Targa Resources Partners (NGLS-PA) 10-Q 2 May 14 2014 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2014	Apr. 18, 2014	Apr. 18, 2014
		Common Units [Member]	General Partner Units [Member]
Document and Entity Information [Line Items]	'	'	'
Entity Registrant Name	'Targa Resources Partners LP	'	'
Entity Central Index Key	'0001379661	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Entity Common Stock, Shares Outstanding	'	114,296,848	2,332,590
Document Fiscal Year Focus	'2014	'	'
Document Fiscal Period Focus	'Q1	'	'
Document Type	'10-Q	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Mar-14	'	'

CONSOLIDATED_BALANCE_SHEETS_Un

CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$81.40	$57.50
Trade receivables, net of allowances of $0.9 million and $0.9 million	610.1	658.6
Inventories	88.5	150.7
Assets from risk management activities	1.6	2
Other current assets	4	7.1
Total current assets	785.6	875.9
Property, plant and equipment	5,930.10	5,751.60
Accumulated depreciation	-1,470.30	-1,406.20
Property, plant and equipment, net	4,459.80	4,345.40
Other intangible assets, net	638.1	653.4
Long-term assets from risk management activities	2.9	3.1
Investment in unconsolidated affiliate	53.7	55.9
Other long-term assets	36.2	37.7
Total assets	5,976.30	5,971.40
Current liabilities:	'	'
Accounts payable and accrued liabilities	698.8	721.2
Accounts payable to Targa Resources Corp.	41.1	52.4
Liabilities from risk management activities	12.9	8
Total current liabilities	752.8	781.6
Long-term debt	2,819.70	2,905.30
Long-term liabilities from risk management activities	1.2	1.4
Deferred income taxes	12.5	12.1
Other long-term liabilities	55.3	52.6
Commitments and contingencies (see Note 15)	'	'
Owners' equity:	'	'
Common unitholders (113,494,218 and 111,263,207 units issued and outstanding as of March 31, 2014 and December 31, 2013)	2,123.80	2,001.90
General partner (2,316,210 and 2,270,680 units issued and outstanding as of March 31, 2014 and December 31, 2013)	66.4	62
Receivables from unit offerings	-7.1	0
Accumulated other comprehensive income	-10.4	-6.1
Partners' Capital	2,172.70	2,057.80
Noncontrolling interests in subsidiaries	162.1	160.6
Total owners' equity	2,334.80	2,218.40
Total liabilities and owners' equity	$5,976.30	$5,971.40

CONSOLIDATED_BALANCE_SHEETS_Un1

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Millions, except Share data, unless otherwise specified
Current assets:	'	'
Allowance for receivables	$0.90	$0.90
Owners' equity:	'	'
Common unitholders units issued (in units)	113,494,218	111,263,207
Common unitholders units outstanding (in units)	113,494,218	111,263,207
General partner units issued (in units)	2,316,210	2,270,680
General partner units outstanding (in units)	2,316,210	2,270,680

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) [Abstract]	'	'
Revenues	$2,352.90	$1,397.80
Costs and expenses:	'	'
Product purchases	1,973.30	1,137.50
Operating expenses	104.3	86.1
Depreciation and amortization expenses	79.5	63.9
General and administrative expenses	35.9	34.1
Other operating expense	-0.7	0
Income from operations	160.6	76.2
Other income (expense):	'	'
Interest expense, net	-33.1	-31.4
Equity earnings (loss)	4.9	1.6
Other	0	-0.2
Income before income taxes	132.4	46.2
Income tax expense:	'	'
Current	-0.7	-0.5
Deferred	-0.4	-0.4
Total income tax expense	-1.1	-0.9
Net income	131.3	45.3
Less: Net income attributable to noncontrolling interests	8.9	6.4
Net income attributable to Targa Resources Partners LP	122.4	38.9
Net income attributable to general partner	33.8	22.8
Net income attributable to limited partners	88.6	16.1
Net income attributable to Targa Resources Partners LP	$122.40	$38.90
Net income per limited partner unit - basic (in dollars per share)	$0.79	$0.16
Net income per limited partner unit - diluted (in dollars per share)	$0.78	$0.16
Weighted average limited partner units outstanding - basic (in shares)	112.4	101.8
Weighted average limited partner units outstanding - diluted (in shares)	113	102

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited) [Abstract]	'	'
Net income	$131.30	$45.30
Commodity hedging contracts:	'	'
Change in fair value	-11.9	-7.6
Settlement reclassified to revenues	6.3	-6.6
Interest rate swaps:	'	'
Settlements reclassified to interest expense, net	1.3	1.7
Other comprehensive loss	-4.3	-12.5
Comprehensive income	127	32.8
Less: Comprehensive income attributable to noncontrolling interests	8.9	6.4
Comprehensive income attributable to Targa Resources Partners LP	$118.10	$26.40

CONSOLIDATED_STATEMENTS_OF_CHA

CONSOLIDATED STATEMENTS OF CHANGES IN OWNERS' EQUITY (Unaudited) (USD $)	Limited Partners Common [Member]	General Partner [Member]	Receivables From Unit Offerings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Non-controlling Interests [Member]	Total
In Millions, except Share data
Beginning Balance at Dec. 31, 2012	$1,649.50	$45.30	$0	$14.80	$150.50	$1,860.10
Beginning Balance (in units) at Dec. 31, 2012	100,096,000	2,043,000	'	'	'	'
Compensation on equity grants	1.7	0	0	0	0	1.7
Compensation on equity grants (in units)	13,000	0	'	'	'	'
Accrual of distribution equivalent rights	-0.3	0	0	0	0	-0.3
Equity offerings	105.3	2.3	0	0	0	107.6
Equity offerings (in units)	2,668,000	54,000	'	'	'	'
Distributions to noncontrolling interests	0	0	0	0	-3.7	-3.7
Contribution from noncontrolling interests	0	0	0	0	2.1	2.1
Other comprehensive loss	0	0	0	-12.5	0	-12.5
Net income	16.1	22.8	0	0	6.4	45.3
Distributions	-69	-21.9	0	0	0	-90.9
Ending Balance at Mar. 31, 2013	1,703.30	48.5	0	2.3	155.3	1,909.40
Ending Balance (in units) at Mar. 31, 2013	102,777,000	2,097,000	'	'	'	'
Beginning Balance at Dec. 31, 2013	2,001.90	62	0	-6.1	160.6	2,218.40
Beginning Balance (in units) at Dec. 31, 2013	111,263,000	2,271,000	'	'	'	'
Compensation on equity grants	2.6	0	0	0	0	2.6
Compensation on equity grants (in units)	9,000	0	'	'	'	'
Accrual of distribution equivalent rights	-0.6	0	0	0	0	-0.6
Equity offerings	115.3	2.4	-7.1	0	0	110.6
Equity offerings (in units)	2,222,000	45,000	'	'	'	'
Distributions to noncontrolling interests	0	0	0	0	-7.4	-7.4
Other comprehensive loss	0	0	0	-4.3	0	-4.3
Net income	88.6	33.8	0	0	8.9	131.3
Distributions	-84	-31.8	0	0	0	-115.8
Ending Balance at Mar. 31, 2014	$2,123.80	$66.40	($7.10)	($10.40)	$162.10	$2,334.80
Ending Balance (in units) at Mar. 31, 2014	113,494,000	2,316,000	'	'	'	'

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Cash flows from operating activities	'	'
Net income	$131.30	$45.30
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Amortization in interest expense	3.4	4
Compensation on equity grants	2.6	1.7
Depreciation and amortization expense	79.5	63.9
Accretion of asset retirement obligations	1.2	1.1
Deferred income tax expense	0.4	0.4
Equity earnings, net of distributions	0	-1.6
Risk management activities	-0.3	-0.2
Gain on sale or disposition of assets	-0.8	-0.1
Changes in operating assets and liabilities:	'	'
Receivables and other assets	50.6	87.9
Inventories	60.6	33.6
Accounts payable and other liabilities	-12.1	-45.4
Net cash provided by operating activities	316.4	190.6
Cash flows from investing activities	'	'
Outlays for property, plant and equipment	-197.7	-222.4
Purchase of materials and supplies	0.1	0
Return of capital from unconsolidated affiliate	2.2	0
Other, net	1.7	-4.6
Net cash used in investing activities	-193.7	-227
Cash flows from financing activities	'	'
Proceeds from borrowings under credit facility	460	325
Repayments of credit facility	-500	-380
Borrowings from accounts receivable securitization facility	29.5	171.4
Repayments of accounts receivable securitization facility	-75.7	-60
Costs incurred in connection with financing arrangements	-1.2	-3.1
Proceeds from equity offerings	111.8	109.7
Distributions	-115.8	-90.9
Contributions from noncontrolling interests	0	2.1
Distributions to noncontrolling interests	-7.4	-3.7
Net cash provided by (used in) financing activities	-98.8	70.5
Net change in cash and cash equivalents	23.9	34.1
Cash and cash equivalents, beginning of period	57.5	68
Cash and cash equivalents, end of period	$81.40	$102.10

Organization_and_Operations

Organization and Operations	3 Months Ended
	Mar. 31, 2014
Organization and Operations [Abstract]	'
Organization and Operations	'
	Note 1 — Organization and Operations
	Our Organization
	Targa Resources Partners LP is a publicly traded Delaware limited partnership formed in October 2006 by Targa Resources Corp. ("Targa" or "Parent"). Our common units, which represent limited partner interests in us, are listed on the New York Stock Exchange under the symbol "NGLS." In this Quarterly Report, unless the context requires otherwise, references to "we," "us," "our" or the "Partnership" are intended to mean the business and operations of Targa Resources Partners LP and its consolidated subsidiaries.
	Targa Resources GP LLC is a Delaware limited liability company formed by Targa in October 2006 to own a 2% general partner interest in us. Its primary business purpose is to manage our affairs and operations. Targa Resources GP LLC is an indirect wholly owned subsidiary of Targa. As of March 31, 2014, Targa owned a 13.2% interest in us in the form of 2,316,210 general partner units and 12,945,659 common units. In addition, Targa Resources GP LLC also owns incentive distribution rights ("IDRs"), which entitle it to receive increasing cash distributions up to 48% of distributable cash for a quarter.
	Allocation of costs
	The employees supporting our operations are employed by Targa Resources LLC, a Delaware limited liability company and an indirect wholly owned subsidiary of Targa. Our financial statements include the direct costs of Targa employees deployed to our operating segments, as well as an allocation of costs associated with our usage of Targa centralized general and administrative services.
	Our Operations
	We are engaged in the business of gathering, compressing, treating, processing and selling natural gas; storing, fractionating, treating, transporting and selling NGLs and NGL products; gathering, storing and terminaling crude oil; and storing, terminaling and selling refined petroleum products. See Note 17 for certain financial information for our business segments.

