

'

$0.40

$0.44

$0.53

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum distribution level percentage

'

'

'

'

'

'

'

'

'

13.00%

23.00%

48.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Partnership_Equity_and_Distrib3

Partnership Equity and Distributions - Cash Distribution (Detail) (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Partnership Equity And Distribution [Line Items]	'	'	'
Total Cash Distribution (Millions)	$277	$181	$132
November 14, 2013 [Member]	'	'	'
Partnership Equity And Distribution [Line Items]	'	'	'
Per Unit Distribution	$0.72	'	'
Total Cash Distribution (Millions)	82	'	'
August 14, 2013 [Member]	'	'	'
Partnership Equity And Distribution [Line Items]	'	'	'
Per Unit Distribution	$0.71	'	'
Total Cash Distribution (Millions)	72	'	'
May 15, 2013 [Member]	'	'	'
Partnership Equity And Distribution [Line Items]	'	'	'
Per Unit Distribution	$0.70	'	'
Total Cash Distribution (Millions)	69	'	'
February 14, 2013 [Member]	'	'	'
Partnership Equity And Distribution [Line Items]	'	'	'
Per Unit Distribution	$0.69	'	'
Total Cash Distribution (Millions)	54	'	'
November 14, 2012 [Member]	'	'	'
Partnership Equity And Distribution [Line Items]	'	'	'
Per Unit Distribution	$0.68	'	'
Total Cash Distribution (Millions)	53	'	'
August 14, 2012 [Member]	'	'	'
Partnership Equity And Distribution [Line Items]	'	'	'
Per Unit Distribution	$0.67	'	'
Total Cash Distribution (Millions)	49	'	'
May 15, 2012 [Member]	'	'	'
Partnership Equity And Distribution [Line Items]	'	'	'
Per Unit Distribution	$0.66	'	'
Total Cash Distribution (Millions)	43	'	'
February 14, 2012 [Member]	'	'	'
Partnership Equity And Distribution [Line Items]	'	'	'
Per Unit Distribution	$0.65	'	'
Total Cash Distribution (Millions)	37	'	'
November 14, 2011 [Member]	'	'	'
Partnership Equity And Distribution [Line Items]	'	'	'
Per Unit Distribution	$0.64	'	'
Total Cash Distribution (Millions)	35	'	'
August 12, 2011 [Member]	'	'	'
Partnership Equity And Distribution [Line Items]	'	'	'
Per Unit Distribution	$0.63	'	'
Total Cash Distribution (Millions)	34	'	'
May 13, 2011 [Member]	'	'	'
Partnership Equity And Distribution [Line Items]	'	'	'
Per Unit Distribution	$0.63	'	'
Total Cash Distribution (Millions)	33	'	'
February 14, 2011 [Member]	'	'	'
Partnership Equity And Distribution [Line Items]	'	'	'
Per Unit Distribution	$0.62	'	'
Total Cash Distribution (Millions)	$30	'	'

EquityBased_Compensation_Total

Equity-Based Compensation (Total Compensation Cost for Equity-Based Arrangements) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Compensation cost	$2	$2	$7
Performance Phantom Units [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Compensation cost	1	1	5
Phantom Units [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Compensation cost	0	0	0
Restricted Phantom Units [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Compensation cost	$1	$1	$2

EquityBased_Compensation_Narra

Equity-Based Compensation (Narrative) (Detail) (USD $)

Dec. 31, 2013

Feb. 18, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

In Millions, except Share data, unless otherwise specified

Performance Phantom Units [Member]

Performance Phantom Units [Member]

Performance Phantom Units [Member]

Performance Phantom Units [Member]

Performance Phantom Units [Member]

Performance Phantom Units [Member]

Restricted Phantom Units [Member]

Restricted Phantom Units [Member]

Restricted Phantom Units [Member]

Restricted Phantom Units [Member]

Restricted Phantom Units [Member]

Phantom Units [Member]

Phantom Units [Member]

Phantom Units [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Maximum [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Expected To Vest 2014 [Member]

Expected To Vest 2015 [Member]

Subsequent Event [Member]

Expected To Vest 2014 [Member]

Expected To Vest 2015 [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum limited partner units that may be issued pursuant to awards under the 2005 LTIP

850,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reclassification of share-based compensation liability to additional paid-in capital

'

$2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Performance Units to be vested over three years

'

'

'

'

'

'

'

200.00%

'

'

'

'

'

'

'

'

Expected to vest units

'

'

12,960

[1]

'

'

2,070

10,890

'

13,351

'

'

2,070

11,281

'

'

'

Unrecognized compensation expense

'

'

$1

'

'

'

'

'

$1

'

'

'

'

'

'

'

Weighted average period for the recognition of the unrecognized compensation costs, in years

'

'

'

'

'

'

'

'2 years

'2 years

'

'

'

'

'

'

'

Granted units

'

'

11,450

11,740

[2]

10,580

'

'

'

11,590

11,740

[2]

10,580

'

'

4,400

4,000

4,000

Estimated forfeiture rate

'

'

10.00%

'

'

'

'

'

10.00%

10.00%

'

'

'

'

'

'

[1]

Based on our December 31, 2013 estimated achievement of specified performance targets, the performance estimate for units granted in both 2013 and 2012 is 100%. The estimated forfeiture rate for units granted in both 2013 and 2012 is 10%.

[2]

Includes the impact of conversion of the underlying securities, in connection with Phillip 66's separation from ConocoPhillips, granted under the 2012 LTIP.

EquityBased_Compensation_Discl

Equity-Based Compensation (Disclosure of Share-Based Compensation Arrangements by Share-Based Payment Award) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Performance Phantom Units [Member]	'		'		'
Units	'		'		'
Outstanding, beginning balance units	11,090		27,210		67,350
Granted units	11,450		11,740	[1]	10,580
Vested units	-3,800	[2]	-20,100		-50,720
Forfeited units	-4,990		-7,760		0
Outstanding ending balance units	13,750		11,090		27,210
Expected to vest units	12,960	[3]	'		'
Grant Date Weighted- Average Price per Unit	'		'		'
Outstanding, Beginning Balance (dollars per share)	$39.24		$35.69		$15.42
Granted (dollars per share)	$40.88		$39.31	[1]	$41.80
Vested (dollars per share)	$40.75	[2]	$34.57		$10.05
Forfeited (dollars per share)	$38.77		$38.97		$0
Outstanding, Ending Balance (dollars per share)	$40.36		$39.24		$35.69
Expected to vest grant date weighted average price per unit	$40.38	[3]	'		'
Measurement date price per unit, period end	$50.33		'		'
Measurement date price per unit, expected to vest	$50.33	[3]	'		'
Phantom Units [Member]	'		'		'
Units	'		'		'
Outstanding, beginning balance units	0		0		0
Granted units	4,400		4,000		4,000
Vested units	-4,400		-4,000		-4,000
Outstanding ending balance units	0		0		0
Grant Date Weighted- Average Price per Unit	'		'		'
Outstanding, Beginning Balance (dollars per share)	$0		$0		$0
Granted (dollars per share)	$46.39		$48.03		$41.80
Vested (dollars per share)	$46.39		$48.03		$41.80
Outstanding, Ending Balance (dollars per share)	$0		$0		$0
Measurement date price per unit, period end	$0		'		'
Restricted Phantom Units [Member]	'		'		'
Units	'		'		'
Outstanding, beginning balance units	4,250		19,330		67,350
Granted units	11,590		11,740	[1]	10,580
Vested units	-1,950		-19,060		-58,600
Forfeited units	0		-7,760		0
Outstanding ending balance units	13,890		4,250		19,330
Expected to vest units	13,351		'		'
Grant Date Weighted- Average Price per Unit	'		'		'
Outstanding, Beginning Balance (dollars per share)	$39.63		$37.27		$15.42
Granted (dollars per share)	$41.94		$39.31	[1]	$41.80
Vested (dollars per share)	$41.80		$37.31		$12.97
Forfeited (dollars per share)	$0		$43.27		$0
Outstanding, Ending Balance (dollars per share)	$41.25		$39.63		$37.27
Expected to vest grant date weighted average price per unit	$41.38		'		'
Measurement date price per unit, period end	$50.33		'		'
Measurement date price per unit, expected to vest	$50.30		'		'
[1]	Includes the impact of conversion of the underlying securities, in connection with Phillip 66's separation from ConocoPhillips, granted under the 2012 LTIP.
[2]	The units vested at 150%.
[3]	Based on our December 31, 2013 estimated achievement of specified performance targets, the performance estimate for units granted in both 2013 and 2012 is 100%. The estimated forfeiture rate for units granted in both 2013 and 2012 is 10%.

