Targa Resources Partners (NGLS-PA) 10-Q 7 May 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015	1-May-15
Document and Entity Information [Line Items]
Entity Registrant Name	Targa Resources Partners LP
Entity Central Index Key	1379661
Current Fiscal Year End Date	-19
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15
Limited Partner Interest [Member]
Document and Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		180,830,462
General Partner Units [Member]
Document and Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		3,690,419

CONSOLIDATED_BALANCE_SHEETS_Un

CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Millions, unless otherwise specified
Current assets:
Cash and cash equivalents	$63.50		$72.30
Trade receivables, net of allowances of $0.0 million	667.9		566.8
Inventories	78.2		168.9
Assets from risk management activities	126		44.4
Other current assets	11.8		3.8
Total current assets	947.4		856.2
Property, plant and equipment	11,617.80		6,514.30
Accumulated depreciation	-1,784.90		-1,689.70
Property, plant and equipment, net	9,832.90		4,824.60
Goodwill	628.5	[1]	0
Intangible assets, net	1,602.40	[1]	591.9
Long-term assets from risk management activities	51.2		15.8
Investments in unconsolidated affiliates	322.9		50.2
Other long-term assets	54.3		38.5
Total assets	13,439.60	[2]	6,377.20
Current liabilities:
Accounts payable and accrued liabilities	710.8		592.7
Accounts payable to Targa Resources Corp.	41.3		53.2
Accounts receivable securitization facility	197.9		182.8
Liabilities from risk management activities	0.6		5.2
Total current liabilities	950.6		833.9
Long-term debt	5,140.40		2,783.40
Long-term liabilities from risk management activities	1.8		0
Deferred income taxes	44.5		13.7
Other long-term liabilities	73.3		57.8
Contingencies (see Note 16)
Owners' equity:
Limited partners (178,564,012 and 118,652,798 common units issued and 178,484,485 and 118,586,056 common units outstanding as of March 31, 2015 and December 31, 2014 respectively)	4,960.10		2,384.10
General partner (3,642,543 and 2,420,124 units issued and outstanding as of March 31, 2015 and December 31, 2014 respectively)	133.5		78.6
Special general partner interest (see Note 2)	1,608.30		0
Receivables from unit issuances	-25.6		-1
Accumulated other comprehensive income	77.4		60.3
Treasury units at cost (79,527 units as of March 31, 2015, and 66,742 as of December 31, 2014)	-5.4		-4.8
Partners' Capital	6,748.30		2,517.20
Noncontrolling interests in subsidiaries	480.7		171.2
Total owners' equity	7,229		2,688.40
Total liabilities and owners' equity	$13,439.60		$6,377.20
[1]	Represents preliminary acquisition fair value attributable to the Special GP Interest attributable to goodwill and intangible assets.
[2]	Corporate assets at the Segment level primarily include investment in unconsolidated subsidiaries and debt issuance costs associated with our long-term debt.

CONSOLIDATED_BALANCE_SHEETS_Un1

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, except Share data, unless otherwise specified
Current assets:
Allowance for receivables	$0	$0
Owners' equity:
Limited partners common units issued (in units)	178,564,012	118,652,798
Limited partners common units outstanding (in units)	178,484,485	118,586,056
General partner units issued (in units)	3,642,543	2,420,124
General partner units outstanding (in units)	3,642,543	2,420,124
Treasury units at cost (in units)	79,527	66,742

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) [Abstract]
Revenues	$1,679.70	$2,294.70
Costs and expenses:
Product purchases	1,268.30	1,915.10
Operating expenses	111.3	104.3
Depreciation and amortization expenses	119.6	79.5
General and administrative expenses	40.3	35.9
Other operating income (expense)	0.6	-0.7
Income from operations	139.6	160.6
Other income (expense):
Interest expense, net	-50.9	-33.1
Equity earnings	1.7	4.9
Other	-12.8	0
Income before income taxes	77.6	132.4
Income tax benefit (expense):
Current	-0.5	-0.7
Deferred	-0.6	-0.4
Total Income tax (expense) benefit	-1.1	-1.1
Net income	76.5	131.3
Less: Net income attributable to noncontrolling interests	4.9	8.9
Net income attributable to Targa Resources Partners LP	71.6	122.4
Net income attributable to general partner	42.5	33.8
Net income attributable to limited partners	29.1	88.6
Net income attributable to Targa Resources Partners LP	$71.60	$122.40
Net income per limited partner unit - basic (in dollars per share)	$0.21	$0.79
Net income per limited partner unit - diluted (in dollars per share)	$0.21	$0.78
Weighted average limited partner units outstanding - basic (in shares)	137.1	112.4
Weighted average limited partner units outstanding - diluted (in shares)	137.5	113

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited) [Abstract]
Net income	$76.50	$131.30
Commodity hedging derivative contracts:
Change in fair value	25.2	-11.9
Settlements reclassified to revenues	-8.1	6.3
Interest rate swaps:
Settlements reclassified to interest expense, net	0	1.3
Other comprehensive income (loss)	17.1	-4.3
Comprehensive income	93.6	127
Less: Comprehensive income attributable to noncontrolling interests	4.9	8.9
Comprehensive income attributable to Targa Resources Partners LP	$88.70	$118.10