Basis_of_Presentation

Basis of Presentation	3 Months Ended
	Mar. 31, 2014
Basis of Presentation [Abstract]	'
Basis of Presentation	'
	Note 2 — Basis of Presentation
	We have prepared these unaudited consolidated financial statements in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. While we derived the year-end balance sheet data from audited financial statements, this interim report does not include all disclosures required by GAAP for annual periods. These unaudited consolidated financial statements and other information included in this Quarterly Report should be read in conjunction with our consolidated financial statements and notes thereto included in our Annual Report.
	The unaudited consolidated financial statements for the three months ended March 31, 2014 and 2013 include all adjustments, which we believe are necessary, for a fair presentation of the results for interim periods. All significant intercompany balances and transactions have been eliminated in consolidation. Certain amounts in prior periods may have been reclassified to conform to the current year presentation.
	Our financial results for the three months ended March 31, 2014 are not necessarily indicative of the results that may be expected for the full year.
	Reclassifications Affecting Statement of Cash Flows
	In conjunction with the ongoing integration of Badlands into our financial reporting environment during 2013, we obtained further information about acquisition date balance sheet, including the nature of the items comprising assumed Accounts payable and accrued liabilities. We determined that certain assumed liabilities related to purchases that, under our accounting policies, we considered capital in nature. Consequently, we made certain refinements to better reflect Badlands cash flow activity on a basis similar to that used for our other operations. As a result of these refinements, certain Badlands cash flow activity was presented in our 2013 Form 10-K on a basis different than that utilized for previous quarterly reporting during 2013. In preparing this quarterly report we have made certain measurement period reclassifications to the comparative Statement of Cash Flows for the three months ended March 31, 2013 to conform to the presentation of our Form 10-K, reclassifying $18.9 million related to capital expenditures previously included in Accounts payable and other liabilities of operating activities to Outlays for property, plant and equipment in investing activities, as shown below.
		Three Months Ended March 31, 2013
	Revised line items Consolidated Statement of Cash Flows	As Reported			Reclassification			Revised
	Cash Flows from operating activities
	Changes in operating assets and liabilities:
	Accounts payable and other liabilities	$	(64.3	)	$	18.9		$	(45.4	)
	Net cash provided by operating activities		171.7			18.9			190.6
	Cash flows from investing activities:
	Changes in investing assets and liabilities:
	Outlays for property, plant and equipment		(203.5	)		(18.9	)		(222.4	)
	Net cash used in investing activities		(208.1	)		(18.9	)		(227.0	)

Significant_Accounting_Policie

Significant Accounting Policies	3 Months Ended
	Mar. 31, 2014
Significant Accounting Policies [Abstract]	'
Significant Accounting Policies	'
	Note 3 — Significant Accounting Policies
	Accounting Policy Updates/Revisions
	The accounting policies that we follow are set forth in Note 3 of the Notes to Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 2013. There were no significant updates or revisions to these policies during the three months ended March 31, 2014.
	Recent Accounting Pronouncements
	In April 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update No 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. The amendment, required to be applied prospectively for reporting periods beginning after December 15, 2014, limits discontinued operations reporting to disposals of components of an entity that represent strategic shifts that have, or will have, a major effect on operations and financial results.  The amendment requires expanded disclosures for discontinued operations and also requires additional disclosures regarding disposals of individually significant components that do not qualify as discontinued operations. Early adoption is permitted, but only for disposals (or classifications as held for sale) that have not been reported in financial statements previously issued or available for issuance. This amendment has no impact on our current disclosures, but will in the future if we dispose of any individually significant components.

Inventories

Inventories	3 Months Ended
	Mar. 31, 2014
Inventories [Abstract]	'
Inventories	'
	Note 4 — Inventories
	The components of inventories consisted of the following:
		31-Mar-14		31-Dec-13
	Commodities	$	74.7	$	136.4
	Materials and supplies		13.8		14.3
		$	88.5	$	150.7

Property_Plant_and_Equipment_a

Property, Plant and Equipment and Intangible Assets	3 Months Ended
	Mar. 31, 2014
Property, Plant and Equipment and Intangible Assets [Abstract]	'
Property, Plant and Equipment and Intangible Assets	'
	Note 5 — Property, Plant and Equipment and Intangible Assets
								Estimated useful life
		31-Mar-14			31-Dec-13			(In Years)
	Gathering systems	$	2,293.60		$	2,230.10		5 to 20
	Processing and fractionation facilities		1,600.70			1,598.00		5 to 25
	Terminaling and storage facilities		735.4			715.2		5 to 25
	Transportation assets		334.7			294.7		10 to 25
	Other property, plant and equipment		124.8			121.3		3 to 25
	Land		89.7			89.5			-
	Construction in progress		751.2			702.8			-
	Property, plant and equipment		5,930.10			5,751.60
	Accumulated depreciation		(1,470.3	)		(1,406.2	)
	Property, plant and equipment, net	$	4,459.80		$	4,345.40
	Intangible assets	$	681.8		$	681.8			20
	Accumulated amortization		(43.7	)		(28.4	)
	Intangible assets, net	$	638.1		$	653.4

Asset_Retirement_Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2014
Asset Retirement Obligations [Abstract]	'
Asset Retirement Obligations	'
	Note 6 — Asset Retirement Obligations
	Our asset retirement obligations primarily relate to certain gas gathering pipelines and processing facilities, and are included in our consolidated balance sheets as a component of other long-term liabilities. The changes in our aggregate asset retirement obligations are as follows:
		Three Months Ended
		31-Mar-14
	Beginning of period	$	50.5
	Change in cash flow estimate		2.1
	Accretion expense		1.2
	End of period	$	53.8

Investment_in_Unconsolidated_A

Investment in Unconsolidated Affiliate	3 Months Ended
	Mar. 31, 2014
Investment in Unconsolidated Affiliate [Abstract]	'
Investment in Unconsolidated Affiliate	'
	Note 7 — Investment in Unconsolidated Affiliate
	At March 31, 2014 our unconsolidated investment consisted of a 38.8% ownership interest in Gulf Coast Fractionators LP ("GCF").
	The following table shows the activity related to our investment in GCF:
			Three Months Ended
			31-Mar-14
	Beginning of period		$	55.9
	Equity earnings			4.9
	Cash distributions (1)			(7.1	)
	End of period		$	53.7
	___________
	-1	Includes distributions in excess of cumulative earnings of $2.2 million that are considered a return of capital and disclosed in cash flows from investing activities in the Consolidated Statements of Cash Flows.

Accounts_Payable_and_Accrued_L

Accounts Payable and Accrued Liabilities	3 Months Ended
	Mar. 31, 2014
Accounts Payable and Accrued Liabilities [Abstract]	'
Accounts Payable and Accrued Liabilities	'
	Note 8 — Accounts Payable and Accrued Liabilities
	The components of accounts payable and accrued liabilities consisted of the following:
		31-Mar-14		31-Dec-13
	Commodities	$	528.1	$	520.8
	Other goods and services		108.5		145.1
	Interest		42.3		35.8
	Compensation and benefits		1.7		1.3
	Income and other taxes		12		11.1
	Other		6.2		7.1
		$	698.8	$	721.2

Debt_Obligations

Debt Obligations	3 Months Ended
	Mar. 31, 2014
Debt Obligations [Abstract]	'
Debt Obligations	'
	Note 9 — Debt Obligations
			31-Mar-14			31-Dec-13
	Senior secured revolving credit facility, variable rate, due October 2017 (1)		$	355		$	395
	Senior unsecured notes, 7⅞% fixed rate, due October 2018			250			250
	Senior unsecured notes, 6⅞% fixed rate, due February 2021			483.6			483.6
	Unamortized discount			(27.4	)		(28.0	)
	Senior unsecured notes, 6⅜% fixed rate, due August 2022			300			300
	Senior unsecured notes, 5¼% fixed rate, due May 2023			600			600
	Senior unsecured notes, 4¼% fixed rate, due November 2023			625			625
	Accounts receivable securitization facility, due December 2014 (2)			233.5			279.7
	Total long-term debt		$	2,819.70		$	2,905.30
	Letters of credit outstanding (1)		$	97.2		$	86.8
	________
	-1	As of March 31, 2014, availability under our $1.2 billion senior secured revolving credit facility was $747.8 million.
	-2	All amounts outstanding under the Securitization Facility are reflected as long-term debt in our balance sheet because we have the ability and intent to fund the Securitization Facility's borrowings on a long-term basis.
	The following table shows the range of interest rates and weighted average interest rate incurred on our variable-rate debt obligations during the three months ended March 31, 2014:
			Range of Interest Rates Incurred			Weighted Average Interest Rate Incurred
	Senior secured revolving credit facility			2.2% - 4.5	%		2.3	%
	Accounts receivable securitization facility			0.9	%		0.9	%
	Compliance with Debt Covenants
	As of March 31, 2014, we were in compliance with the covenants contained in our various debt agreements.

Partnership_Units_and_Related_

Partnership Units and Related Matters

3 Months Ended

Mar. 31, 2014

Partnership Units and Related Matters [Abstract]

'

Partnership Units and Related Matters

'

Note 10 — Partnership Units and Related Matters

Public Offerings of Common Units

During 2014, we issued 2,222,271 common units under an equity distribution agreement entered into in August 2013 (the "August 2013 EDA"), receiving net proceeds of $115.3 million, of which $5.9 million was received in April. Targa contributed $2.4 million to us to maintain its 2% general partner interest, of which $1.2 million was received in April.

Subsequent Event

In April 2014, we issued 802,630 common units under the August 2013 EDA, receiving net proceeds of $47.7 million. Targa contributed $1.0 million to us to maintain its 2% general partner interest. As of April 18, 2014, approximately $7.4 million of the aggregate offering amount remained available for sale pursuant to the August 2013 EDA.

Distributions

In accordance with the Partnership Agreement, we must distribute all of our available cash, as determined by the general partner, to unitholders of record within 45 days after the end of each quarter. The following table details the distributions declared and/or paid by us for the three months ended March 31, 2014.

Distributions

Three Months Ended

Date Paid or to be Paid

Limited Partners

General Partner

Distributions per Limited Partner Unit

Common

Incentive

2

%

Total

(In millions, except per unit amounts)

31-Mar-14

15-May-14

$

87.2

$

31.7

$

2.4

$

121.3

$

0.7625

31-Dec-13

14-Feb-14

84

29.5

2.3

115.8

0.7475

Earnings_per_Limited_Partner_U

Earnings per Limited Partner Unit	3 Months Ended
	Mar. 31, 2014
Earnings per Limited Partner Unit [Abstract]	'
Earnings per Limited Partner Unit	'
	Note 11 — Earnings per Limited Partner Unit
	The following table sets forth a reconciliation of net income and weighted average shares outstanding used in computing basic and diluted net income per limited partner:
		Three Months Ended March 31,
		2014		2013
	Net income	$	131.3	$	45.3
	Less: Net income attributable to noncontrolling interests		8.9		6.4
	Net income attributable to Targa Resources Partners LP	$	122.4	$	38.9
	Net income attributable to general partner	$	33.8	$	22.8
	Net income attributable to limited partners		88.6		16.1
	Net income attributable to Targa Resources Partners LP	$	122.4	$	38.9
	Weighted average units outstanding - basic		112.4		101.8
	Net income available per limited partner unit - basic	$	0.79	$	0.16
	Weighted average units outstanding		112.4		101.8
	Dilutive effect of unvested stock awards		0.6		0.2
	Weighted average units outstanding - diluted		113		102
	Net income available per limited partner unit - diluted	$	0.78	$	0.16