EquityBased_Compensation_Discl1

Equity-Based Compensation (Disclosure of Share-Based Compensation Arrangements by Share-Based Payment Award) (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Performance Phantom Units [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Percentage of units vested	150.00%	'
Performance estimate for units granted	100.00%	100.00%
Estimated forfeiture rate	10.00%	'
Performance Units [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Estimated forfeiture rate	'	10.00%
Restricted Phantom Units [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Estimated forfeiture rate	10.00%	10.00%

EquityBased_Compensation_Fair_

Equity-Based Compensation (Fair Value of Units Vested and Unit-Based Liabilities Paid for Unit Based Awards) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Performance Phantom Units [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Fair value of units vested	$1	$1	$5
Unit-based liabilities paid	1	5	0
Phantom Units [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Fair value of units vested	1	1	1
Restricted Phantom Units [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Fair value of units vested	1	1	3
Unit-based liabilities paid	1	2	1
Maximum [Member] | Performance Phantom Units [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Fair value of units vested	1	'	'
Maximum [Member] | Restricted Phantom Units [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Fair value of units vested	$1	'	'

Net_Income_or_Loss_per_Limited1

Net Income or Loss per Limited Partner Unit - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Earnings Per Share [Abstract]	'	'	'
Weighted Average Number Diluted Limited Partnership Units Outstanding Adjustment	19,179	33,043	64,286

Income_Taxes_Narrative_Detail

Income Taxes (Narrative) (Detail) (USD $)

12 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2011

Jan. 04, 2011

Dec. 30, 2010

Dec. 31, 2011

Texas Express NGL [Member]

Texas Express NGL [Member]

Texas Express NGL [Member]

Taxable Income [Member]

Tax Surcharge [Member]

Marysville Acquisition [Member]

Marysville Acquisition [Member]

Marysville Acquisition [Member]

Gross Receipts [Member]

Michigan [Member]

Michigan [Member]

Michigan [Member]

Income Taxes [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Deferred tax liabilities from acquisition

'

'

'

'

'

'

'

'

'

'

$35

'

Taxes Payable, Current

'

'

'

'

'

'

'

'

5

35

'

'

Income Taxes Paid

'

'

'

'

'

'

'

'

29

'

'

'

Current, state income tax expense

3

1

2

'

'

'

'

'

1

'

'

'

Texas Margin Tax Rate

'

'

'

0.98%

1.00%

1.00%

'

'

'

'

'

'

Michigan Business Tax

'

'

'

'

'

'

4.95%

21.99%

'

'

'

0.80%

Net long-term deferred tax liabilities

$11

$6

'

'

'

'

'

'

'

'

'

'

Income_Taxes_Components_of_Inc

Income Taxes (Components of Income Tax Benefit (Expense)) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Income Tax Disclosure [Abstract]	'		'		'
Current, federal income tax expense	$0		$0		($29)
Current, state income tax expense	-3		-1		-2
Deferred, federal income tax benefit expense	0		0		29
Deferred, state income tax (expense) benefit	-5		0		1
Income tax expense	($8)	[1],[2]	($1)	[1],[3]	($1)	[1],[4]
[1]	For the year ended December 31, 2011, income tax expense relates primarily to the Texas margin tax and the Michigan business tax. The Michigan business tax was repealed in 2012; accordingly, income tax expense for the years ended December 31, 2013 and 2012 relates primarily to the Texas margin tax.
[2]	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[3]	The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[4]	The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Commitments_and_Contingent_Lia2

Commitments and Contingent Liabilities - Additional Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Commitments and Contingencies Disclosure [Abstract]	'	'	'
Rent expense	$17	$14	$15
2014	16	'	'
2015	14	'	'
2016	12	'	'
2017	10	'	'
2018	9	'	'
Thereafter	33	'	'
Total minimum rental payments	$94	'	'

Business_Segments_Additional_I

Business Segments - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2013
	Project
	Segment
Segment Reporting Information [Line Items]	'
Number of reporting segments	3
Ownership interest percentage	100.00%
Number of owned and operated rail terminals	6
Number of owned marine import terminals	1
Number of leased marine terminals	1
Number of pipeline and several open access pipeline terminals	1
Eagle Ford System [Member]	'
Segment Reporting Information [Line Items]	'
Ownership interest percentage	80.00%
Eagle Plant [Member]	'
Segment Reporting Information [Line Items]	'
Ownership interest percentage	100.00%
Colorado [Member]	'
Segment Reporting Information [Line Items]	'
Ownership interest percentage	75.00%
Discovery Producer Services LLC [Member]	'
Segment Reporting Information [Line Items]	'
Ownership interest percentage	40.00%
Mont Belvieu 1 Fractionator [Member]	'
Segment Reporting Information [Line Items]	'
Ownership interest percentage	20.00%
Mont Belvieu Enterprise Fractionator [Member]	'
Segment Reporting Information [Line Items]	'
Ownership interest percentage	12.50%
Front Range Pipeline [Member]	'
Segment Reporting Information [Line Items]	'
Ownership interest percentage	33.33%
Texas Express [Member]	'
Segment Reporting Information [Line Items]	'
Ownership interest percentage in subsidiary	10.00%

Business_Segments_Segment_Info

Business Segments - Segment Information (Detail) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Total operating revenues

'

$821

$689

$792

$749

$671

$618

$680

$855

$3,051

[1]

$2,824

[2]

$3,790

[3]

Gross margin

'

'

'

'

'

'

'

'

'

625

[4]

609

[4]

635

[4]

Operating and maintenance expense

'

'

'

'

'

'

'

'

'

-215

[1]

-197

[2]

-192

[3]

Depreciation and amortization expense

'

'

'

'

'

'

'

'

'

-95

[1]

-91

[2]

-135

[3]

General and administrative expense

'

'

'

'

'

'

'

'

'

-63

[1]

-75

[2]

-76

[3]

Other expense

'

'

'

'

'

'

'

'

'

-8

'

'

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

'

33

[1]

26

[2]

23

[3]

Other operating income

'

'

'

'

'

'

'

'

'

-8

[1]

0

1

[3]

Interest expense

'

'

'

'

'

'

'

'

'

-52

[1]

-42

[2]

-34

[3]

Income tax expense

'

'

'

'

'

'

'

'

'

-8

[1],[5]

-1

[2],[5]

-1

[3],[5]

Net income

'

40

6

111

60

81

14

90

44

217

[1]

229

[2]

221

[3]

Net income attributable to noncontrolling interests

'

-7

-3

-4

-3

-5

-2

-2

-4

-17

[1]

-13

[2]

-30

[3]

Net income attributable to partners

'

33

3

107

57

76

12

88

40

200

[1]

216

[2]

191

[3]

Non-cash derivative mark-to-market

'

'

'

'

'

'

'

'

'

-36

[6]

21

[6]

40

[6]

Non-cash lower of cost or market adjustments

'

'

'

'

'

'

'

'

'

4

19

'

Capital expenditures

63

'

'

'

101

'

'

'

'

363

[1]

484

[7]

385

Acquisitions net of cash acquired

'

'

'

'

'

'

'

'

'

782

745

152

Investments in unconsolidated affiliates

65

'

'

'

26

'

'

'

'

242

[1]

158

[7]

8

Total long-term assets

'

4,064

'

'

'

3,277

'

'

'

4,064

3,277

2,582

Current assets

'

503

[8]

'

'

'

368

[8],[9]

'

'

'

503

[8]

368

[8],[9]

373

[8]

Total assets

'

4,567

'

'

'

3,645

[9]

'

'

'

4,567

3,645

[9]

2,955

Natural Gas Services [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Total operating revenues

'

'

'

'

'

'

'

'

'

2,598

[8]

2,345

[8]

3,102

[8]

Gross margin

'

'

'

'

'

'

'

'

'

501

[4],[8]

503

[4],[8]

532

[4],[8]

Operating and maintenance expense

'

'

'

'

'

'

'

'

'

-184

[8]

-166

[8]

-161

[8]

Depreciation and amortization expense

'

'

'

'

'

'

'

'

'

-87

[8]

-83

[8]

-124

[8]

General and administrative expense

'

'

'

'

'

'

'

'

'

0

[8]

0

[8]

0

[8]

Other expense

'

'

'

'

'

'

'

'

'

-1

[8]

'

'

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

'

1

[8]

15

[8]

23

[8]

Other operating income

'

'

'

'

'

'

'

'

'

'

'

0

[8]

Interest expense

'

'

'

'

'

'

'

'

'

0

[8]

0

[8]

0

[8]

Income tax expense

'

'

'

'

'

'

'

'

'

0

[5],[8]

0

[5],[8]

0

[5],[8]

Net income

'

'

'

'

'

'

'

'

'

230

[8]

269

[8]

270

[8]

Net income attributable to noncontrolling interests

'

'

'

'

'

'

'

'

'

-17

[8]

-13

[8]

-30

[8]

Net income attributable to partners

'

'

'

'

'

'

'

'

'

213

[8]

256

[8]

240

[8]

Non-cash derivative mark-to-market

'

'

'

'

'

'

'

'

'

-36

[6],[8]

20

[6],[8]

42

[6],[8]

Non-cash lower of cost or market adjustments

'

'

'

'

'

'

'

'

'

2

[8]

'

'

Capital expenditures

'

'

'

'

'

'

'

'

'

334

[8]

468

[8]

372

[8]

Acquisitions net of cash acquired

'

'

'

'

'

'

'

'

'

696

[8]

715

[8]

122

[8]

Investments in unconsolidated affiliates

'

'

'

'

'

'

'

'

'

133

[8]

115

[8]

8

[8]

Total long-term assets

'

3,303

[8]

'

'

'

2,748

[8]

'

'

'

3,303

[8]

2,748

[8]

2,214

[8]

NGL Logistics [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Total operating revenues

'

'

'

'

'

'

'

'

'

73

64

57

Gross margin

'

'

'

'

'

'

'

'

'

72

[4]

64

[4]