CONSOLIDATED_STATEMENTS_OF_CHA

CONSOLIDATED STATEMENTS OF CHANGES IN OWNERS' EQUITY (Unaudited) (USD $)	Limited Partners Common [Member]	General Partner [Member]	Special General Partner Interest [Member]	Receivables From Unit Issuances [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Treasury Units [Member]	Non-controlling Interests [Member]	Total
In Millions, except Share data in Thousands, unless otherwise specified
Balance at Dec. 31, 2013	$2,001.90	$62	$0	$0	($6.10)	$0	$160.60	$2,218.40
Balance (in units) at Dec. 31, 2013	111,263	2,271				0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Compensation on equity grants	2.6	0	0	0	0	0	0	2.6
Compensation on equity grants (in units)	9	0				0
Accrual of distribution equivalent rights	-0.6	0	0	0	0	0	0	-0.6
Equity offerings	115.3	2.4	0	-7.1	0	0	0	110.6
Equity offerings (in units)	2,222	45				0
Distributions to noncontrolling interests	0	0	0	0	0	0	-7.4	-7.4
Other comprehensive income (loss)	0	0	0	0	-4.3	0	0	-4.3
Net income	88.6	33.8	0	0	0	0	8.9	131.3
Distributions	-84	-31.8	0	0	0	0	0	-115.8
Balance at Mar. 31, 2014	2,123.80	66.4	0	-7.1	-10.4	0	162.1	2,334.80
Balance (in units) at Mar. 31, 2014	113,494	2,316				0
Balance at Dec. 31, 2014	2,384.10	78.6	0	-1	60.3	-4.8	171.2	2,688.40
Balance (in units) at Dec. 31, 2014	118,586	2,420				67
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Compensation on equity grants	3.8	0	0	0	0	0	0	3.8
Compensation on equity grants (in units)	0	0				0
Issuance of common units under compensation program	0	0	0	0	0	0	0	0
Issuance of common units under compensation program (in units)	26	0				0
Units tendered for tax withholding obligations	0	0	0	0	0	-0.6	0	-0.6
Units tendered for tax withholding obligations (in units)	-13	0				13
Equity offerings	53	0	0	-24.8	0	0	0	28.2
Equity offerings (in units)	1,271	0				0
Issuance of units for acquisition	2,582.40			0	0	0	303.9	2,886.30
Issuance of units for acquisition (in units)	58,614					0
Contributions from Targa Resources Corp.	0	53.4	0	0.2	0	0	0	53.6
Contributions from Targa Resources Corp. (in units)	0	1,222				0
Distributions to noncontrolling interests	0	0	0	0	0	0	-2.7	-2.7
Contribution from noncontrolling interests	0	0	0	0	0	0	3.4	3.4
Other comprehensive income (loss)	0	0	0	0	17.1	0	0	17.1
Net income	29.1	42.5	0	0	0	0	4.9	76.5
Distributions	-96.3	-41.1	0	0	0	0	0	-137.4
Targa contribution - Special General Partner Interest	0	0	1,612.40	0	0	0	0	1,612.40
Allocation of special general partner interest	4	0.1	-4.1	0	0	0	0	0
Balance at Mar. 31, 2015	$4,960.10	$133.50	$1,608.30	($25.60)	$77.40	($5.40)	$480.70	$7,229
Balance (in units) at Mar. 31, 2015	178,484	3,642				80

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash flows from operating activities
Net income	$76.50	$131.30
Adjustments to reconcile net income to net cash provided by operating activities:
Amortization in interest expense	3	3.4
Compensation on equity grants	3.8	2.6
Depreciation and amortization expense	119.6	79.5
Accretion of asset retirement obligations	1.3	1.2
Deferred income tax expense (benefit)	0.6	0.4
Equity earnings of unconsolidated affiliates	-1.7	-4.9
Distributions received from unconsolidated affiliates	2.1	4.9
Risk management activities	6.6	-0.3
(Gain) loss on sale or disposition of assets	0.6	-0.8
(Gain) loss on debt redemptions and amendments	-0.1	0
Changes in operating assets and liabilities:
Receivables and other assets	82.2	50.6
Inventory	102.5	60.6
Accounts payable and other liabilities	-84.5	-12.1
Net cash provided by operating activities	312.5	316.4
Cash flows from investing activities
Outlays for property, plant and equipment	-187.6	-197.7
Business acquisition, net of cash acquired	-852.3	0
Return of capital from unconsolidated affiliate	0.6	2.2
Other, net	-0.6	1.8
Net cash used in investing activities	-1,039.90	-193.7
Cash flows from financing activities
Proceeds from borrowings under credit facility	975	460
Repayments of credit facility	-135	-500
Proceeds from issuance of senior notes	1,100	0
Proceeds from accounts receivable securitization facility	253.4	29.5
Repayments of accounts receivable securitization facility	-238.3	-75.7
Redemption of APL senior notes	-1,168.80	0
Costs paid in connection with debt and equity financing arrangements	-12.2	-1.2
Proceeds from equity offerings	28.2	109.4
Repurchase of common units under compensation plans	-0.6	0
Distributions paid to unit holders	-137.4	-115.8
Contributions received from General Partner	53.6	2.4
Contributions received from noncontrolling interests	3.4	0
Distributions paid to noncontrolling interests	-2.7	-7.4
Net cash provided by (used in) financing activities	718.6	-98.8
Net change in cash and cash equivalents	-8.8	23.9
Cash and cash equivalents, beginning of period	72.3	57.5
Cash and cash equivalents, end of period	$63.50	$81.40