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	3 Months Ended
	Mar. 31, 2014
Derivative Instruments and Hedging Activities [Abstract]	'
Derivative Instruments and Hedging Activities	'
	Note 12 — Derivative Instruments and Hedging Activities
	Commodity Hedges
	The primary purpose of our commodity risk management activities is to manage our exposure to commodity price risk and reduce volatility in our operating cash flow due to fluctuations in commodity prices. We have hedged the commodity prices associated with a portion of our expected (i) natural gas equity volumes in our Field Gathering and Processing segment and (ii) NGL and condensate equity volumes predominately in our Field Gathering and Processing segment and the LOU business unit in our Coastal Gathering and Processing segment that result from its percent-of-proceeds processing arrangements. These hedge positions will move favorably in periods of falling commodity prices and unfavorably in periods of rising commodity prices. We have designated these derivative contracts as cash flow hedges for accounting purposes.
	The hedges generally match the NGL product composition and the NGL and natural gas delivery points to those of our physical equity volumes. The NGL hedges may be transacted as specific NGL hedges or as baskets of ethane, propane, normal butane, isobutane and natural gasoline based upon our expected equity NGL composition. We believe this approach avoids uncorrelated risks resulting from employing hedges on crude oil or other petroleum products as "proxy" hedges of NGL prices. Our natural gas and NGL hedges are settled using published index prices for delivery at various locations, which closely approximate our actual natural gas and NGL delivery points.
	We hedge a portion of our condensate equity volumes using crude oil hedges that are based on the New York Mercantile Exchange ("NYMEX") futures contracts for West Texas Intermediate light, sweet crude, which approximates the prices received for condensate. This necessarily exposes us to a market differential risk if the NYMEX futures do not move in exact parity with the sales price of our underlying condensate equity volumes.
	At March 31, 2014, the notional volumes of our commodity hedges for equity volumes were:
	Commodity		Instrument		Unit		2014				2015			2016
	Natural Gas		Swaps		MMBtu/d			54,050				40,551			25,500
	NGL		Swaps		Bbl/d			1,125				-			-
	Condensate		Swaps		Bbl/d			2,450				-			-
	We also enter into derivative instruments to help manage other short-term commodity-related business risks. We have not designated these derivatives as hedges, and we record changes in fair value and cash settlements to revenues.
	Our derivative contracts are subject to netting arrangements that allow net cash settlement of offsetting asset and liability positions with the same counterparty. We record derivative assets and liabilities on our Consolidated Balance Sheets on a gross basis, without considering the effect of master netting arrangements. The following schedules reflect the fair values of our derivative instruments and their location in our Consolidated Balance Sheets as well as pro forma reporting assuming that we reported derivatives subject to master netting agreements on a net basis:
				Fair Value as of March 31, 2014								Fair Value as of December 31, 2013
		Balance Sheet		Derivative				Derivative				Derivative			Derivative
		Location		Assets				Liabilities				Assets			Liabilities
	Derivatives designated as hedging instruments
	Commodity contracts	Current		$	1.6			$	(12.8	)		$	2		$	(7.7	)
		Long-term			2.9				(1.2	)			3.1			(1.4	)
	Total derivatives designated as hedging instruments			$	4.5			$	(14.0	)		$	5.1		$	(9.1	)
	Derivatives not designated as hedging instruments
	Commodity contracts	Current		$	-			$	(0.1	)		$	-		$	(0.3	)
	Total derivatives not designated as hedging instruments			$	-			$	(0.1	)		$	-		$	(0.3	)
	Total current position			$	1.6			$	(12.9	)		$	2		$	(8.0	)
	Total long-term position				2.9				(1.2	)			3.1			(1.4	)
	Total derivatives			$	4.5			$	(14.1	)		$	5.1		$	(9.4	)
	The pro forma impact of reporting derivatives in the Consolidated Balance Sheets is as follows:
			Gross Presentation								Pro forma Net Presentation
			Asset				Liability				Asset			Liability
	31-Mar-14		Position				Position				Position			Position
	Current position
	Counterparties with offsetting position		$	1.6			$	(3.4	)		$	-		$	(1.8	)
	Counterparties without offsetting position - assets			-				-				-			-
	Counterparties without offsetting position - liabilities			-				(9.5	)			-			(9.5	)
				1.6				(12.9	)			-			(11.3	)
	Long-term position
	Counterparties with offsetting position			1				(0.3	)			0.7			-
	Counterparties without offsetting position - assets			1.9				-				1.9			-
	Counterparties without offsetting position - liabilities			-				(0.9	)			-			(0.9	)
				2.9				(1.2	)			2.6			(0.9	)
	Total derivatives
	Counterparties with offsetting position			2.6				(3.7	)			0.7			(1.8	)
	Counterparties without offsetting position - assets			1.9				-				1.9			-
	Counterparties without offsetting position - liabilities			-				(10.4	)			-			(10.4	)
			$	4.5			$	(14.1	)		$	2.6		$	(12.2	)
	31-Dec-13
	Current position
	Counterparties with offsetting position		$	1.9			$	(4.4	)		$	-		$	(2.5	)
	Counterparties without offsetting position - assets			0.1				-				0.1			-
	Counterparties without offsetting position - liabilities			-				(3.6	)			-			(3.6	)
				2				(8.0	)			0.1			(6.1	)
	Long-term position
	Counterparties with offsetting position			0.7				(1.2	)			-			(0.5	)
	Counterparties without offsetting position - assets			2.4				-				2.4			-
	Counterparties without offsetting position - liabilities			-				(0.2	)			-			(0.2	)
				3.1				(1.4	)			2.4			(0.7	)
	Total derivatives
	Counterparties with offsetting position			2.6				(5.6	)			-			(3.0	)
	Counterparties without offsetting position - assets			2.5				-				2.5			-
	Counterparties without offsetting position - liabilities			-				(3.8	)			-			(3.8	)
			$	5.1			$	(9.4	)		$	2.5		$	(6.8	)
	The fair value of our derivative instruments, depending on the type of instrument, was determined by the use of present value methods or standard option valuation models with assumptions about commodity prices based on those observed in underlying markets.
	The estimated fair value of our derivative instruments was a net liability of $9.6 million as of March 31, 2014. The estimated fair value is net of an adjustment for credit risk based on the default probabilities by year as indicated by market quotes for the counterparties' credit default swap rates. The credit risk adjustment was immaterial for all periods presented.
	Our payment obligations in connection with substantially all of these hedging transactions are secured by a first priority lien in the collateral securing our senior secured indebtedness that ranks equal in right of payment with liens granted in favor of our senior secured lenders.
The following tables reflect amounts recorded in OCI and amounts reclassified from OCI to revenue and expense for the periods indicated:
	Gain (Loss) Recognized in OCI on Derivatives
	(Effective Portion)
	Three Months Ended March 31,
Derivatives in Cash Flow Hedging Relationships		2014				2013
Commodity contracts		$	(11.9	)		$	(7.6	)
	Gain (Loss) Reclassified from OCI into Income
	(Effective Portion)
Location of Gain (Loss)	Three Months Ended March 31,
	2014				2013
Interest expense, net		$	(1.3	)		$	(1.7	)
Revenues			(6.3	)			6.6
		$	(7.6	)		$	4.9
Hedge ineffectiveness was immaterial for all periods presented.
Our consolidated earnings are also affected by our use of the mark-to-market method of accounting for derivative instruments that do not qualify for hedge accounting or that have not been designated as hedges. The changes in fair value of these instruments are recorded on the balance sheet and through earnings (i.e., using the "mark-to-market" method) rather than being deferred until the anticipated transaction settles. The use of mark-to-market accounting for financial instruments can cause non-cash earnings volatility due to changes in the underlying commodity price indices. Gain (loss) recognized on commodity derivatives not designated as hedging instruments was immaterial for all periods presented.
The following table shows the deferred gains (losses) included in accumulated OCI that will be reclassified into earnings through the end of 2016:
		31-Mar-14				31-Dec-13
Commodity hedges		$	(9.4	)		$	(3.7	)
Interest rate hedges			(1.1	)			(2.4	)
As of March 31, 2014, net losses of $11.0 million on commodity hedges and net losses of $1.1 million on terminated interest rate swaps recorded in OCI are expected to be reclassified to revenue and interest expense during the next twelve months.
See Note 13 for additional disclosures related to derivative instruments and hedging activities.

Fair_Value_Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2014
Fair Value Measurements [Abstract]	'
Fair Value Measurements	'
	Note 13 — Fair Value Measurements
	Under GAAP, our Consolidated Balance Sheets reflect a mixture of measurement methods for financial assets and liabilities ("financial instruments"). Derivative financial instruments are reported at fair value in our Consolidated Balance Sheets. Other financial instruments are reported at historical cost or amortized cost in our Consolidated Balance Sheets, with fair value measurements for these instruments provided as supplemental information.
	The following are additional qualitative and quantitative disclosures regarding fair value measurements of financial instruments.
	Fair Value of Derivative Financial Instruments
	Our derivative instruments consist of financially settled commodity swaps and option contracts and fixed-price commodity contracts with certain counterparties. We determine the fair value of our derivative contracts using a discounted cash flow model for swaps and a standard option-pricing model for options, based on inputs that are readily available in public markets. We have consistently applied these valuation techniques in all periods presented and believe we have obtained the most accurate information available for the types of derivative contracts we hold.
	The fair values of our derivative instruments are sensitive to changes in forward pricing on natural gas, NGLs and crude oil. This financial position reflects the present value, adjusted for counterparty credit risk, of the amount we expect to receive or pay in the future on our derivative contracts. If forward pricing on natural gas, NGLs and crude oil were to increase by 10%, the result would be a fair value reflecting a net liability of $33.1 million, ignoring an adjustment for counterparty credit risk. If forward pricing on natural gas, NGLs and crude oil were to decrease by 10%, the result would be a fair value reflecting a net asset of $13.8 million, ignoring an adjustment for counterparty credit risk.
	Fair Value of Other Financial Instruments
	The contingent consideration obligation related to our Badlands acquisition is reported at fair value. Due to their cash or near-cash nature, the carrying value of other financial instruments included in working capital (i.e., cash and cash equivalents, accounts receivable, accounts payable) approximates their fair value. As such, long-term debt is primarily the other financial instrument for which our carrying value could vary significantly from fair value. We determined the supplemental fair value disclosures for our long-term debt as follows:
	·	Senior secured revolving credit facility and accounts receivable securitization facility are based on carrying value, which approximates fair value as its interest rate is based on prevailing market rates; and
	·	Senior unsecured notes are based on quoted market prices derived from trades of the debt.
	Fair Value Hierarchy
	We categorize the inputs to the fair value measurements of financial assets and liabilities using a three-tier fair value hierarchy that prioritizes the significant inputs used in measuring fair value:
	·	Level 1 – observable inputs such as quoted prices in active markets;
	·	Level 2 – inputs other than quoted prices in active markets that we can directly or indirectly observe to the extent that the markets are liquid for the relevant settlement periods; and
	·	Level 3 – unobservable inputs in which little or no market data exists, therefore we must develop our own assumptions.
	The following table shows a breakdown by fair value hierarchy category for (1) financial instruments measurements included in our Consolidated Balance Sheets at fair value and (2) supplemental fair value disclosures for other financial instruments:
			31-Mar-14
			Carrying Value			Fair Value
						Total		Level 1		Level 2		Level 3
	Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value:
	Assets from commodity derivative contracts (1)		$	3.9		$	3.9	$	-	$	2.6	$	1.3
	Liabilities from commodity derivative contracts (1)			13.5			13.5		-		12		1.5
	Badlands contingent consideration liability			-			-		-		-		-
	Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
	Cash and cash equivalents			81.4			81.4		-		-		-
	Senior secured revolving credit facility			355			355		-		355		-
	Senior unsecured notes			2,231.20			2,284.00		-		2,284.00		-
	Accounts receivable securitization facility			233.5			233.5		-		233.5		-
	___________
	-1	The fair value of our derivative contracts in this table is presented on a different basis than the balance sheet presentation as disclosed in Note 12. The above fair values reflect the total value of each derivative contract taken as a whole, whereas the balance sheet presentation is based on the individual maturity dates of estimated future settlements.  As such, an individual contract could have both an asset and liability position when segregated into its current and long-term portions for balance sheet classification purposes.
	Additional Information Regarding Level 3 Fair Value Measurements Included in Our Consolidated Balance Sheets
	As of March 31, 2014, we reported certain of our natural gas basis swaps at fair value using Level 3 inputs due to such derivatives not having observable market prices for substantially the full term of the derivative asset or liability. For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is categorized in Level 3. This includes derivatives valued using indicative price quotations whose contract length extends into unobservable periods.
	The fair value of these natural gas basis swaps is determined using a discounted cash flow valuation technique based on a forward commodity basis curve. For these derivatives, the primary input to the valuation model is the forward commodity basis curve, which is based on observable or public data sources and extrapolated when observable prices are not available.
	As of March 31, 2014, we had fourteen natural gas basis swaps categorized as Level 3. The significant unobservable inputs used in the fair value measurements of our Level 3 derivatives are the forward natural gas basis curves, for which a significant portion of the derivative's term is beyond available forward pricing. The change in the fair value of Level 3 derivatives associated with a 10% change in the forward basis curve where prices are not observable is immaterial.
	The following table summarizes the changes in fair value of our financial instruments classified as Level 3 in the fair value hierarchy:
			Commodity Derivative Contracts Asset /(Liability)
	Balance, December 31, 2013		$	0.7
	Settlements included in Revenue			(0.9	)
	Balance, March 31, 2014		$	(0.2	)
	There has been no material transfer of assets or liabilities among the three levels of the fair value hierarchy during the three months ended March 31, 2014.