52

[4]

Operating and maintenance expense

'

'

'

'

'

'

'

'

'

-16

-16

-16

Depreciation and amortization expense

'

'

'

'

'

'

'

'

'

-6

-6

-8

General and administrative expense

'

'

'

'

'

'

'

'

'

0

0

0

Other expense

'

'

'

'

'

'

'

'

'

-3

'

'

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

'

32

11

0

Other operating income

'

'

'

'

'

'

'

'

'

'

'

1

Interest expense

'

'

'

'

'

'

'

'

'

0

0

0

Income tax expense

'

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Net income

'

'

'

'

'

'

'

'

'

79

53

29

Net income attributable to noncontrolling interests

'

'

'

'

'

'

'

'

'

0

0

0

Net income attributable to partners

'

'

'

'

'

'

'

'

'

79

53

29

Non-cash derivative mark-to-market

'

'

'

'

'

'

'

'

'

0

[6]

0

[6]

0

[6]

Non-cash lower of cost or market adjustments

'

'

'

'

'

'

'

'

'

0

'

'

Capital expenditures

'

'

'

'

'

'

'

'

'

24

12

9

Acquisitions net of cash acquired

'

'

'

'

'

'

'

'

'

86

30

30

Investments in unconsolidated affiliates

'

'

'

'

'

'

'

'

'

109

43

0

Total long-term assets

'

555

'

'

'

340

'

'

'

555

340

250

Wholesale Propane Logistics [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Total operating revenues

'

'

'

'

'

'

'

'

'

380

415

633

Gross margin

'

'

'

'

'

'

'

'

'

52

[4]

42

[4]

51

[4]

Operating and maintenance expense

'

'

'

'

'

'

'

'

'

-15

-15

-15

Depreciation and amortization expense

'

'

'

'

'

'

'

'

'

-2

-2

-3

General and administrative expense

'

'

'

'

'

'

'

'

'

0

0

0

Other expense

'

'

'

'

'

'

'

'

'

-4

'

'

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

'

0

0

0

Other operating income

'

'

'

'

'

'

'

'

'

'

'

0

Interest expense

'

'

'

'

'

'

'

'

'

0

0

0

Income tax expense

'

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Net income

'

'

'

'

'

'

'

'

'

31

25

33

Net income attributable to noncontrolling interests

'

'

'

'

'

'

'

'

'

0

0

0

Net income attributable to partners

'

'

'

'

'

'

'

'

'

31

25

33

Non-cash derivative mark-to-market

'

'

'

'

'

'

'

'

'

-1

[6]

1

[6]

0

[6]

Non-cash lower of cost or market adjustments

'

'

'

'

'

'

'

'

'

2

'

'

Capital expenditures

'

'

'

'

'

'

'

'

'

5

4

4

Acquisitions net of cash acquired

'

'

'

'

'

'

'

'

'

0

0

0

Investments in unconsolidated affiliates

'

'

'

'

'

'

'

'

'

0

0

0

Total long-term assets

'

106

'

'

'

105

'

'

'

106

105

104

Other [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Total operating revenues

'

'

'

'

'

'

'

'

'

0

0

0

Gross margin

'

'

'

'

'

'

'

'

'

0

[4]

0

[4]

0

[4]

Operating and maintenance expense

'

'

'

'

'

'

'

'

'

0

0

0

Depreciation and amortization expense

'

'

'

'

'

'

'

'

'

0

0

0

General and administrative expense

'

'

'

'

'

'

'

'

'

-63

-75

-76

Other expense

'

'

'

'

'

'

'

'

'

0

'

'

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

'

0

0

0

Other operating income

'

'

'

'

'

'

'

'

'

'

'

0

Interest expense

'

'

'

'

'

'

'

'

'

-52

-42

-34

Income tax expense

'

'

'

'

'

'

'

'

'

-8

[5]

-1

[5]

-1

[5]

Net income

'

'

'

'

'

'

'

'

'

-123

-118

-111

Net income attributable to noncontrolling interests

'

'

'

'

'

'

'

'

'

0

0

0

Net income attributable to partners

'

'

'

'

'

'

'

'

'

-123

-118

-111

Non-cash derivative mark-to-market

'

'

'

'

'

'

'

'

'

1

[6]

0

[6]

-2

[6]

Non-cash lower of cost or market adjustments

'

'

'

'

'

'

'

'

'

'

'

'

Capital expenditures

'

'

'

'

'

'

'

'

'

0

0

0

Acquisitions net of cash acquired

'

'

'

'

'

'

'

'

'

0

0

0

Investments in unconsolidated affiliates

'

'

'

'

'

'

'

'

'

0

0

0

Total long-term assets

'

100

[10]

'

'

'

84

[10]

'

'

'

100

[10]

84

[10]

14

[10]

Eliminations [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Total operating revenues

'

'

'

'

'

'

'

'

'

'

'

-2

[11]

Gross margin

'

'

'

'

'

'

'

'

'

'

'

0

[11],[4]

Operating and maintenance expense

'

'

'

'

'

'

'

'

'

'

'

0

[11]

Depreciation and amortization expense

'

'

'

'

'

'

'

'

'

'

'

0

[11]

General and administrative expense

'

'

'

'

'

'

'

'

'

'

'

0

[11]

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

'

'

'

0

[11]

Other operating income

'

'

'

'

'

'

'

'

'

'

'

0

[11]

Interest expense

'

'

'

'

'

'

'

'

'

'

'

0

[11]

Income tax expense

'

'

'

'

'

'

'

'

'

'

'

0

[11],[5]

Net income

'

'

'

'

'

'

'

'

'

'

'

0

[11]

Net income attributable to noncontrolling interests

'

'

'

'

'

'

'

'

'

'

'

0

[11]

Net income attributable to partners

'

'

'

'

'

'

'

'

'

'

'

0

[11]

Non-cash derivative mark-to-market

'

'

'

'

'

'

'

'

'

'

'

0

[11],[6]

Capital expenditures

'

'

'

'

'

'

'

'

'

'

'

0

[11]

Acquisitions net of cash acquired

'

'

'

'

'

'

'

'

'

'

'

0

[11]

Investments in unconsolidated affiliates

'

'

'

'

'

'

'

'

'

'

'

$0

[11]

[1]

The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[2]

The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[3]

The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[4]

Gross margin consists of total operating revenues, including commodity derivative activity, less purchases of natural gas, propane and NGLs. Gross margin is viewed as a non-GAAP measure under the rules of the SEC, but is included as a supplemental disclosure because it is a primary performance measure used by management as it represents the results of product sales versus product purchases. As an indicator of our operating performance, gross margin should not be considered an alternative to, or more meaningful than, net income or cash flow as determined in accordance with GAAP. Our gross margin may not be comparable to a similarly titled measure of another company because other entities may not calculate gross margin in the same manner.

[5]

For the year ended December 31, 2011, income tax expense relates primarily to the Texas margin tax and the Michigan business tax. The Michigan business tax was repealed in 2012; accordingly, income tax expense for the years ended December 31, 2013 and 2012 relates primarily to the Texas margin tax.

[6]

Non-cash commodity derivative mark-to-market is included in segment gross margin, along with cash settlements for our commodity derivative contracts.

[7]

The financial information during the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[8]

The segment information as of and for the years ended December 31, 2013, 2012 and 2011, includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas. Transfers of net assets between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information, similar to the pooling method.

[9]

The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[10]

Other long-term assets not allocable to segments consist of unrealized gains on derivative instruments, corporate leasehold improvements and other long-term assets.

[11]

Represents intersegment revenues consisting of sales of NGLs by Marysville in our NGL Logistics segment to our Wholesale Propane Logistics segment.

Business_Segments_Segment_Info1

Business Segments - Segment Information (Parenthetical) (Detail)	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]	'	'
Ownership interest percentage	100.00%	'
Southeast Texas [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Ownership interest percentage	'	100.00%
Affiliated Entity [Member] | Eagle Ford System [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Ownership interest percentage	80.00%	80.00%

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information - Summary of Supplemental Cash Flow Information (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Supplemental Cash Flow Elements [Abstract]	'	'	'
Cash paid for interest, net of amounts capitalized	$40	$23	$17
Cash paid for income taxes, net of income tax refunds	1	1	30
Property, plant and equipment acquired with accounts payable	27	47	34
Other non-cash additions of property, plant and equipment	1	8	3
Non-cash change in parent advances	0	-115	5
Accounts payable related to equity issuance costs	$1	$0	$0

Quarterly_Financial_Data_Unaud2

Quarterly Financial Data (Unaudited) (Schedule of Quarterly Consolidated Results of Operations) (Detail) (USD $)	3 Months Ended								12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Quarterly Financial Information Disclosure [Abstract]	'	'	'	'	'	'	'	'	'		'		'
Total operating revenues	$821	$689	$792	$749	$671	$618	$680	$855	$3,051	[1]	$2,824	[2]	$3,790	[3]
Operating income	48	14	117	65	82	13	99	52	244	[1]	246	[2]	233	[3]
Net income	40	6	111	60	81	14	90	44	217	[1]	229	[2]	221	[3]
Net income attributable to noncontrolling interests	-7	-3	-4	-3	-5	-2	-2	-4	-17	[1]	-13	[2]	-30	[3]
Net income attributable to partners	33	3	107	57	76	12	88	40	200	[1]	216	[2]	191	[3]
Net income (loss) allocable to limited partners	$8	($20)	$86	$31	$52	($9)	$69	$12	$105		$124		$75
Basic net income (loss) per limited partner unit (in dollars per share)	$0.09	($0.24)	$1.11	$0.48	$0.87	($0.16)	$1.33	$0.26	$1.34		$2.28		$1.73
[1]	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[2]	The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[3]	The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Supplementary_Information_Cond2