Related_Party_Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Note 14 — Related Party Transactions
	Targa Resources Corp.
	We do not have any employees. Targa provides operational, general and administrative and other services to us, associated with our existing assets and assets acquired from third parties. Targa performs centralized corporate functions for us, such as legal, accounting, treasury, insurance, risk management, health, safety and environmental, information technology, human resources, credit, payroll, internal audit, taxes, engineering and marketing.
	The Partnership Agreement between Targa and us, with Targa as the general partner of the Partnership, governs the reimbursement of costs incurred by Targa on behalf of us. Targa charges us for all the direct costs of the employees assigned to our operations, as well as all general and administrative support costs other than (1) costs attributable to Targa's status as a separate reporting company and (2) costs of Targa providing management and support services to certain unaffiliated spun-off entities. We generally reimburse Targa monthly for cost allocations to the extent that Targa has made a cash outlay.
	The following table summarizes transactions with Targa. Management believes these transactions are executed on terms that are fair and reasonable.
		Three Months Ended March 31,
		2014		2013
	Parent billings of payroll and related costs included in operating expense	$	29.9	$	26.5
	Parent allocation of general & administrative expense		33.4		32.6
	Cash distributions to Targa based on unit ownership		41.5		30.7
	Contributions from Targa		2.4		2.3

Commitments_and_Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2014
Commitments and Contingencies [Abstract]	'
Commitments and Contingencies	'
	Note 15 — Commitments and Contingencies
	Legal Proceedings
	We are a party to various legal proceedings and/or regulatory proceedings and certain claims, suits and complaints arising in the ordinary course of business that have been filed or are pending against us. We believe all such matters are without merit or involve amounts which, if resolved unfavorably, would not have a material effect on our financial position, results of operations or cash flows.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information	3 Months Ended
	Mar. 31, 2014
Supplemental Cash Flow Information [Abstract]	'
Supplemental Cash Flow Information	'
	Note 16 — Supplemental Cash Flow Information
			Three Months Ended March 31,
			2014			2013
	Cash:
	Interest paid, net of capitalized interest (1)		$	23		$	31.4
	Income taxes paid, net of refunds			(0.2	)		-
	Non-cash:
	Deadstock inventory transferred to property, plant and equipment			1.1			4.5
	Accrued distribution equivalent rights			0.6			0.3
	Changes in receivables from unit offerings			7.1			-
	Change in capital accruals			22.7			15.5
	Transfers from materials and supplies inventory to property, plant and equipment			0.4			-
	Change in ARO cash flow estimate			2.1			0.2
	___________
	-1	Interest capitalized on major projects was $6.9 million and $6.1 million for the three months ended March 31, 2014 and 2013.

Segment_Information

Segment Information	3 Months Ended
	Mar. 31, 2014
Segment Information [Abstract]	'
Segment Information	'
	Note 17 — Segment Information
	We report our operations in two divisions: (i) Gathering and Processing, consisting of two reportable segments – (a) Field Gathering and Processing and (b) Coastal Gathering and Processing; and (ii) Logistics and Marketing consisting of two reportable segments – (a) Logistics Assets and (b) Marketing and Distribution. The financial results of our hedging activities are reported in Other.
	Our Gathering and Processing division includes assets used in the gathering of natural gas produced from oil and gas wells and processing this raw natural gas into merchantable natural gas by extracting NGLs and removing impurities; and assets used for crude oil gathering and terminaling. The Field Gathering and Processing segment's assets are located in North Texas, the Permian Basin of West Texas, New Mexico and in North Dakota. The Coastal Gathering and Processing segment's assets are located in the onshore and near offshore regions of the Louisiana Gulf Coast and the Gulf of Mexico.
	Our Logistics and Marketing division is also referred to as our Downstream Business. Our Downstream Business includes all the activities necessary to convert mixed NGLs into NGL products and provides certain value added services such as storing, terminaling, distributing and marketing of NGLs, refined petroleum products and crude oil. It also includes certain natural gas supply and marketing activities in support of our other operations, including services to LPG exporters, as well as transporting natural gas and NGLs.
	Our Logistics Assets segment is involved in transporting, storing, and fractionating mixed NGLs; storing, terminaling, and transporting finished NGLs, including services for exported LPGs; and storing and terminaling refined petroleum products. These assets are generally connected to and supplied in part by our Gathering and Processing segments and are predominantly located in Mont Belvieu, and Galena Park, Texas and Lake Charles, Louisiana.
	Our Marketing and Distribution segment covers activities required to distribute and market raw and finished NGLs and all natural gas marketing activities. It includes (1) marketing our own NGL production and purchasing NGL products for resale in selected United States markets; (2) providing LPG balancing services to refinery customers; (3) transporting, storing and selling propane and providing related propane logistics services to multi-state retailers, independent retailers and other end-users; (4) providing propane, butane and services to LPG exporters; and (5) marketing natural gas available to us from our Gathering and Processing division and the purchase and resale and other value added activities related to third-party natural gas in selected United States markets.
	Other contains the results of our commodity hedging activities included in operating margin. Eliminations of inter-segment transactions are reflected in the corporate and eliminations column.
	Our reportable segment information is shown in the following tables:
		Three Months Ended March 31, 2014
		Field			Coastal
		Gathering			Gathering					Marketing					Corporate
		and			and			Logistics		and					and
		Processing			Processing			Assets		Distribution		Other			Eliminations			Total
	Revenues
	Sales of commodities	$	45.8		$	100.5		$	21	$	1,983.70	$	(6.1	)	$	(0.1	)	$	2,144.80
	Fees from midstream services		40.8			7.7			68.1		91.3		-			0.2			208.1
			86.6			108.2			89.1		2,075.00		(6.1	)		0.1			2,352.90
	Intersegment revenues
	Sales of commodities		400.4			177			0.6		130.4		-			(708.4	)		-
	Fees from midstream services		1.1			-			66.2		7.9		-			(75.2	)		-
			401.5			177			66.8		138.3		-			(783.6	)		-
	Revenues	$	488.1		$	285.2		$	155.9	$	2,213.30	$	(6.1	)	$	(783.5	)	$	2,352.90
	Operating margin	$	94.1		$	26.1		$	96.6	$	64.6	$	(6.1	)	$	-		$	275.3
	Other financial information:
	Total assets	$	3,275.10		$	385.1		$	1,568.70	$	614.1	$	4.5		$	128.8		$	5,976.30
	Capital expenditures	$	98.9		$	4.3		$	68.6	$	3.1	$	-		$	0.5		$	175.4
		Three Months Ended March 31, 2013
		Field			Coastal
		Gathering			Gathering					Marketing					Corporate
		and			and			Logistics		and					and
		Processing			Processing			Assets		Distribution		Other			Eliminations			Total
	Revenues
	Sales of commodities	$	38.1		$	69.6		$	32.9	$	1,136.50	$	6.6		$	-		$	1,283.70
	Fees from midstream services		20.2			8.8			47.1		38		-			-			114.1
			58.3			78.4			80		1,174.50		6.6			-			1,397.80
	Intersegment revenues
	Sales of commodities		273			151.9			0.9		110.5		-			(536.3	)		-
	Fees from midstream services		0.9			-			36.6		6.4		-			(43.9	)		-
			273.9			151.9			37.5		116.9		-			(580.2	)		-
	Revenues	$	332.2		$	230.3		$	117.5	$	1,291.40	$	6.6		$	(580.2	)	$	1,397.80
	Operating margin	$	53.8		$	23.5		$	56.3	$	34	$	6.6		$	-		$	174.2
	Other financial information:
	Total assets	$	2,854.70		$	416.3		$	1,210.70	$	436.9	$	21.4		$	134.2		$	5,074.20
	Capital expenditures	$	96.1		$	6.5		$	103.7	$	-	$	-		$	0.6		$	206.9
	The following table shows our consolidated revenues by product and service for the periods presented:
		Three Months Ended March 31,
		2014			2013
	Sales of commodities
	Natural gas	$	392.6		$	255.3
	NGL		1,710.60			963.5
	Condensate		28.4			27.1
	Petroleum products		20.1			31.3
	Derivative activities		(6.9	)		6.5
			2,144.80			1,283.70
	Fees from midstream services
	Fractionating and treating		46.5			27.2
	Storage, terminaling, transportation and export		99.6			60.2
	Gathering and processing		42.6			18.5
	Other		19.4			8.2
			208.1			114.1
	Total revenues	$	2,352.90		$	1,397.80
	The following table shows a reconciliation of operating margin to net income for the periods presented:
		Three Months Ended March 31,
	2014			2013
Reconciliation of operating margin to net income:
Operating margin	$	275.3		$	174.2
Depreciation and amortization expense		(79.5	)		(63.9	)
General and administrative expense		(35.9	)		(34.1	)
Interest expense, net		(33.1	)		(31.4	)
Other, net		5.6			1.4
Income tax expense		(1.1	)		(0.9	)
Net income	$	131.3		$	45.3

Basis_of_Presentation_Policies

Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2014
Basis of Presentation [Abstract]	'
Reclassifications Affecting Statement of Cash Flows	'
	Reclassifications Affecting Statement of Cash Flows
	In conjunction with the ongoing integration of Badlands into our financial reporting environment during 2013, we obtained further information about acquisition date balance sheet, including the nature of the items comprising assumed Accounts payable and accrued liabilities. We determined that certain assumed liabilities related to purchases that, under our accounting policies, we considered capital in nature. Consequently, we made certain refinements to better reflect Badlands cash flow activity on a basis similar to that used for our other operations. As a result of these refinements, certain Badlands cash flow activity was presented in our 2013 Form 10-K on a basis different than that utilized for previous quarterly reporting during 2013. In preparing this quarterly report we have made certain measurement period reclassifications to the comparative Statement of Cash Flows for the three months ended March 31, 2013 to conform to the presentation of our Form 10-K, reclassifying $18.9 million related to capital expenditures previously included in Accounts payable and other liabilities of operating activities to Outlays for property, plant and equipment in investing activities, as shown below.
		Three Months Ended March 31, 2013
	Revised line items Consolidated Statement of Cash Flows	As Reported			Reclassification			Revised
	Cash Flows from operating activities
	Changes in operating assets and liabilities:
	Accounts payable and other liabilities	$	(64.3	)	$	18.9		$	(45.4	)
	Net cash provided by operating activities		171.7			18.9			190.6
	Cash flows from investing activities:
	Changes in investing assets and liabilities:
	Outlays for property, plant and equipment		(203.5	)		(18.9	)		(222.4	)
	Net cash used in investing activities		(208.1	)		(18.9	)		(227.0	)

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2014
Significant Accounting Policies [Abstract]	'
Accounting Policy Updates/Revisions	'
	Accounting Policy Updates/Revisions
	The accounting policies that we follow are set forth in Note 3 of the Notes to Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 2013. There were no significant updates or revisions to these policies during the three months ended March 31, 2014.
Recent Accounting Pronouncements	'
	Recent Accounting Pronouncements
	In April 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update No 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. The amendment, required to be applied prospectively for reporting periods beginning after December 15, 2014, limits discontinued operations reporting to disposals of components of an entity that represent strategic shifts that have, or will have, a major effect on operations and financial results.  The amendment requires expanded disclosures for discontinued operations and also requires additional disclosures regarding disposals of individually significant components that do not qualify as discontinued operations. Early adoption is permitted, but only for disposals (or classifications as held for sale) that have not been reported in financial statements previously issued or available for issuance. This amendment has no impact on our current disclosures, but will in the future if we dispose of any individually significant components.

Basis_of_Presentation_Tables

Basis of Presentation (Tables)	3 Months Ended
	Mar. 31, 2014
Basis of Presentation [Abstract]	'
Certain Measurement Period Reclassifications Made to Comparative Statement of Cash Flows	'
	In preparing this quarterly report we have made certain measurement period reclassifications to the comparative Statement of Cash Flows for the three months ended March 31, 2013 to conform to the presentation of our Form 10-K, reclassifying $18.9 million related to capital expenditures previously included in Accounts payable and other liabilities of operating activities to Outlays for property, plant and equipment in investing activities, as shown below.
		Three Months Ended March 31, 2013
	Revised line items Consolidated Statement of Cash Flows	As Reported			Reclassification			Revised
	Cash Flows from operating activities
	Changes in operating assets and liabilities:
	Accounts payable and other liabilities	$	(64.3	)	$	18.9		$	(45.4	)
	Net cash provided by operating activities		171.7			18.9			190.6
	Cash flows from investing activities:
	Changes in investing assets and liabilities:
	Outlays for property, plant and equipment		(203.5	)		(18.9	)		(222.4	)
	Net cash used in investing activities		(208.1	)		(18.9	)		(227.0	)

Inventories_Tables

Inventories (Tables)	3 Months Ended
	Mar. 31, 2014
Inventories [Abstract]	'
Components of inventory	'
	The components of inventories consisted of the following:
		31-Mar-14		31-Dec-13
	Commodities	$	74.7	$	136.4
	Materials and supplies		13.8		14.3
		$	88.5	$	150.7

Property_Plant_and_Equipment_a1

Property, Plant and Equipment and Intangible Assets (Tables)	3 Months Ended
	Mar. 31, 2014
Property, Plant and Equipment and Intangible Assets [Abstract]	'
Property, Plant and Equipment and Intangible Assets	'
								Estimated useful life
		31-Mar-14			31-Dec-13			(In Years)
	Gathering systems	$	2,293.60		$	2,230.10		5 to 20
	Processing and fractionation facilities		1,600.70			1,598.00		5 to 25
	Terminaling and storage facilities		735.4			715.2		5 to 25
	Transportation assets		334.7			294.7		10 to 25
	Other property, plant and equipment		124.8			121.3		3 to 25
	Land		89.7			89.5			-
	Construction in progress		751.2			702.8			-
	Property, plant and equipment		5,930.10			5,751.60
	Accumulated depreciation		(1,470.3	)		(1,406.2	)
	Property, plant and equipment, net	$	4,459.80		$	4,345.40
	Intangible assets	$	681.8		$	681.8			20
	Accumulated amortization		(43.7	)		(28.4	)
	Intangible assets, net	$	638.1		$	653.4

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2014
Asset Retirement Obligations [Abstract]	'
Changes in Aggregate Asset Retirement Obligations	'
	Our asset retirement obligations primarily relate to certain gas gathering pipelines and processing facilities, and are included in our consolidated balance sheets as a component of other long-term liabilities. The changes in our aggregate asset retirement obligations are as follows:
		Three Months Ended
		31-Mar-14
	Beginning of period	$	50.5
	Change in cash flow estimate		2.1
	Accretion expense		1.2
	End of period	$	53.8

Investment_in_Unconsolidated_A1

Investment in Unconsolidated Affiliate (Tables)	3 Months Ended
	Mar. 31, 2014
Investment in Unconsolidated Affiliate [Abstract]	'
Activity Related to Investment in Unconsolidated Affiliate	'
	The following table shows the activity related to our investment in GCF:
			Three Months Ended
			31-Mar-14
	Beginning of period		$	55.9
	Equity earnings			4.9
	Cash distributions (1)			(7.1	)
	End of period		$	53.7
	___________
	-1	Includes distributions in excess of cumulative earnings of $2.2 million that are considered a return of capital and disclosed in cash flows from investing activities in the Consolidated Statements of Cash Flows.

Accounts_Payable_and_Accrued_L1

Accounts Payable and Accrued Liabilities (Tables)	3 Months Ended
	Mar. 31, 2014
Accounts Payable and Accrued Liabilities [Abstract]	'
Schedule of Accounts Payable and Accrued Liabilities	'
	The components of accounts payable and accrued liabilities consisted of the following:
		31-Mar-14		31-Dec-13
	Commodities	$	528.1	$	520.8
	Other goods and services		108.5		145.1
	Interest		42.3		35.8
	Compensation and benefits		1.7		1.3
	Income and other taxes		12		11.1
	Other		6.2		7.1
		$	698.8	$	721.2

Debt_Obligations_Tables

Debt Obligations (Tables)	3 Months Ended
	Mar. 31, 2014
Debt Obligations [Abstract]	'
Schedule of Outstanding Debt	'
			31-Mar-14			31-Dec-13
	Senior secured revolving credit facility, variable rate, due October 2017 (1)		$	355		$	395
	Senior unsecured notes, 7⅞% fixed rate, due October 2018			250			250
	Senior unsecured notes, 6⅞% fixed rate, due February 2021			483.6			483.6
	Unamortized discount			(27.4	)		(28.0	)
	Senior unsecured notes, 6⅜% fixed rate, due August 2022			300			300
	Senior unsecured notes, 5¼% fixed rate, due May 2023			600			600
	Senior unsecured notes, 4¼% fixed rate, due November 2023			625			625
	Accounts receivable securitization facility, due December 2014 (2)			233.5			279.7
	Total long-term debt		$	2,819.70		$	2,905.30
	Letters of credit outstanding (1)		$	97.2		$	86.8
	________
	-1	As of March 31, 2014, availability under our $1.2 billion senior secured revolving credit facility was $747.8 million.
	-2	All amounts outstanding under the Securitization Facility are reflected as long-term debt in our balance sheet because we have the ability and intent to fund the Securitization Facility's borrowings on a long-term basis.
Interest Rates Incurred on Variable-Rate Debt Obligations	'
	The following table shows the range of interest rates and weighted average interest rate incurred on our variable-rate debt obligations during the three months ended March 31, 2014:
			Range of Interest Rates Incurred			Weighted Average Interest Rate Incurred
	Senior secured revolving credit facility			2.2% - 4.5	%		2.3	%
	Accounts receivable securitization facility			0.9	%		0.9	%

Partnership_Units_and_Related_1

Partnership Units and Related Matters (Tables)	3 Months Ended
	Mar. 31, 2014
Partnership Units and Related Matters [Abstract]	'
Schedule of Distributions	'
	The following table details the distributions declared and/or paid by us for the three months ended March 31, 2014.
			Distributions
	Three Months Ended	Date Paid or to be Paid	Limited Partners			General Partner									Distributions per Limited Partner Unit
			Common			Incentive				2	%	Total
			(In millions, except per unit amounts)
	31-Mar-14	15-May-14		$	87.2		$	31.7	$	2.4			$	121.3		$	0.7625
	31-Dec-13	14-Feb-14			84			29.5		2.3				115.8			0.7475

Earnings_per_Limited_Partner_U1

Earnings per Limited Partner Unit (Tables)	3 Months Ended
	Mar. 31, 2014
Earnings per Limited Partner Unit [Abstract]	'
Earnings per Limited Partner Unit	'
	The following table sets forth a reconciliation of net income and weighted average shares outstanding used in computing basic and diluted net income per limited partner:
		Three Months Ended March 31,
		2014		2013
	Net income	$	131.3	$	45.3
	Less: Net income attributable to noncontrolling interests		8.9		6.4
	Net income attributable to Targa Resources Partners LP	$	122.4	$	38.9
	Net income attributable to general partner	$	33.8	$	22.8
	Net income attributable to limited partners		88.6		16.1
	Net income attributable to Targa Resources Partners LP	$	122.4	$	38.9
	Weighted average units outstanding - basic		112.4		101.8
	Net income available per limited partner unit - basic	$	0.79	$	0.16
	Weighted average units outstanding		112.4		101.8
	Dilutive effect of unvested stock awards		0.6		0.2
	Weighted average units outstanding - diluted		113		102
	Net income available per limited partner unit - diluted	$	0.78	$	0.16

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Tables)	3 Months Ended
	Mar. 31, 2014
Derivative Instruments and Hedging Activities [Abstract]	'
Notional Volume of Commodity Hedges	'
	At March 31, 2014, the notional volumes of our commodity hedges for equity volumes were:
	Commodity		Instrument		Unit		2014				2015			2016
	Natural Gas		Swaps		MMBtu/d			54,050				40,551			25,500
	NGL		Swaps		Bbl/d			1,125				-			-
	Condensate		Swaps		Bbl/d			2,450				-			-
Fair Values of Derivative Instruments	'
	The following schedules reflect the fair values of our derivative instruments and their location in our Consolidated Balance Sheets as well as pro forma reporting assuming that we reported derivatives subject to master netting agreements on a net basis:
				Fair Value as of March 31, 2014								Fair Value as of December 31, 2013
		Balance Sheet		Derivative				Derivative				Derivative			Derivative
		Location		Assets				Liabilities				Assets			Liabilities
	Derivatives designated as hedging instruments
	Commodity contracts	Current		$	1.6			$	(12.8	)		$	2		$	(7.7	)
		Long-term			2.9				(1.2	)			3.1			(1.4	)
	Total derivatives designated as hedging instruments			$	4.5			$	(14.0	)		$	5.1		$	(9.1	)
	Derivatives not designated as hedging instruments
	Commodity contracts	Current		$	-			$	(0.1	)		$	-		$	(0.3	)
	Total derivatives not designated as hedging instruments			$	-			$	(0.1	)		$	-		$	(0.3	)
	Total current position			$	1.6			$	(12.9	)		$	2		$	(8.0	)
	Total long-term position				2.9				(1.2	)			3.1			(1.4	)
	Total derivatives			$	4.5			$	(14.1	)		$	5.1		$	(9.4	)
Pro Forma Impact of Derivatives Net In Consolidated Balance Sheet	'
	The pro forma impact of reporting derivatives in the Consolidated Balance Sheets is as follows:
			Gross Presentation								Pro forma Net Presentation
			Asset				Liability				Asset			Liability
	31-Mar-14		Position				Position				Position			Position
	Current position
	Counterparties with offsetting position		$	1.6			$	(3.4	)		$	-		$	(1.8	)
	Counterparties without offsetting position - assets			-				-				-			-
	Counterparties without offsetting position - liabilities			-				(9.5	)			-			(9.5	)
				1.6				(12.9	)			-			(11.3	)
	Long-term position
	Counterparties with offsetting position			1				(0.3	)			0.7			-
	Counterparties without offsetting position - assets			1.9				-				1.9			-
	Counterparties without offsetting position - liabilities			-				(0.9	)			-			(0.9	)
				2.9				(1.2	)			2.6			(0.9	)
	Total derivatives
	Counterparties with offsetting position			2.6				(3.7	)			0.7			(1.8	)
	Counterparties without offsetting position - assets			1.9				-				1.9			-
	Counterparties without offsetting position - liabilities			-				(10.4	)			-			(10.4	)
			$	4.5			$	(14.1	)		$	2.6		$	(12.2	)
	31-Dec-13
	Current position
	Counterparties with offsetting position		$	1.9			$	(4.4	)		$	-		$	(2.5	)
	Counterparties without offsetting position - assets			0.1				-				0.1			-
	Counterparties without offsetting position - liabilities			-				(3.6	)			-			(3.6	)
				2				(8.0	)			0.1			(6.1	)
	Long-term position
	Counterparties with offsetting position			0.7				(1.2	)			-			(0.5	)
	Counterparties without offsetting position - assets			2.4				-				2.4			-
	Counterparties without offsetting position - liabilities			-				(0.2	)			-			(0.2	)
				3.1				(1.4	)			2.4			(0.7	)
	Total derivatives
	Counterparties with offsetting position			2.6				(5.6	)			-			(3.0	)
	Counterparties without offsetting position - assets			2.5				-				2.5			-
	Counterparties without offsetting position - liabilities			-				(3.8	)			-			(3.8	)
			$	5.1			$	(9.4	)		$	2.5		$	(6.8	)
Cash Flow Hedges Included In Accumulated Other Comprehensive Income (Loss)	'
	The following tables reflect amounts recorded in OCI and amounts reclassified from OCI to revenue and expense for the periods indicated:
		Gain (Loss) Recognized in OCI on Derivatives
		(Effective Portion)
		Three Months Ended March 31,
	Derivatives in Cash Flow Hedging Relationships		2014				2013
	Commodity contracts		$	(11.9	)		$	(7.6	)
Schedule of Gain (Loss) On Financial Instruments	'
		Gain (Loss) Reclassified from OCI into Income
		(Effective Portion)
	Location of Gain (Loss)	Three Months Ended March 31,
		2014				2013
	Interest expense, net		$	(1.3	)		$	(1.7	)
	Revenues			(6.3	)			6.6
			$	(7.6	)		$	4.9