Supplementary Information - Condensed Consolidating Financial Information - Additional Information (Detail) (Parent Guarantor [Member])	12 Months Ended
	Dec. 31, 2013
Parent Guarantor [Member]	'
Parent Company Only Financial Information [Line Items]	'
Ownership percentage	100.00%

Supplementary_Information_Cond3

Supplementary Information - Condensed Consolidating Financial Information - Condensed Consolidating Balance Sheets (Detail) (USD $)	Mar. 31, 2014	Dec. 31, 2013		Mar. 31, 2013	Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
In Millions, unless otherwise specified
ASSETS	'	'		'	'		'		'
Cash and cash equivalents	$27	$12	[1]	$37	$2	[1],[2],[3]	$8	[2]	$7
Accounts receivable, net	'	342		'	239	[3]	'		'
Inventories	'	67		'	76	[3]	'		'
Other	'	82		'	51	[3]	'		'
Total current assets	'	503	[4]	'	368	[3],[4]	373	[4]	'
Property, plant and equipment, net	'	3,046		'	2,592	[3]	'		'
Goodwill and intangible assets, net	'	283		'	291	[3]	'		'
Advances receivable - consolidated subsidiaries	'	0		'	0	[3]	'		'
Investments in consolidated subsidiaries	'	0		'	0	[3]	'		'
Investments in unconsolidated affiliates	'	627		'	304	[3]	'		'
Other long-term assets	'	108		'	90	[3]	'		'
Total assets	'	4,567		'	3,645	[3]	2,955		'
LIABILITIES AND EQUITY	'	'		'	'		'		'
Accounts payable and other current liabilities	'	723		'	345	[3]	'		'
Advances payable - consolidated subsidiaries	'	0		'	0	[3]	'		'
Long-term debt	'	1,590		'	1,620	[3]	'		'
Other long-term liabilities	'	41		'	44	[3]	'		'
Total liabilities	'	2,354		'	2,009	[3]	'		'
Commitments and contingent liabilities	'	'		'	'		'		'
Equity:	'	'		'	'		'		'
Predecessor equity	'	40	[3]	'	399	[3]	'		'
Net equity	'	1,956		'	1,063	[3]	'		'
Accumulated other comprehensive loss	'	-11		'	-15	[3]	'		'
Total partners' equity	'	1,985		'	1,447	[3]	'		'
Noncontrolling interests	'	228		'	189	[3]	'		'
Total equity	'	2,213		'	1,636	[3]	1,605		1,460
Total liabilities and equity	'	4,567		'	3,645	[3]	'		'
Parent Guarantor [Member]	'	'		'	'		'		'
ASSETS	'	'		'	'		'		'
Cash and cash equivalents	0	0	[1]	0	0	[1],[2],[3]	0	[2]	0
Accounts receivable, net	'	0		'	0	[3]	'		'
Inventories	'	0		'	0	[3]	'		'
Other	'	0		'	0	[3]	'		'
Total current assets	'	0		'	0	[3]	'		'
Property, plant and equipment, net	'	0		'	0	[3]	'		'
Goodwill and intangible assets, net	'	0		'	0	[3]	'		'
Advances receivable - consolidated subsidiaries	'	1,805		'	873	[3]	'		'
Investments in consolidated subsidiaries	'	181		'	574	[3]	'		'
Investments in unconsolidated affiliates	'	0		'	0	[3]	'		'
Other long-term assets	'	0		'	0	[3]	'		'
Total assets	'	1,986		'	1,447	[3]	'		'
LIABILITIES AND EQUITY	'	'		'	'		'		'
Accounts payable and other current liabilities	'	1		'	0	[3]	'		'
Advances payable - consolidated subsidiaries	'	0		'	0	[3]	'		'
Long-term debt	'	0		'	0	[3]	'		'
Other long-term liabilities	'	0		'	0	[3]	'		'
Total liabilities	'	1		'	0	[3]	'		'
Commitments and contingent liabilities	'	'		'	'		'		'
Equity:	'	'		'	'		'		'
Predecessor equity	'	0	[3]	'	0	[3]	'		'
Net equity	'	1,985		'	1,447	[3]	'		'
Accumulated other comprehensive loss	'	0		'	0	[3]	'		'
Total partners' equity	'	1,985		'	1,447	[3]	'		'
Noncontrolling interests	'	0		'	0	[3]	'		'
Total equity	'	1,985		'	1,447	[3]	'		'
Total liabilities and equity	'	1,986		'	1,447	[3]	'		'
Subsidiary Issuer [Member]	'	'		'	'		'		'
ASSETS	'	'		'	'		'		'
Cash and cash equivalents	23	0	[1]	45	3	[1],[2],[3]	4	[2]	2
Accounts receivable, net	'	0		'	0	[3]	'		'
Inventories	'	0		'	0	[3]	'		'
Other	'	0		'	0	[3]	'		'
Total current assets	'	0		'	3	[3]	'		'
Property, plant and equipment, net	'	0		'	0	[3]	'		'
Goodwill and intangible assets, net	'	0		'	0	[3]	'		'
Advances receivable - consolidated subsidiaries	'	1,683		'	1,424	[3]	'		'
Investments in consolidated subsidiaries	'	426		'	770	[3]	'		'
Investments in unconsolidated affiliates	'	0		'	0	[3]	'		'
Other long-term assets	'	12		'	11	[3]	'		'
Total assets	'	2,121		'	2,208	[3]	'		'
LIABILITIES AND EQUITY	'	'		'	'		'		'
Accounts payable and other current liabilities	'	350		'	12	[3]	'		'
Advances payable - consolidated subsidiaries	'	0		'	0	[3]	'		'
Long-term debt	'	1,590		'	1,620	[3]	'		'
Other long-term liabilities	'	0		'	2	[3]	'		'
Total liabilities	'	1,940		'	1,634	[3]	'		'
Commitments and contingent liabilities	'	'		'	'		'		'
Equity:	'	'		'	'		'		'
Predecessor equity	'	0	[3]	'	0	[3]	'		'
Net equity	'	187		'	584	[3]	'		'
Accumulated other comprehensive loss	'	-6		'	-10	[3]	'		'
Total partners' equity	'	181		'	574	[3]	'		'
Noncontrolling interests	'	0		'	0	[3]	'		'
Total equity	'	181		'	574	[3]	'		'
Total liabilities and equity	'	2,121		'	2,208	[3]	'		'
Non-Guarantor Subsidiaries [Member]	'	'		'	'		'		'
ASSETS	'	'		'	'		'		'
Cash and cash equivalents	4	12	[1]	1	2	[1],[2],[3]	6	[2]	7
Accounts receivable, net	'	342		'	239	[3]	'		'
Inventories	'	67		'	76	[3]	'		'
Other	'	82		'	51	[3]	'		'
Total current assets	'	503		'	368	[3]	'		'
Property, plant and equipment, net	'	3,046		'	2,592	[3]	'		'
Goodwill and intangible assets, net	'	283		'	291	[3]	'		'
Advances receivable - consolidated subsidiaries	'	0		'	0	[3]	'		'
Investments in consolidated subsidiaries	'	0		'	0	[3]	'		'
Investments in unconsolidated affiliates	'	627		'	304	[3]	'		'
Other long-term assets	'	96		'	79	[3]	'		'
Total assets	'	4,555		'	3,634	[3]	'		'
LIABILITIES AND EQUITY	'	'		'	'		'		'
Accounts payable and other current liabilities	'	372		'	336	[3]	'		'
Advances payable - consolidated subsidiaries	'	3,488		'	2,297	[3]	'		'
Long-term debt	'	0		'	0	[3]	'		'
Other long-term liabilities	'	41		'	42	[3]	'		'
Total liabilities	'	3,901		'	2,675	[3]	'		'
Commitments and contingent liabilities	'	'		'	'		'		'
Equity:	'	'		'	'		'		'
Predecessor equity	'	40	[3]	'	399	[3]	'		'
Net equity	'	391		'	376	[3]	'		'
Accumulated other comprehensive loss	'	-5		'	-5	[3]	'		'
Total partners' equity	'	426		'	770	[3]	'		'
Noncontrolling interests	'	228		'	189	[3]	'		'
Total equity	'	654		'	959	[3]	'		'
Total liabilities and equity	'	4,555		'	3,634	[3]	'		'
Consolidating Adjustments [Member]	'	'		'	'		'		'
ASSETS	'	'		'	'		'		'
Cash and cash equivalents	0	0	[1]	-9	-3	[1],[2],[3]	-2	[2]	-2
Accounts receivable, net	'	0		'	0	[3]	'		'
Inventories	'	0		'	0	[3]	'		'
Other	'	0		'	0	[3]	'		'
Total current assets	'	0		'	-3	[3]	'		'
Property, plant and equipment, net	'	0		'	0	[3]	'		'
Goodwill and intangible assets, net	'	0		'	0	[3]	'		'
Advances receivable - consolidated subsidiaries	'	-3,488		'	-2,297	[3]	'		'
Investments in consolidated subsidiaries	'	-607		'	-1,344	[3]	'		'
Investments in unconsolidated affiliates	'	0		'	0	[3]	'		'
Other long-term assets	'	0		'	0	[3]	'		'
Total assets	'	-4,095		'	-3,644	[3]	'		'
LIABILITIES AND EQUITY	'	'		'	'		'		'
Accounts payable and other current liabilities	'	0		'	-3	[3]	'		'
Advances payable - consolidated subsidiaries	'	-3,488		'	-2,297	[3]	'		'
Long-term debt	'	0		'	0	[3]	'		'
Other long-term liabilities	'	0		'	0	[3]	'		'
Total liabilities	'	-3,488		'	-2,300	[3]	'		'
Commitments and contingent liabilities	'	'		'	'		'		'
Equity:	'	'		'	'		'		'
Predecessor equity	'	0	[3]	'	0	[3]	'		'
Net equity	'	-607		'	-1,344	[3]	'		'
Accumulated other comprehensive loss	'	0		'	0	[3]	'		'
Total partners' equity	'	-607		'	-1,344	[3]	'		'
Noncontrolling interests	'	0		'	0	[3]	'		'
Total equity	'	-607		'	-1,344	[3]	'		'
Total liabilities and equity	'	($4,095)		'	($3,644)	[3]	'		'
[1]	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[2]	The financial information during the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[3]	The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[4]	The segment information as of and for the years ended December 31, 2013, 2012 and 2011, includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas. Transfers of net assets between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information, similar to the pooling method.