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2014
Fair Value Measurements [Abstract]	'
Schedule of Fair Value of Assets and Liabilities Measured on a Recurring Basis	'
	The following table shows a breakdown by fair value hierarchy category for (1) financial instruments measurements included in our Consolidated Balance Sheets at fair value and (2) supplemental fair value disclosures for other financial instruments:
			31-Mar-14
			Carrying Value			Fair Value
						Total		Level 1		Level 2		Level 3
	Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value:
	Assets from commodity derivative contracts (1)		$	3.9		$	3.9	$	-	$	2.6	$	1.3
	Liabilities from commodity derivative contracts (1)			13.5			13.5		-		12		1.5
	Badlands contingent consideration liability			-			-		-		-		-
	Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
	Cash and cash equivalents			81.4			81.4		-		-		-
	Senior secured revolving credit facility			355			355		-		355		-
	Senior unsecured notes			2,231.20			2,284.00		-		2,284.00		-
	Accounts receivable securitization facility			233.5			233.5		-		233.5		-
	___________
	-1	The fair value of our derivative contracts in this table is presented on a different basis than the balance sheet presentation as disclosed in Note 12. The above fair values reflect the total value of each derivative contract taken as a whole, whereas the balance sheet presentation is based on the individual maturity dates of estimated future settlements.  As such, an individual contract could have both an asset and liability position when segregated into its current and long-term portions for balance sheet classification purposes.
Reconciliation of the Changes in Fair Value of Financial Instruments Classified As Level 3	'
	The following table summarizes the changes in fair value of our financial instruments classified as Level 3 in the fair value hierarchy:
			Commodity Derivative Contracts Asset /(Liability)
	Balance, December 31, 2013		$	0.7
	Settlements included in Revenue			(0.9	)
	Balance, March 31, 2014		$	(0.2	)

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2014
Related Party Transactions [Abstract]	'
Summary of Transactions with Affiliates	'
	The following table summarizes transactions with Targa. Management believes these transactions are executed on terms that are fair and reasonable.
		Three Months Ended March 31,
		2014		2013
	Parent billings of payroll and related costs included in operating expense	$	29.9	$	26.5
	Parent allocation of general & administrative expense		33.4		32.6
	Cash distributions to Targa based on unit ownership		41.5		30.7
	Contributions from Targa		2.4		2.3

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 2014
Supplemental Cash Flow Information [Abstract]	'
Supplemental Cash Flow Information	'
			Three Months Ended March 31,
			2014			2013
	Cash:
	Interest paid, net of capitalized interest (1)		$	23		$	31.4
	Income taxes paid, net of refunds			(0.2	)		-
	Non-cash:
	Deadstock inventory transferred to property, plant and equipment			1.1			4.5
	Accrued distribution equivalent rights			0.6			0.3
	Changes in receivables from unit offerings			7.1			-
	Change in capital accruals			22.7			15.5
	Transfers from materials and supplies inventory to property, plant and equipment			0.4			-
	Change in ARO cash flow estimate			2.1			0.2
	___________
	-1	Interest capitalized on major projects was $6.9 million and $6.1 million for the three months ended March 31, 2014 and 2013.

Segment_Information_Tables

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2014
Segment Information [Abstract]	'
Information by Segment	'
	Our reportable segment information is shown in the following tables:
		Three Months Ended March 31, 2014
		Field			Coastal
		Gathering			Gathering					Marketing					Corporate
		and			and			Logistics		and					and
		Processing			Processing			Assets		Distribution		Other			Eliminations			Total
	Revenues
	Sales of commodities	$	45.8		$	100.5		$	21	$	1,983.70	$	(6.1	)	$	(0.1	)	$	2,144.80
	Fees from midstream services		40.8			7.7			68.1		91.3		-			0.2			208.1
			86.6			108.2			89.1		2,075.00		(6.1	)		0.1			2,352.90
	Intersegment revenues
	Sales of commodities		400.4			177			0.6		130.4		-			(708.4	)		-
	Fees from midstream services		1.1			-			66.2		7.9		-			(75.2	)		-
			401.5			177			66.8		138.3		-			(783.6	)		-
	Revenues	$	488.1		$	285.2		$	155.9	$	2,213.30	$	(6.1	)	$	(783.5	)	$	2,352.90
	Operating margin	$	94.1		$	26.1		$	96.6	$	64.6	$	(6.1	)	$	-		$	275.3
	Other financial information:
	Total assets	$	3,275.10		$	385.1		$	1,568.70	$	614.1	$	4.5		$	128.8		$	5,976.30
	Capital expenditures	$	98.9		$	4.3		$	68.6	$	3.1	$	-		$	0.5		$	175.4
		Three Months Ended March 31, 2013
		Field			Coastal
		Gathering			Gathering					Marketing					Corporate
		and			and			Logistics		and					and
		Processing			Processing			Assets		Distribution		Other			Eliminations			Total
	Revenues
	Sales of commodities	$	38.1		$	69.6		$	32.9	$	1,136.50	$	6.6		$	-		$	1,283.70
	Fees from midstream services		20.2			8.8			47.1		38		-			-			114.1
			58.3			78.4			80		1,174.50		6.6			-			1,397.80
	Intersegment revenues
	Sales of commodities		273			151.9			0.9		110.5		-			(536.3	)		-
	Fees from midstream services		0.9			-			36.6		6.4		-			(43.9	)		-
			273.9			151.9			37.5		116.9		-			(580.2	)		-
	Revenues	$	332.2		$	230.3		$	117.5	$	1,291.40	$	6.6		$	(580.2	)	$	1,397.80
	Operating margin	$	53.8		$	23.5		$	56.3	$	34	$	6.6		$	-		$	174.2
	Other financial information:
	Total assets	$	2,854.70		$	416.3		$	1,210.70	$	436.9	$	21.4		$	134.2		$	5,074.20
	Capital expenditures	$	96.1		$	6.5		$	103.7	$	-	$	-		$	0.6		$	206.9
Revenues by Product and Service	'
	The following table shows our consolidated revenues by product and service for the periods presented:
		Three Months Ended March 31,
		2014			2013
	Sales of commodities
	Natural gas	$	392.6		$	255.3
	NGL		1,710.60			963.5
	Condensate		28.4			27.1
	Petroleum products		20.1			31.3
	Derivative activities		(6.9	)		6.5
			2,144.80			1,283.70
	Fees from midstream services
	Fractionating and treating		46.5			27.2
	Storage, terminaling, transportation and export		99.6			60.2
	Gathering and processing		42.6			18.5
	Other		19.4			8.2
			208.1			114.1
	Total revenues	$	2,352.90		$	1,397.80
Reconciliation of Operating Margin to Net Income	'
	The following table shows a reconciliation of operating margin to net income for the periods presented:
		Three Months Ended March 31,
		2014			2013
	Reconciliation of operating margin to net income:
	Operating margin	$	275.3		$	174.2
	Depreciation and amortization expense		(79.5	)		(63.9	)
	General and administrative expense		(35.9	)		(34.1	)
	Interest expense, net		(33.1	)		(31.4	)
	Other, net		5.6			1.4
	Income tax expense		(1.1	)		(0.9	)
	Net income	$	131.3		$	45.3

Organization_and_Operations_De

Organization and Operations (Details)	Mar. 31, 2014	Dec. 31, 2013
Organization and Operations [Abstract]	'	'
General partner interest (in hundredths)	2.00%	'
Ownership interest by related party and parents (in hundredths)	13.20%	'
General partner units outstanding (in units)	2,316,210	2,270,680
Common units held by related party (in units)	12,945,659	'
Increasing cash distributions as percentage of distributable cash for a quarter (in hundredths)	48.00%	'

Basis_of_Presentation_Details

Basis of Presentation (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Reclassification [Line Items]	'	'
Amount reclassified from operating activities to investing activities	'	$18.90
Changes in operating assets and liabilities:	'	'
Accounts payable and other liabilities	-12.1	-45.4
Net cash provided by operating activities	316.4	190.6
Changes in investing assets and liabilities:	'	'
Outlays for property, plant and equipment	-197.7	-222.4
Net cash used in investing activities	-193.7	-227
As Reported [Member]	'	'
Changes in operating assets and liabilities:	'	'
Accounts payable and other liabilities	'	-64.3
Net cash provided by operating activities	'	171.7
Changes in investing assets and liabilities:	'	'
Outlays for property, plant and equipment	'	-203.5
Net cash used in investing activities	'	-208.1
Reclassification [Member]	'	'
Changes in operating assets and liabilities:	'	'
Accounts payable and other liabilities	'	18.9
Net cash provided by operating activities	'	18.9
Changes in investing assets and liabilities:	'	'
Outlays for property, plant and equipment	'	-18.9
Net cash used in investing activities	'	($18.90)

Inventories_Details

Inventories (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Components of inventory [Abstract]	'	'
Commodities	$74.70	$136.40
Materials and supplies	13.8	14.3
Total inventory	$88.50	$150.70

Property_Plant_and_Equipment_a2

Property, Plant and Equipment and Intangible Assets (Details) (USD $)

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

In Millions, unless otherwise specified

Intangible Assets [Member]

Gathering systems [Member]

Gathering systems [Member]

Processing and fractionation facilities [Member]

Processing and fractionation facilities [Member]

Terminaling and storage facilities [Member]

Terminaling and storage facilities [Member]

Transportation assets [Member]

Transportation assets [Member]

Other property, plant and equipment [Member]

Other property, plant and equipment [Member]

Land [Member]

Land [Member]

Construction in progress [Member]

Construction in progress [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Gathering systems [Member]

Processing and fractionation facilities [Member]

Terminaling and storage facilities [Member]

Transportation assets [Member]

Other property, plant and equipment [Member]

Gathering systems [Member]

Processing and fractionation facilities [Member]

Terminaling and storage facilities [Member]

Transportation assets [Member]

Other property, plant and equipment [Member]

Property, Plant and Equipment [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Property, plant and equipment

$5,930.10

$5,751.60

'

$2,293.60

$2,230.10

$1,600.70

$1,598

$735.40

$715.20

$334.70

$294.70

$124.80

$121.30

$89.70

$89.50

$751.20

$702.80

'

'

'

'

'

'

'

'

'

'

Accumulated depreciation

-1,470.30

-1,406.20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Property, plant and equipment, net

4,459.80

4,345.40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated useful lives

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

'5 years

'5 years

'10 years

'3 years

'20 years

'25 years

'25 years

'25 years

'25 years

Intangible assets

681.8

681.8

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accumulated amortization

-43.7

-28.4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Intangible assets, net

$638.10

$653.40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Finite-Lived Intangible Assets [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Intangible assets, estimated useful lives (in years)

'

'

'20 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Changes in aggregate asset retirement obligations [Roll Forward]	'	'
Beginning of period	$50.50	'
Change in cash flow estimate	2.1	0.2
Accretion expense	1.2	1.1
End of period	$53.80	'

Investment_in_Unconsolidated_A2

Investment in Unconsolidated Affiliate (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Schedule of Equity Method Investments [Line Items]	'		'
Beginning	$55.90		'
Equity earnings	4.9		1.6
End of period	53.7		'
Cumulative earnings considered as return of capital	-2.2		0
GCF [Member]	'		'
Schedule of Equity Method Investments [Line Items]	'		'
Ownership interest (in hundredths)	38.80%		'
Beginning	55.9		'
Equity earnings	4.9		'
Cash distributions	-7.1	[1]	'
End of period	53.7		'
Cumulative earnings considered as return of capital	$2.20		'
[1]	Includes distributions in excess of cumulative earnings of $2.2 million that are considered a return of capital and disclosed in cash flows from investing activities in the Consolidated Statements of Cash Flows.

Accounts_Payable_and_Accrued_L2

Accounts Payable and Accrued Liabilities (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Accounts Payable and Accrued Liabilities [Abstract]	'	'
Commodities	$528.10	$520.80
Other goods and services	108.5	145.1
Interest	42.3	35.8
Compensation and benefits	1.7	1.3
Income and other taxes	12	11.1
Other	6.2	7.1
Accounts payable and accrued liabilities	$698.80	$721.20

Debt_Obligations_Details

Debt Obligations (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014		Dec. 31, 2013
Debt Instrument [Line Items]	'		'
Long-term debt	$2,819.70		$2,905.30
Letters of credit outstanding	97.2	[1]	86.8	[1]
Accounts Receivable Securitization Facility [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term debt	233.5	[2]	279.7	[2]
Maturity Date	31-Dec-14		'
Range of interest rates and weighted average interest rate [Abstract]	'		'
Range of Interest Rates Incurred, Maximum (in hundredths)	0.90%		'
Weighted Average Interest Rate Incurred (in hundredths)	0.90%		'
Secured Debt [Member] | Revolving Credit Facility Due 2017 [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term debt	355	[1]	395	[1]
Maturity Date	31-Oct-17		'
Maximum borrowing capacity under Revolving Credit Facility	1,200		'
Availability of credit under senior secured credit facility	747.8		'
Range of interest rates and weighted average interest rate [Abstract]	'		'
Weighted Average Interest Rate Incurred (in hundredths)	2.30%		'
Secured Debt [Member] | Minimum [Member] | Revolving Credit Facility Due 2017 [Member]	'		'
Range of interest rates and weighted average interest rate [Abstract]	'		'
Range of Interest Rates Incurred, Minimum (in hundredths)	2.20%		'
Secured Debt [Member] | Maximum [Member] | Revolving Credit Facility Due 2017 [Member]	'		'
Range of interest rates and weighted average interest rate [Abstract]	'		'
Range of Interest Rates Incurred, Maximum (in hundredths)	4.50%		'
Unsecured Debt [Member] | Senior Unsecured Notes due 2018 [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term debt	250		250
Maturity Date	31-Oct-18		'
Interest rate on fixed rate debt (in hundredths)	7.88%		'
Unsecured Debt [Member] | Senior Unsecured Notes due 2021 [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term debt	483.6		483.6
Maturity Date	28-Feb-21		'
Interest rate on fixed rate debt (in hundredths)	6.88%		'
Unsecured Debt [Member] | Senior Unsecured Notes due 2021 Unamortized Discount [Member]	'		'
Debt Instrument [Line Items]	'		'
Unamortized discount	-27.4		-28
Unsecured Debt [Member] | Senior Unsecured Notes due 2022 [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term debt	300		300
Maturity Date	31-Aug-22		'
Interest rate on fixed rate debt (in hundredths)	6.38%		'
Unsecured Debt [Member] | Senior Unsecured Notes due May 2023 [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term debt	600		600
Maturity Date	31-May-23		'
Interest rate on fixed rate debt (in hundredths)	5.25%		'
Unsecured Debt [Member] | Senior Unsecured Notes due November 2023 [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term debt	$625		$625
Maturity Date	30-Nov-23		'
Interest rate on fixed rate debt (in hundredths)	4.25%		'
[1]	As of March 31, 2014, availability under our $1.2 billion senior secured revolving credit facility was $747.8 million.
[2]	All amounts outstanding under the Securitization Facility are reflected as long-term debt in our balance sheet because we have the ability and intent to fund the Securitization Facilitybs borrowings on a long-term basis.

Partnership_Units_and_Related_2

Partnership Units and Related Matters (Details) (USD $)	3 Months Ended			1 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Apr. 18, 2014	Apr. 30, 2014
			August 2013 EDA [Member]	August 2013 EDA [Member]	August 2013 EDA [Member]
				Subsequent Event [Member]	Subsequent Event [Member]
Subsidiary, Sale of Stock [Line Items]	'	'	'	'	'
Number of common units included in public offerings (in shares)	'	'	2,222,271	802,630	'
Net proceeds from public offering	'	'	$115.30	$47.70	'
Receivables from issuance of common units	'	'	'	'	5.9
General partner contributed to maintain general partner ownership percentage	'	'	2.4	1	'
Receivables from contribution to maintain 2% general partner interest	'	'	'	'	1.2
General partner interest (in hundredths)	'	'	2.00%	2.00%	'
Aggregate offering amount remained available for sale pursuant to agreement	'	'	'	7.4	'
Number of days from end of each quarter by when cash is distributed to unitholders	'45 days	'	'	'	'
Date Paid or to be paid	15-May-14	14-Feb-14	'	'	'
Distributions to limited partners	87.2	84	'	'	'
Distributions to general partners (Incentive)	31.7	29.5	'	'	'
Distributions to general partners (2%)	2.4	2.3	'	'	'
Total distributions to general and limited partners	$121.30	$115.80	'	'	'
Distributions per limited partner per unit (in dollars per unit)	$0.76	$0.75	'	'	'

Earnings_per_Limited_Partner_U2

Earnings per Limited Partner Unit (Details) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Earnings per Limited Partner Unit [Abstract]	'	'
Net income	$131.30	$45.30
Less: Net income attributable to noncontrolling interests	8.9	6.4
Net income attributable to Targa Resources Partners LP	122.4	38.9
Net income attributable to general partner	33.8	22.8
Net income attributable to limited partners	88.6	16.1
Net income attributable to Targa Resources Partners LP	$122.40	$38.90
Weighted average units outstanding - basic (in shares)	112.4	101.8
Net income available per limited partner unit - basic (in dollars per share)	$0.79	$0.16
Weighted average units outstanding (in shares)	112.4	101.8
Dilutive effect of unvested stock awards (in shares)	0.6	0.2
Weighted average units outstanding - diluted (in shares)	113	102
Net income available per limited partner unit - diluted (in dollars per share)	$0.78	$0.16

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Derivative Assets [Abstract]	'	'	'
Current assets	$1.60	'	$2
Long-term assets	2.9	'	3.1
Total derivative assets	4.5	'	5.1
Derivative Liabilities [Abstract]	'	'	'
Current liabilities	-12.9	'	-8
Long-term liabilities	-1.2	'	-1.4
Total derivative liabilities	-14.1	'	-9.4
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Cash flow commodity hedge deferred net gain to be reclassified within twelve months	11	'	'
Cash flow interest rate swaps deferred net loss to be reclassified within twelve months	1.1	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Fair value	-9.6	'	'
Asset Position [Member] | Gross Presentation [Member]	'	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Counterparties with offsetting position	2.6	'	2.6
Counterparties without offsetting position - assets	1.9	'	2.5
Counterparties without offsetting position - liabilities	0	'	0
Fair value	4.5	'	5.1
Asset Position [Member] | Gross Presentation [Member] | Current Position [Member]	'	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Counterparties with offsetting position	1.6	'	1.9
Counterparties without offsetting position - assets	0	'	0.1
Counterparties without offsetting position - liabilities	0	'	0
Fair value	1.6	'	2
Asset Position [Member] | Gross Presentation [Member] | Long-term Position [Member]	'	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Counterparties with offsetting position	1	'	0.7
Counterparties without offsetting position - assets	1.9	'	2.4
Counterparties without offsetting position - liabilities	0	'	0
Fair value	2.9	'	3.1
Asset Position [Member] | Pro Forma Net Presentation [Member]	'	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Counterparties with offsetting position	0.7	'	0
Counterparties without offsetting position - assets	1.9	'	2.5
Counterparties without offsetting position - liabilities	0	'	0
Fair value	2.6	'	2.5
Asset Position [Member] | Pro Forma Net Presentation [Member] | Current Position [Member]	'	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Counterparties with offsetting position	0	'	0
Counterparties without offsetting position - assets	0	'	0.1
Counterparties without offsetting position - liabilities	0	'	0
Fair value	0	'	0.1
Asset Position [Member] | Pro Forma Net Presentation [Member] | Long-term Position [Member]	'	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Counterparties with offsetting position	0.7	'	0
Counterparties without offsetting position - assets	1.9	'	2.4
Counterparties without offsetting position - liabilities	0	'	0
Fair value	2.6	'	2.4
Liability Position [Member] | Gross Presentation [Member]	'	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Counterparties with offsetting position	-3.7	'	-5.6
Counterparties without offsetting position - assets	0	'	0
Counterparties without offsetting position - liabilities	-10.4	'	-3.8
Fair value	-14.1	'	-9.4
Liability Position [Member] | Gross Presentation [Member] | Current Position [Member]	'	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Counterparties with offsetting position	-3.4	'	-4.4
Counterparties without offsetting position - assets	0	'	0
Counterparties without offsetting position - liabilities	-9.5	'	-3.6
Fair value	-12.9	'	-8
Liability Position [Member] | Gross Presentation [Member] | Long-term Position [Member]	'	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Counterparties with offsetting position	-0.3	'	-1.2
Counterparties without offsetting position - assets	0	'	0
Counterparties without offsetting position - liabilities	-0.9	'	-0.2
Fair value	-1.2	'	-1.4
Liability Position [Member] | Pro Forma Net Presentation [Member]	'	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Counterparties with offsetting position	-1.8	'	-3
Counterparties without offsetting position - assets	0	'	0
Counterparties without offsetting position - liabilities	-10.4	'	-3.8
Fair value	-12.2	'	-6.8
Liability Position [Member] | Pro Forma Net Presentation [Member] | Current Position [Member]	'	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Counterparties with offsetting position	-1.8	'	-2.5
Counterparties without offsetting position - assets	0	'	0
Counterparties without offsetting position - liabilities	-9.5	'	-3.6
Fair value	-11.3	'	-6.1
Liability Position [Member] | Pro Forma Net Presentation [Member] | Long-term Position [Member]	'	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'	'
Counterparties with offsetting position	0	'	-0.5
Counterparties without offsetting position - assets	0	'	0
Counterparties without offsetting position - liabilities	-0.9	'	-0.2
Fair value	-0.9	'	-0.7
Cash Flow Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (Loss) Reclassified from OCI into Income (Effective Portion)	-7.6	4.9	'
Cash Flow Hedging [Member] | Interest Expense, Net [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (Loss) Reclassified from OCI into Income (Effective Portion)	-1.3	-1.7	'
Cash Flow Hedging [Member] | Revenue [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (Loss) Reclassified from OCI into Income (Effective Portion)	-6.3	6.6	'
Interest Rate Contracts [Member] | Cash Flow Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Deferred gain loss in OCI to be reclassified in future	-1.1	'	-2.4
Commodity Contracts [Member] | Cash Flow Hedging [Member]	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	-11.9	-7.6	'
Deferred gain loss in OCI to be reclassified in future	-9.4	'	-3.7
Designated as Hedging Instrument [Member]	'	'	'
Derivative Assets [Abstract]	'	'	'
Total derivative assets	4.5	'	5.1
Derivative Liabilities [Abstract]	'	'	'
Total derivative liabilities	-14	'	-9.1
Designated as Hedging Instrument [Member] | Commodity Contracts [Member]	'	'	'
Derivative Assets [Abstract]	'	'	'
Current assets	1.6	'	2
Long-term assets	2.9	'	3.1
Derivative Liabilities [Abstract]	'	'	'
Current liabilities	-12.8	'	-7.7
Long-term liabilities	-1.2	'	-1.4
Not Designated as Hedging Instrument [Member]	'	'	'
Derivative Assets [Abstract]	'	'	'
Total derivative assets	0	'	0
Derivative Liabilities [Abstract]	'	'	'
Total derivative liabilities	-0.1	'	-0.3
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member]	'	'	'
Derivative Assets [Abstract]	'	'	'
Current assets	0	'	0
Derivative Liabilities [Abstract]	'	'	'
Current liabilities	($0.10)	'	($0.30)
Natural Gas [Member] | Swaps [Member] | Year 2014 [Member]	'	'	'
Derivative [Line Items]	'	'	'
Notional volumes of commodity hedges (per day)	54,050	'	'
Natural Gas [Member] | Swaps [Member] | Year 2015 [Member]	'	'	'
Derivative [Line Items]	'	'	'
Notional volumes of commodity hedges (per day)	40,551	'	'
Natural Gas [Member] | Swaps [Member] | Year 2016 [Member]	'	'	'
Derivative [Line Items]	'	'	'
Notional volumes of commodity hedges (per day)	25,500	'	'
Natural Gas Liquids [Member] | Options [Member] | Year 2014 [Member]	'	'	'
Derivative [Line Items]	'	'	'
Notional volumes of commodity hedges (per day)	1,125	'	'
Natural Gas Liquids [Member] | Options [Member] | Year 2015 [Member]	'	'	'
Derivative [Line Items]	'	'	'
Notional volumes of commodity hedges (per day)	0	'	'
Natural Gas Liquids [Member] | Options [Member] | Year 2016 [Member]	'	'	'
Derivative [Line Items]	'	'	'
Notional volumes of commodity hedges (per day)	0	'	'
Condensate [Member] | Swaps [Member] | Year 2014 [Member]	'	'	'
Derivative [Line Items]	'	'	'
Notional volumes of commodity hedges (per day)	2,450	'	'
Condensate [Member] | Swaps [Member] | Year 2015 [Member]	'	'	'
Derivative [Line Items]	'	'	'
Notional volumes of commodity hedges (per day)	0	'	'
Condensate [Member] | Swaps [Member] | Year 2016 [Member]	'	'	'
Derivative [Line Items]	'	'	'
Notional volumes of commodity hedges (per day)	0	'	'