Supplementary_Information_Cond4

Supplementary Information - Condensed Consolidating Financial Information - Condensed Consolidating Balance Sheets (Parenthetical) (Detail) (Eagle Ford System [Member])	0 Months Ended	12 Months Ended
	Mar. 28, 2013	Dec. 31, 2013	Dec. 31, 2012
Eagle Ford System [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Ownership interest percentage in subsidiary	80.00%	80.00%	80.00%

Supplementary_Information_Cond5

Supplementary Information - Condensed Consolidating Financial Information - Condensed Consolidating Statements of Operations (Detail) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Sales of natural gas, propane, NGLs and condensate

'

'

'

'

'

'

'

'

$2,763

[1]

$2,520

[2]

$3,574

[3]

Transportation, processing and other

'

'

'

'

'

'

'

'

271

[1]

234

[2]

208

[3]

Gains from commodity derivative activity, net

'

'

'

'

'

'

'

'

17

[1]

70

[2]

8

[3]

Total operating revenues

821

689

792

749

671

618

680

855

3,051

[1]

2,824

[2]

3,790

[3]

Purchases of natural gas, propane and NGLs

'

'

'

'

'

'

'

'

2,426

[1]

2,215

[2]

3,155

[3]

Operating and maintenance expense

'

'

'

'

'

'

'

'

215

[1]

197

[2]

192

[3]

Depreciation and amortization expense

'

'

'

'

'

'

'

'

95

[1]

91

[2]

135

[3]

General and administrative expense

'

'

'

'

'

'

'

'

63

[1]

75

[2]

76

[3]

Other expense (income)

'

'

'

'

'

'

'

'

8

[1]

0

-1

[3]

Total operating costs and expenses

'

'

'

'

'

'

'

'

2,807

[1]

2,578

[2]

3,557

[3]

Operating income

48

14

117

65

82

13

99

52

244

[1]

246

[2]

233

[3]

Interest expense

'

'

'

'

'

'

'

'

-52

[1]

-42

[2]

-34

[3]

Income from consolidated subsidiaries

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

33

[1]

26

[2]

23

[3]

Income before income taxes

'

'

'

'

'

'

'

'

225

[1]

230

[2]

222

[3]

Income tax expense

'

'

'

'

'

'

'

'

-8

[1],[4]

-1

[2],[4]

-1

[3],[4]

Net income

40

6

111

60

81

14

90

44

217

[1]

229

[2]

221

[3]

Net income attributable to noncontrolling interests

-7

-3

-4

-3

-5

-2

-2

-4

-17

[1]

-13

[2]

-30

[3]

Net income attributable to partners

33

3

107

57

76

12

88

40

200

[1]

216

[2]

191

[3]

Parent Guarantor [Member]

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Sales of natural gas, propane, NGLs and condensate

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Transportation, processing and other

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Gains from commodity derivative activity, net

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Total operating revenues

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Purchases of natural gas, propane and NGLs

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Operating and maintenance expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Depreciation and amortization expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

General and administrative expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Other expense (income)

'

'

'

'

'

'

'

'

0

[1]

'

0

[3]

Total operating costs and expenses

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Operating income

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Interest expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Income from consolidated subsidiaries

'

'

'

'

'

'

'

'

200

[1]

216

[2]

191

[3]

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Income before income taxes

'

'

'

'

'

'

'

'

200

[1]

216

[2]

191

[3]

Income tax expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Net income

'

'

'

'

'

'

'

'

200

[1]

216

[2]

191

[3]

Net income attributable to noncontrolling interests

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Net income attributable to partners

'

'

'

'

'

'

'

'

200

[1]

216

[2]

191

[3]

Subsidiary Issuer [Member]

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Sales of natural gas, propane, NGLs and condensate

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Transportation, processing and other

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Gains from commodity derivative activity, net

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Total operating revenues

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Purchases of natural gas, propane and NGLs

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Operating and maintenance expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Depreciation and amortization expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

General and administrative expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Other expense (income)

'

'

'

'

'

'

'

'

0

[1]

'

0

[3]

Total operating costs and expenses

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Operating income

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Interest expense

'

'

'

'

'

'

'

'

-52

[1]

-41

[2]

-33

[3]

Income from consolidated subsidiaries

'

'

'

'

'

'

'

'

252

[1]

257

[2]

224

[3]

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Income before income taxes

'

'

'

'

'

'

'

'

200

[1]

216

[2]

191

[3]

Income tax expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Net income

'

'

'

'

'

'

'

'

200

[1]

216

[2]

191

[3]

Net income attributable to noncontrolling interests

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Net income attributable to partners

'

'

'

'

'

'

'

'

200

[1]

216

[2]

191

[3]

Non-Guarantor Subsidiaries [Member]

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Sales of natural gas, propane, NGLs and condensate

'

'

'

'

'

'

'

'

2,763

[1]

2,520

[2]

3,574

[3]

Transportation, processing and other

'

'

'

'

'

'

'

'

271

[1]

234

[2]

208

[3]

Gains from commodity derivative activity, net

'

'

'

'

'

'

'

'

17

[1]

70

[2]

8

[3]

Total operating revenues

'

'

'

'

'

'

'

'

3,051

[1]

2,824

[2]

3,790

[3]

Purchases of natural gas, propane and NGLs

'

'

'

'

'

'

'

'

2,426

[1]

2,215

[2]

3,155

[3]

Operating and maintenance expense

'

'

'

'

'

'

'

'

215

[1]

197

[2]

192

[3]

Depreciation and amortization expense

'

'

'

'

'

'

'

'

95

[1]

91

[2]

135

[3]

General and administrative expense

'

'

'

'

'

'

'

'

63

[1]

75

[2]

76

[3]

Other expense (income)

'

'

'

'

'

'

'

'

8

[1]

'

-1

[3]

Total operating costs and expenses

'

'

'

'

'

'

'

'

2,807

[1]

2,578

[2]

3,557

[3]

Operating income

'

'

'

'

'

'

'

'

244

[1]

246

[2]

233

[3]

Interest expense

'

'

'

'

'

'

'

'

0

[1]

-1

[2]

-1

[3]

Income from consolidated subsidiaries

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

33

[1]

26

[2]

23

[3]

Income before income taxes

'

'

'

'

'

'

'

'

277

[1]

271

[2]

255

[3]

Income tax expense

'

'

'

'

'

'

'

'

-8

[1]

-1

[2]

-1

[3]

Net income

'

'

'

'

'

'

'

'

269

[1]

270

[2]

254

[3]

Net income attributable to noncontrolling interests

'

'

'

'

'

'

'

'

-17

[1]

-13

[2]

-30

[3]

Net income attributable to partners

'

'

'

'

'

'

'

'

252

[1]

257

[2]

224

[3]

Consolidating Adjustments [Member]

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Sales of natural gas, propane, NGLs and condensate

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Transportation, processing and other

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Gains from commodity derivative activity, net

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Total operating revenues

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Purchases of natural gas, propane and NGLs

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Operating and maintenance expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Depreciation and amortization expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

General and administrative expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Other expense (income)

'

'

'

'

'

'

'

'

0

[1]

'

0

[3]

Total operating costs and expenses

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Operating income

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Interest expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Income from consolidated subsidiaries

'

'

'

'

'

'

'

'

-452

[1]

-473

[2]

-415

[3]

Earnings from unconsolidated affiliates

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Income before income taxes

'

'

'

'

'

'

'

'

-452

[1]

-473

[2]

-415

[3]

Income tax expense

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Net income

'

'

'

'

'

'

'

'

-452

[1]

-473

[2]

-415

[3]

Net income attributable to noncontrolling interests

'

'

'

'

'

'

'

'

0

[1]

0

[2]

0

[3]

Net income attributable to partners

'

'

'

'

'

'

'

'

($452)

[1]

($473)

[2]

($415)

[3]

[1]

The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[2]

The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[3]

The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[4]

For the year ended December 31, 2011, income tax expense relates primarily to the Texas margin tax and the Michigan business tax. The Michigan business tax was repealed in 2012; accordingly, income tax expense for the years ended December 31, 2013 and 2012 relates primarily to the Texas margin tax.

Supplementary_Information_Cond6

Supplementary Information - Condensed Consolidating Financial Information - Condensed Consolidating Statements of Operations (Parenthetical) (Detail) (Eagle Ford System [Member])	0 Months Ended	12 Months Ended
	Mar. 28, 2013	Dec. 31, 2013	Dec. 31, 2012
Eagle Ford System [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Ownership interest percentage in subsidiary	80.00%	80.00%	80.00%

Supplementary_Information_Cond7

Supplementary Information - Condensed Consolidating Financial Information - Condensed Consolidating Statement of Comprehensive Income (Detail) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Net income

$40

$6

$111

$60

$81

$14

$90

$44

$217

[1]

$229

[2]

$221

[3]

Other comprehensive income (loss):

'

'

'

'

'

'

'

'

'

'

'

Reclassification of cash flow hedge losses into earnings

'

'

'

'

'

'

'

'

4

10

[2]

21

[3]

Other comprehensive income from consolidated subsidiaries

'

'

'

'

'

'

'

'

0

0

[2]

0

[3]

Net unrealized losses on cash flow hedges

'

'

'

'

'

'

'

'

'

-1

[2]

-15

[3]

Total other comprehensive income

'

'

'

'

'

'

'

'

4

9

[2]

6

[3]

Total comprehensive income

'

'

'

'

'

'

'

'

221

238

[2]

227

[3]

Total comprehensive income (loss) attributable to noncontrolling interests

'

'

'

'

'

'

'

'

-17

-13

[2]

-30

[3]

Total comprehensive income attributable to partners

'

'

'

'

'

'

'

'

204

225

[2]

197

[3]

Parent Guarantor [Member]

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Net income

'

'

'

'

'

'

'

'

200

[1]

216

[2]

191

[3]

Other comprehensive income (loss):

'

'

'

'

'

'

'

'

'

'

'

Reclassification of cash flow hedge losses into earnings

'

'

'

'

'

'

'

'

0

0

[2]

0

[3]

Other comprehensive income from consolidated subsidiaries

'

'

'

'

'

'

'

'

4

9

[2]

6

[3]

Net unrealized losses on cash flow hedges

'

'

'

'

'

'

'

'

'

'

[2]

0

[3]

Total other comprehensive income

'

'

'

'

'

'

'

'

4

9

[2]

6

[3]

Total comprehensive income

'

'

'

'

'

'

'

'

204

225

[2]

197

[3]

Total comprehensive income (loss) attributable to noncontrolling interests

'

'

'

'

'

'

'

'

0

0

[2]

0

[3]

Total comprehensive income attributable to partners

'

'

'

'

'

'

'

'

204

225

[2]

197

[3]

Subsidiary Issuer [Member]

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Net income

'

'

'

'

'

'

'

'

200

[1]

216

[2]

191

[3]

Other comprehensive income (loss):

'

'

'

'

'

'

'

'

'

'

'

Reclassification of cash flow hedge losses into earnings

'

'

'

'

'

'

'

'

4

10

[2]

21

[3]

Other comprehensive income from consolidated subsidiaries

'

'

'

'

'

'

'

'

0

0

[2]

-3

[3]

Net unrealized losses on cash flow hedges

'

'

'

'

'

'

'

'

'

-1

[2]

-12

[3]

Total other comprehensive income

'

'

'

'

'

'

'

'

4

9

[2]

6

[3]

Total comprehensive income

'

'

'

'

'

'

'

'

204

225

[2]

197

[3]

Total comprehensive income (loss) attributable to noncontrolling interests

'

'

'

'

'

'

'

'

0

0

[2]

0

[3]

Total comprehensive income attributable to partners

'

'

'

'

'

'

'

'

204

225

[2]

197

[3]

Non-Guarantor Subsidiaries [Member]

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Net income

'

'

'

'

'

'

'

'

269

[1]

270

[2]

254

[3]

Other comprehensive income (loss):

'

'

'

'

'

'

'

'

'

'

'

Reclassification of cash flow hedge losses into earnings

'

'

'

'

'

'

'

'

0

0

[2]

0

[3]

Other comprehensive income from consolidated subsidiaries

'

'

'

'

'

'

'

'

0

0

[2]

0

[3]

Net unrealized losses on cash flow hedges

'

'

'

'

'

'

'

'

'

'

[2]

-3

[3]

Total other comprehensive income

'

'

'

'

'

'

'

'

0

0

[2]

-3

[3]

Total comprehensive income

'

'

'

'

'

'

'

'

269

270

[2]

251

[3]

Total comprehensive income (loss) attributable to noncontrolling interests

'

'

'

'

'

'

'

'

-17

-13

[2]

-30

[3]

Total comprehensive income attributable to partners

'

'

'

'

'

'

'

'

252

257

[2]

221

[3]

Consolidating Adjustments [Member]

'

'

'

'

'

'

'

'

'

'

'

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Net income

'

'

'

'

'

'

'

'

-452

[1]

-473

[2]

-415

[3]

Other comprehensive income (loss):

'

'

'

'

'

'

'

'

'

'

'

Reclassification of cash flow hedge losses into earnings

'

'

'

'

'

'

'

'

0

0

[2]

0

[3]

Other comprehensive income from consolidated subsidiaries

'

'

'

'

'

'

'

'

-4

-9

[2]

-3

[3]

Net unrealized losses on cash flow hedges

'

'

'

'

'

'

'

'

'

'

[2]

0

[3]

Total other comprehensive income

'

'

'

'

'

'

'

'

-4

-9

[2]

-3

[3]

Total comprehensive income

'

'

'

'

'

'

'

'

-456

-482

[2]

-418

[3]

Total comprehensive income (loss) attributable to noncontrolling interests

'

'

'

'

'

'

'

'

0

0

[2]

0

[3]

Total comprehensive income attributable to partners

'

'

'

'

'

'

'

'

($456)

($482)

[2]

($418)

[3]

[1]

The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[2]

The financial information for the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

[3]

The financial information for the year ended December 31, 2011 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Supplementary_Information_Cond8

Supplementary Information - Condensed Consolidating Financial Information - Condensed Consolidating Statement of Comprehensive Income (Parenthetical) (Detail) (Eagle Ford System [Member])	0 Months Ended	12 Months Ended
	Mar. 28, 2013	Dec. 31, 2013	Dec. 31, 2012
Eagle Ford System [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Ownership interest percentage in subsidiary	80.00%	80.00%	80.00%