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014
Fair Value Measurements [Abstract]	'
Derivative fair value commodity price increases 10 percent, net liability	$33.10
Derivative fair value commodity price decreases 10 percent, net asset	13.8
Number of natural gas basis swaps categorized as Level 3	14
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'
Assets from commodity derivative contracts	3.9	[1]
Liability from commodity derivative contracts	13.5	[1]
Badlands contingent consideration liability	0
Cash and cash equivalents	81.4
Senior secured revolving credit facility	355
Senior unsecured notes	2,284
Accounts receivable securitization facility	233.5
Commodity Derivative Contracts Asset/ (Liability)	'
Fair Value Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]	'
Balance, December 31, 2013	0.7
Settlements included in Revenue	-0.9
Balance, March 31, 2014	-0.2
Level 1 [Member]	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'
Assets from commodity derivative contracts	0	[1]
Liability from commodity derivative contracts	0	[1]
Badlands contingent consideration liability	0
Cash and cash equivalents	0
Senior secured revolving credit facility	0
Senior unsecured notes	0
Accounts receivable securitization facility	0
Level 2 [Member]	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'
Assets from commodity derivative contracts	2.6	[1]
Liability from commodity derivative contracts	12	[1]
Badlands contingent consideration liability	0
Cash and cash equivalents	0
Senior secured revolving credit facility	355
Senior unsecured notes	2,284
Accounts receivable securitization facility	233.5
Level 3 [Member]	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'
Assets from commodity derivative contracts	1.3	[1]
Liability from commodity derivative contracts	1.5	[1]
Badlands contingent consideration liability	0
Cash and cash equivalents	0
Senior secured revolving credit facility	0
Senior unsecured notes	0
Accounts receivable securitization facility	0
Carrying Value [Member]	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'
Assets from commodity derivative contracts	3.9	[1]
Liability from commodity derivative contracts	13.5	[1]
Badlands contingent consideration liability	0
Cash and cash equivalents	81.4
Senior secured revolving credit facility	355
Senior unsecured notes	2,231.20
Accounts receivable securitization facility	$233.50
[1]	The fair value of our derivative contracts in this table is presented on a different basis than the balance sheet presentation as disclosed in Note 12. The above fair values reflect the total value of each derivative contract taken as a whole, whereas the balance sheet presentation is based on the individual maturity dates of estimated future settlements. As such, an individual contract could have both an asset and liability position when segregated into its current and long-term portions for balance sheet classification purposes.

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Related Party Transactions [Abstract]	'	'
Parent billings of payroll and related costs included in operating expense	$29.90	$26.50
Parent allocation of general & administrative expense	33.4	32.6
Cash distributions to Targa based on unit ownership	41.5	30.7
Contributions from Targa	$2.40	$2.30

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Cash [Abstract]	'		'
Interest paid, net of capitalized interest	$23	[1]	$31.40	[1]
Income taxes paid, net of refunds	-0.2		0
Non-cash [Abstract]	'		'
Deadstock inventory transferred to property, plant and equipment	1.1		4.5
Accrued distribution equivalent rights	0.6		0.3
Changes in receivables from unit offerings	7.1		0
Change in capital accruals	22.7		15.5
Transfers from materials and supplies inventory to property, plant and equipment	0.4		0
Change in ARO cash flow estimate	2.1		0.2
Interest capitalized on major projects	$6.90		$6.10
[1]	Interest capitalized on major projects was $6.9 million and $6.1 million for the three months ended March 31, 2014 and 2013.

Segment_Information_Details

Segment Information (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
	Segment
	Division
Segment Information [Abstract]	'	'	'
Number of divisions	2	'	'
Number of segments	4	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	$2,144.80	$1,283.70	'
Fees from midstream services	208.1	114.1	'
Revenues	2,352.90	1,397.80	'
Operating margin	275.3	174.2	'
Other financial information:	'	'	'
Total assets	5,976.30	5,074.20	5,971.40
Capital expenditures	175.4	206.9	'
Total Outside Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	2,144.80	1,283.70	'
Fees from midstream services	208.1	114.1	'
Revenues	2,352.90	1,397.80	'
Total Intersegment Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	0	0	'
Fees from midstream services	0	0	'
Intersegment revenues	0	0	'
Field Gathering and Processing [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues	488.1	332.2	'
Operating margin	94.1	53.8	'
Other financial information:	'	'	'
Total assets	3,275.10	2,854.70	'
Capital expenditures	98.9	96.1	'
Field Gathering and Processing [Member] | Total Outside Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	45.8	38.1	'
Fees from midstream services	40.8	20.2	'
Revenues	86.6	58.3	'
Field Gathering and Processing [Member] | Total Intersegment Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	400.4	273	'
Fees from midstream services	1.1	0.9	'
Intersegment revenues	401.5	273.9	'
Coastal Gathering and Processing [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues	285.2	230.3	'
Operating margin	26.1	23.5	'
Other financial information:	'	'	'
Total assets	385.1	416.3	'
Capital expenditures	4.3	6.5	'
Coastal Gathering and Processing [Member] | Total Outside Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	100.5	69.6	'
Fees from midstream services	7.7	8.8	'
Revenues	108.2	78.4	'
Coastal Gathering and Processing [Member] | Total Intersegment Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	177	151.9	'
Fees from midstream services	0	0	'
Intersegment revenues	177	151.9	'
Logistics Assets [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues	155.9	117.5	'
Operating margin	96.6	56.3	'
Other financial information:	'	'	'
Total assets	1,568.70	1,210.70	'
Capital expenditures	68.6	103.7	'
Logistics Assets [Member] | Total Outside Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	21	32.9	'
Fees from midstream services	68.1	47.1	'
Revenues	89.1	80	'
Logistics Assets [Member] | Total Intersegment Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	0.6	0.9	'
Fees from midstream services	66.2	36.6	'
Intersegment revenues	66.8	37.5	'
Marketing and Distribution [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues	2,213.30	1,291.40	'
Operating margin	64.6	34	'
Other financial information:	'	'	'
Total assets	614.1	436.9	'
Capital expenditures	3.1	0	'
Marketing and Distribution [Member] | Total Outside Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	1,983.70	1,136.50	'
Fees from midstream services	91.3	38	'
Revenues	2,075	1,174.50	'
Marketing and Distribution [Member] | Total Intersegment Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	130.4	110.5	'
Fees from midstream services	7.9	6.4	'
Intersegment revenues	138.3	116.9	'
Other Segment [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues	-6.1	6.6	'
Operating margin	-6.1	6.6	'
Other financial information:	'	'	'
Total assets	4.5	21.4	'
Capital expenditures	0	0	'
Other Segment [Member] | Total Outside Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	-6.1	6.6	'
Fees from midstream services	0	0	'
Revenues	-6.1	6.6	'
Other Segment [Member] | Total Intersegment Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	0	0	'
Fees from midstream services	0	0	'
Intersegment revenues	0	0	'
Corporate And Elimination [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Revenues	-783.5	-580.2	'
Operating margin	0	0	'
Other financial information:	'	'	'
Total assets	128.8	134.2	'
Capital expenditures	0.5	0.6	'
Corporate And Elimination [Member] | Total Outside Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	-0.1	0	'
Fees from midstream services	0.2	0	'
Revenues	0.1	0	'
Corporate And Elimination [Member] | Total Intersegment Revenues [Member]	'	'	'
Segment Reporting Information [Line Items]	'	'	'
Sales of commodities	-708.4	-536.3	'
Fees from midstream services	-75.2	-43.9	'
Intersegment revenues	($783.60)	($580.20)	'

Segment_Information_Revenues_b

Segment Information, Revenues by Product and Service and Reconciliation of Operating Margin to Net Income (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Revenue from External Customer [Line Items]	'	'
Sales of commodities	$2,144.80	$1,283.70
Fees from midstream services	208.1	114.1
Revenues	2,352.90	1,397.80
Reconciliation of operating margin to net income: [Abstract]	'	'
Operating margin	275.3	174.2
Depreciation and amortization expense	-79.5	-63.9
General and administrative expense	-35.9	-34.1
Interest expense, net	-33.1	-31.4
Other, net	5.6	1.4
Income tax expense	-1.1	-0.9
Net income	131.3	45.3
Natural Gas [Member]	'	'
Revenue from External Customer [Line Items]	'	'
Sales of commodities	392.6	255.3
NGL [Member]	'	'
Revenue from External Customer [Line Items]	'	'
Sales of commodities	1,710.60	963.5
Condensate [Member]	'	'
Revenue from External Customer [Line Items]	'	'
Sales of commodities	28.4	27.1
Petroleum Products [Member]	'	'
Revenue from External Customer [Line Items]	'	'
Sales of commodities	20.1	31.3
Derivative Activities [Member]	'	'
Revenue from External Customer [Line Items]	'	'
Sales of commodities	-6.9	6.5
Fractionating and Treating [Member]	'	'
Revenue from External Customer [Line Items]	'	'
Fees from midstream services	46.5	27.2
Storage, Terminaling, Transportation and Export [Member]	'	'
Revenue from External Customer [Line Items]	'	'
Fees from midstream services	99.6	60.2
Gathering and Processing [Member]	'	'
Revenue from External Customer [Line Items]	'	'
Fees from midstream services	42.6	18.5
Other [Member]	'	'
Revenue from External Customer [Line Items]	'	'
Fees from midstream services	$19.40	$8.20