Supplementary_Information_Cond9

Supplementary Information - Condensed Consolidating Financial Information - Condensed Consolidating Statements of Cash Flows (Detail) (USD $)	3 Months Ended				12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013		Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
OPERATING ACTIVITIES	'		'		'		'		'
Net cash (used in) provided by operating activities	$146		$152		$345	[1]	$102	[2]	$417
INVESTING ACTIVITIES:	'		'		'		'		'
Payments for (Proceeds from) Other Investing Activities	0		0		0		0		0
Capital expenditures	-63		-101		-363	[1]	-484	[2]	-385
Acquisitions, net of cash acquired	-100		'		-696	[1]	-433		-38
Acquisitions, net of cash acquired	'		-481		'		-745	[2]	-152
Acquisition of unconsolidated affiliates	-669		'		-86	[1]	-312		-114
Investments in unconsolidated affiliates	-65		-26		-242	[1]	-158	[2]	-8
Return of investment in unconsolidated affiliates	'		'		0		1	[2]	2
Proceeds from sales of assets	1		'		0		2	[2]	5
Net cash used in investing activities	-896		-608		-1,387	[1]	-1,384	[2]	-538
FINANCING ACTIVITIES:	'		'		'		'		'
Proceeds from (Payments for) Other Financing Activities	0		0		0		0		0
Proceeds from long-term debt	719		809		1,957	[1]	2,665	[2]	1,524
Payments of long-term debt	'		-690		-1,988	[1]	-1,792	[2]	-1,425
Proceeds from issuance of commercial paper	-314		'		335	[1]	0		0
Payments of deferred financing costs	-6		-4		-4	[1]	-8	[2]	-4
Excess purchase price over acquired net assets and commodity hedge	-14		-94		-85	[1]	-225	[2]	-36
Proceeds from issuance of common units, net of offering cost	677		494		1,083	[1]	455	[2]	170
Excess Purchase Price Over Acquired Assets	'		'		'		'		-36
Net change in advances to predecessor from DCP Midstream, LLC	-6		22		11	[1]	336	[2]	52
Distributions to limited partners and general partner	-86		-54		-277	[1]	-181	[2]	-132
Distributions to noncontrolling interests	-10		-5		-24	[1]	-9	[2]	-45
Payments to Noncontrolling Interests	-198		'		'		'		'
Contributions from noncontrolling interests	3		15		46	[1]	25	[2]	18
Distributions to DCP Midstream, LLC	'		-3		-3	[1]	0		0
Contributions from DCP Midstream, LLC	'		1		1	[1]	10	[2]	0
Net cash provided by financing activities	765		491		1,052	[1]	1,276	[2]	122
Net change in cash and cash equivalents	15		35		10	[1]	-6	[2]	1
Cash and cash equivalents, beginning of year	12	[1]	2	[1],[2],[3]	2	[1],[2],[3]	8	[2]	7
Cash and cash equivalents, end of year	27		37		12	[1]	2	[1],[2],[3]	8	[2]
Parent Guarantor [Member]	'		'		'		'		'
OPERATING ACTIVITIES	'		'		'		'		'
Net cash (used in) provided by operating activities	0		0		0	[1]	0	[2]	0
INVESTING ACTIVITIES:	'		'		'		'		'
Payments for (Proceeds from) Other Investing Activities	-591		-440		-806	[1]	-274	[1]	-38	[1]
Capital expenditures	0		0		0	[1]	0	[2]	0
Acquisitions, net of cash acquired	0		'		0	[1]	'		'
Acquisitions, net of cash acquired	'		0		'		0	[2]	0
Acquisition of unconsolidated affiliates	0		'		0	[1]	'		'
Investments in unconsolidated affiliates	0		0		0	[1]	0	[2]	0
Return of investment in unconsolidated affiliates	'		'		'		0	[2]	0
Proceeds from sales of assets	0		'		'		0	[2]	0
Net cash used in investing activities	-591		-440		-806	[1]	-274	[2]	-38
FINANCING ACTIVITIES:	'		'		'		'		'
Proceeds from (Payments for) Other Financing Activities	0		0		0	[1]	0	[1]	0	[1]
Proceeds from long-term debt	0		0		0	[1]	0	[2]	0
Payments of long-term debt	'		0		0	[1]	0	[2]	0
Proceeds from issuance of commercial paper	0		'		0	[1]	'		'
Payments of deferred financing costs	0		0		0	[1]	0	[2]	0
Excess purchase price over acquired net assets and commodity hedge	0		0		0	[1]	0	[2]	'
Proceeds from issuance of common units, net of offering cost	677		494		1,083	[1]	455	[2]	170
Excess Purchase Price Over Acquired Assets	'		'		'		'		0
Net change in advances to predecessor from DCP Midstream, LLC	0		0		0	[1]	0	[2]	0
Distributions to limited partners and general partner	-86		-54		-277	[1]	-181	[2]	-132
Distributions to noncontrolling interests	0		0		0	[1]	0	[2]	0
Payments to Noncontrolling Interests	0		'		'		'		'
Contributions from noncontrolling interests	0		0		0	[1]	0	[2]	0
Distributions to DCP Midstream, LLC	'		0		0	[1]	'		'
Contributions from DCP Midstream, LLC	'		0		0	[1]	0	[2]	'
Net cash provided by financing activities	591		440		806	[1]	274	[2]	38
Net change in cash and cash equivalents	0		0		0	[1]	0	[2]	0
Cash and cash equivalents, beginning of year	0	[1]	0	[1],[2],[3]	0	[1],[2],[3]	0	[2]	0
Cash and cash equivalents, end of year	0		0		0	[1]	0	[1],[2],[3]	0	[2]
Subsidiary Issuer [Member]	'		'		'		'		'
OPERATING ACTIVITIES	'		'		'		'		'
Net cash (used in) provided by operating activities	-11		-1		-45	[1]	-39	[2]	-31
INVESTING ACTIVITIES:	'		'		'		'		'
Payments for (Proceeds from) Other Investing Activities	365		72		258		827		62
Capital expenditures	0		0		0	[1]	0	[2]	0
Acquisitions, net of cash acquired	0		'		0	[1]	'		'
Acquisitions, net of cash acquired	'		0		'		0	[2]	0
Acquisition of unconsolidated affiliates	0		'		0	[1]	'		'
Investments in unconsolidated affiliates	0		0		0	[1]	0	[2]	0
Return of investment in unconsolidated affiliates	'		'		'		0	[2]	0
Proceeds from sales of assets	0		'		'		0	[2]	0
Net cash used in investing activities	-365		-72		-258	[1]	-827	[2]	-62
FINANCING ACTIVITIES:	'		'		'		'		'
Proceeds from (Payments for) Other Financing Activities	0		0		0		0		0
Proceeds from long-term debt	719		809		1,957	[1]	2,665	[2]	1,524
Payments of long-term debt	'		-690		-1,988	[1]	-1,792	[2]	-1,425
Proceeds from issuance of commercial paper	-314		'		335	[1]	'		'
Payments of deferred financing costs	-6		-4		-4	[1]	-8	[2]	-4
Excess purchase price over acquired net assets and commodity hedge	0		0		0	[1]	0	[2]	'
Proceeds from issuance of common units, net of offering cost	0		0		0	[1]	0	[2]	0
Excess Purchase Price Over Acquired Assets	'		'		'		'		0
Net change in advances to predecessor from DCP Midstream, LLC	0		0		0	[1]	0	[2]	0
Distributions to limited partners and general partner	0		0		0	[1]	0	[2]	0
Distributions to noncontrolling interests	0		0		0	[1]	0	[2]	0
Payments to Noncontrolling Interests	0		'		'		'		'
Contributions from noncontrolling interests	0		0		0	[1]	0	[2]	0
Distributions to DCP Midstream, LLC	'		0		0	[1]	'		'
Contributions from DCP Midstream, LLC	'		0		0	[1]	0	[2]	'
Net cash provided by financing activities	399		115		300	[1]	865	[2]	95
Net change in cash and cash equivalents	23		42		-3	[1]	-1	[2]	2
Cash and cash equivalents, beginning of year	0	[1]	3	[1],[2],[3]	3	[1],[2],[3]	4	[2]	2
Cash and cash equivalents, end of year	23		45		0	[1]	3	[1],[2],[3]	4	[2]
Non-Guarantor Subsidiaries [Member]	'		'		'		'		'
OPERATING ACTIVITIES	'		'		'		'		'
Net cash (used in) provided by operating activities	157		159		387	[1]	142	[2]	448
INVESTING ACTIVITIES:	'		'		'		'		'
Payments for (Proceeds from) Other Investing Activities	0		0		0		0		0
Capital expenditures	-63		-101		-363	[1]	-484	[2]	-385
Acquisitions, net of cash acquired	-100		'		-696	[1]	'		'
Acquisitions, net of cash acquired	'		-481		'		-745	[2]	-152
Acquisition of unconsolidated affiliates	-669		'		-86	[1]	'		'
Investments in unconsolidated affiliates	-65		-26		-242	[1]	-158	[2]	-8
Return of investment in unconsolidated affiliates	'		'		'		1	[2]	2
Proceeds from sales of assets	1		'		'		2	[2]	5
Net cash used in investing activities	-896		-608		-1,387	[1]	-1,384	[2]	-538
FINANCING ACTIVITIES:	'		'		'		'		'
Proceeds from (Payments for) Other Financing Activities	956		512		1,064		1,101		100
Proceeds from long-term debt	0		0		0	[1]	0	[2]	0
Payments of long-term debt	'		0		0	[1]	0	[2]	0
Proceeds from issuance of commercial paper	0		'		0	[1]	'		'
Payments of deferred financing costs	0		0		0	[1]	0	[2]	0
Excess purchase price over acquired net assets and commodity hedge	-14		-94		-85	[1]	-225	[2]	'
Proceeds from issuance of common units, net of offering cost	0		0		0	[1]	0	[2]	0
Excess Purchase Price Over Acquired Assets	'		'		'		'		-36
Net change in advances to predecessor from DCP Midstream, LLC	-6		22		11	[1]	336	[2]	52
Distributions to limited partners and general partner	0		0		0	[1]	0	[2]	0
Distributions to noncontrolling interests	-10		-5		-24	[1]	-9	[2]	-45
Payments to Noncontrolling Interests	-198		'		'		'		'
Contributions from noncontrolling interests	3		15		46	[1]	25	[2]	18
Distributions to DCP Midstream, LLC	'		-3		-3	[1]	'		'
Contributions from DCP Midstream, LLC	'		1		1	[1]	10	[2]	'
Net cash provided by financing activities	731		448		1,010	[1]	1,238	[2]	89
Net change in cash and cash equivalents	-8		-1		10	[1]	-4	[2]	-1
Cash and cash equivalents, beginning of year	12	[1]	2	[1],[2],[3]	2	[1],[2],[3]	6	[2]	7
Cash and cash equivalents, end of year	4		1		12	[1]	2	[1],[2],[3]	6	[2]
Consolidating Adjustments [Member]	'		'		'		'		'
OPERATING ACTIVITIES	'		'		'		'		'
Net cash (used in) provided by operating activities	0		-6		3	[1]	-1	[2]	0
INVESTING ACTIVITIES:	'		'		'		'		'
Payments for (Proceeds from) Other Investing Activities	-956		-512		-1,064		-1,101		-100
Capital expenditures	0		0		0	[1]	0	[2]	0
Acquisitions, net of cash acquired	0		'		0	[1]	'		'
Acquisitions, net of cash acquired	'		0		'		0	[2]	0
Acquisition of unconsolidated affiliates	0		'		0	[1]	'		'
Investments in unconsolidated affiliates	0		0		0	[1]	0	[2]	0
Return of investment in unconsolidated affiliates	'		'		'		0	[2]	0
Proceeds from sales of assets	0		'		'		0	[2]	0
Net cash used in investing activities	956		512		1,064	[1]	1,101	[2]	100
FINANCING ACTIVITIES:	'		'		'		'		'
Proceeds from (Payments for) Other Financing Activities	-956		-512		-1,064		-1,101		-100
Proceeds from long-term debt	0		0		0	[1]	0	[2]	0
Payments of long-term debt	'		0		0	[1]	0	[2]	0
Proceeds from issuance of commercial paper	0		'		0	[1]	'		'
Payments of deferred financing costs	0		0		0	[1]	0	[2]	0
Excess purchase price over acquired net assets and commodity hedge	0		0		0	[1]	0	[2]	'
Proceeds from issuance of common units, net of offering cost	0		0		0	[1]	0	[2]	0
Excess Purchase Price Over Acquired Assets	'		'		'		'		0
Net change in advances to predecessor from DCP Midstream, LLC	0		0		0	[1]	0	[2]	0
Distributions to limited partners and general partner	0		0		0	[1]	0	[2]	0
Distributions to noncontrolling interests	0		0		0	[1]	0	[2]	0
Payments to Noncontrolling Interests	0		'		'		'		'
Contributions from noncontrolling interests	0		0		0	[1]	0	[2]	0
Distributions to DCP Midstream, LLC	'		0		0	[1]	'		'
Contributions from DCP Midstream, LLC	'		0		0	[1]	0	[2]	'
Net cash provided by financing activities	-956		-512		-1,064	[1]	-1,101	[2]	-100
Net change in cash and cash equivalents	0		-6		3	[1]	-1	[2]	0
Cash and cash equivalents, beginning of year	0	[1]	-3	[1],[2],[3]	-3	[1],[2],[3]	-2	[2]	-2
Cash and cash equivalents, end of year	0		-9		0	[1]	-3	[1],[2],[3]	-2	[2]
Scenario, Adjustment [Member]	'		'		'		'		'
OPERATING ACTIVITIES	'		'		'		'		'
Net cash (used in) provided by operating activities	0		0		0	[1]	0	[1]	0	[1]
INVESTING ACTIVITIES:	'		'		'		'		'
Net cash used in investing activities	0		0		0	[1]	0	[1]	0	[1]
FINANCING ACTIVITIES:	'		'		'		'		'
Net cash provided by financing activities	0		0		0		0		0
Scenario, Adjustment [Member] | Parent Guarantor [Member]	'		'		'		'		'
OPERATING ACTIVITIES	'		'		'		'		'
Net cash (used in) provided by operating activities	591		440		806	[1]	274	[1]	38	[1]
INVESTING ACTIVITIES:	'		'		'		'		'
Net cash used in investing activities	-591		-440		-806	[1]	-274	[1]	-38	[1]
FINANCING ACTIVITIES:	'		'		'		'		'
Net cash provided by financing activities	0		0		0		0		0
Scenario, Adjustment [Member] | Subsidiary Issuer [Member]	'		'		'		'		'
OPERATING ACTIVITIES	'		'		'		'		'
Net cash (used in) provided by operating activities	365		72		258	[1]	827	[1]	62	[1]
INVESTING ACTIVITIES:	'		'		'		'		'
Net cash used in investing activities	-365		-72		-258	[1]	-827	[1]	-62	[1]
FINANCING ACTIVITIES:	'		'		'		'		'
Net cash provided by financing activities	0		0		0		0		0
Scenario, Adjustment [Member] | Non-Guarantor Subsidiaries [Member]	'		'		'		'		'
OPERATING ACTIVITIES	'		'		'		'		'
Net cash (used in) provided by operating activities	-956		-512		-1,064	[1]	-1,101	[1]	-100	[1]
INVESTING ACTIVITIES:	'		'		'		'		'
Net cash used in investing activities	0		0		0	[1]	0	[1]	0	[1]
FINANCING ACTIVITIES:	'		'		'		'		'
Net cash provided by financing activities	956		512		1,064		1,101		100
Scenario, Adjustment [Member] | Consolidating Adjustments [Member]	'		'		'		'		'
OPERATING ACTIVITIES	'		'		'		'		'
Net cash (used in) provided by operating activities	0		0		0	[1]	0	[1]	0	[1]
INVESTING ACTIVITIES:	'		'		'		'		'
Net cash used in investing activities	956		512		1,064	[1]	1,101	[1]	100	[1]
FINANCING ACTIVITIES:	'		'		'		'		'
Net cash provided by financing activities	($956)		($512)		($1,064)		($1,101)		($100)
[1]	The financial information for the year ended December 31, 2013 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[2]	The financial information during the year ended December 31, 2012 includes the results of our Lucerne 1 plant, our 80% interest in the Eagle Ford system and our 100% interest in Southeast Texas and commodity derivative hedge instruments related to the Southeast Texas storage business. These transfers of net assets between entities under common control were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.
[3]	The financial information as of December 31, 2012 includes the results of our Lucerne 1 plant and our 80% interest in the Eagle Ford system, transfers of net assets between entities under common control that were accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information similar to the pooling method.

Recovered_Sheet3

Supplementary Information - Condensed Consolidating Financial Information - Condensed Consolidating Statements of Cash Flows (Parenthetical) (Detail)	0 Months Ended	12 Months Ended
	Mar. 28, 2013	Dec. 31, 2013	Dec. 31, 2012
Eagle Ford System [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Ownership interest percentage in subsidiary	80.00%	80.00%	80.00%
Southeast Texas [Member]	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'
Ownership interest percentage in subsidiary	'	100.00%	100.00%

Valuation_and_Qualifying_Accou2

Valuation and Qualifying Accounts and Reserves (Schedule of Valuation and Qualifying Accounts Reserves) (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Movement in Valuation Allowances and Reserves [Roll Forward]	'		'		'
Balance at Beginning of Period	$3		$4		$4
Charged to Consolidated Statements of Operations	1		0		1
Charged to Other Accounts	0		0		0
Deductions/ Other	-1		-1		-1
Balance at End of Period	3		3		4
Environmental [Member]	'		'		'
Movement in Valuation Allowances and Reserves [Roll Forward]	'		'		'
Balance at Beginning of Period	2		3		3
Charged to Consolidated Statements of Operations	1		0		0
Charged to Other Accounts	0		0		0
Deductions/ Other	-1		-1		0
Balance at End of Period	2		2		3
Litigation [Member]	'		'		'
Movement in Valuation Allowances and Reserves [Roll Forward]	'		'		'
Balance at Beginning of Period	'		'		1
Charged to Consolidated Statements of Operations	'		'		0
Charged to Other Accounts	'		'		0
Deductions/ Other	'		'		-1
Balance at End of Period	'		'		0
Other [Member]	'		'		'
Movement in Valuation Allowances and Reserves [Roll Forward]	'		'		'
Balance at Beginning of Period	1	[1]	1	[1]	0	[1]
Charged to Consolidated Statements of Operations	0	[1]	0	[1]	1	[1]
Charged to Other Accounts	0	[1]	0	[1]	0	[1]
Deductions/ Other	0	[1]	0	[1]	0	[1]
Balance at End of Period	$1	[1]	$1	[1]	$1	[1]
[1]	Principally consists of allowance for doubtful accounts, reserves against other long-term assets, which are included in other long-term assets, and other contingency liabilities, which are included in other current liabilities.

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Detail) (USD $)

0 Months Ended

0 Months Ended

0 Months Ended

In Millions, except Per Share data, unless otherwise specified

Feb. 25, 2014

Jul. 25, 2013

Jan. 28, 2014

Feb. 25, 2014

Feb. 25, 2014

Feb. 25, 2014

Feb. 25, 2014

Feb. 25, 2014

Mar. 28, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2013

Mar. 26, 2013

Mar. 14, 2013

Dec. 31, 2012

Nov. 30, 2012

Feb. 29, 2012

Mar. 28, 2014

Mar. 31, 2014

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

DCP SC Texas GP [Member]

Lucerne 1 [Member]

Lucerne 2 [Member]

Southern Hills Pipeline [Member]

DCP Southern Hills Pipeline LLC [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Eagle Ford System [Member]

Lucerne 1 [Member]

DCP Southern Hills Pipeline LLC [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

MMcf

MMcf

mi

mi

MBbls

MBbls

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution of dividend

'

'

$0.73

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution payable date

'

14-Feb-14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution record date

'

7-Feb-14

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest acquired

'

'

'

'

'

'

'

'

46.67%

20.00%

46.67%

46.67%

'

46.67%

33.33%

33.33%

'

100.00%

33.33%

Ownership interest percentage

'

'

'

20.00%

'

'

'

33.33%

'

'

'

'

33.33%

'

'

'

33.33%

'

'

Capacity per day

'

'

'

'

35,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expected capacity per day

'

'

'

'

'

200,000,000

175

200

'

'

'

'

'

'

'

'

'

'

'

Aggregate consideration for acquisition

$1,220

'

'

'

'

'

'

'

$626

'

'

'

'

'

'

'

'

$0

'

Length of pipeline (in miles)

'

'

'

'

'

'

800

720

'

'

'

'

'

'

'

'

'

'

'