Organization_and_Operations

Organization and Operations	3 Months Ended
	Mar. 31, 2015
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. 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, 2015, Targa owned an 11.0% interest in us in the form of 3,642,543 general partner units and 16,309,594 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, exclusive of amounts reallocated to common unit-holders under the IDR Giveback Amendment (see Note 11).
	In connection with the Atlas mergers, our partnership agreement was amended to provide for the issuance of a special general partner interest (“the Special GP Interest”) representing a capital account credit equal to the tax basis of the APL GP Interests acquired in the ATLS merger. The Special GP Interest is not entitled to current distributions or allocations of net income or loss, and has no voting rights or other rights except for the limited right to receive deductions attributable to the contribution of APL GP.
	Allocation of costs
	The employees supporting our operations are employed by 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 18 for certain financial information for our business segments.

Basis_of_Presentation

Basis of Presentation	3 Months Ended
	Mar. 31, 2015
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 February 27, 2015 Atlas mergers involved two separate legal transactions involving different groups of unitholders. For GAAP reporting purposes these two mergers are viewed as a single integrated transaction.  As such, the financial effects of the Targa consideration related to the ATLS merger have been reflected in these financial statements. As described in Note 1, our Partnership Agreement was amended to provide for the issuance of a special general partner interest in us representing a capital account credit equal to the tax basis of the APL GP Interests acquired in the ATLS merger totaling $1.6 billion. The Special GP Interest is not entitled to current distributions or allocations of net income or loss, and has no voting rights or other rights except for the limited right to receive deductions attributable to the contribution of APL GP. Pending finalization of our fair value acquisition accounting, we have attributed goodwill and intangible assets to this special capital account and have reflected the related financial effects in our Owners’ Equity.
	The unaudited consolidated financial statements for the three months ended March 31, 2015 and 2014 include all adjustments that 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, 2015 are not necessarily indicative of the results that may be expected for the full year.

Significant_Accounting_Policie

Significant Accounting Policies	3 Months Ended
	Mar. 31, 2015
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. We have updated our policies during the three months ended March 31, 2015 to include our accounting policy for goodwill related to the Atlas mergers.
	Goodwill results when the cost of an acquisition exceeds the fair value of the net identifiable assets of the acquired business. Goodwill is not amortized, but is assessed annually to determine whether its carrying value has been impaired.
	Impairment testing for goodwill is performed at the reporting unit level. A reporting unit is an operating segment or one level below an operating segment (also known as a component). A component of an operating segment is a reporting unit if the component constitutes a business for which discrete financial information is available, and segment management regularly reviews the operating results of that component.
	We evaluate goodwill for impairment at least annually, as of November 30th for all affected reporting units. We also evaluate goodwill for impairment whenever events or changes in circumstances indicate it is more likely than not the fair value of a reporting unit is less than its carrying amount. We may first assess qualitative factors to evaluate whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount (including assigned goodwill) as the basis for determining whether it is necessary to perform the two-step goodwill impairment test. If a two-step process goodwill impairment test is required, the first step involves comparing the fair value of the reporting unit to which goodwill has been allocated with its carrying amount. If the carrying amount of a reporting unit exceeds its fair value, the second step of the process involves comparing the implied fair value to the carrying value of the goodwill for that reporting unit. If the carrying value of the goodwill of a reporting unit exceeds the implied fair value of that goodwill, the excess of the carrying value over the implied fair value is recognized as a reduction of goodwill on our Consolidated Balance Sheets and a goodwill impairment loss on our Consolidated Statements of Operations.
	Recent Accounting Pronouncements
	In February 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standard Update (“ASU”) No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis. The amendments are intended to simplify the consolidation evaluation for reporting organizations that are required to evaluate whether they should consolidate certain legal entities and modify the evaluation of whether limited partnerships and similar legal entities are variable interest entities or voting interest entities. The amendments are effective for us in 2016, with early adoption permitted. We are currently evaluating the effect of the amendments on our consolidated financial statements and related disclosures.
	In April 2015, the FASB issued ASU 2015-03, Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. The amendments in this update require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this update. The amendments are effective for us in 2016, with early adoption permitted. We anticipate adopting the amendments on January 1, 2016. Unamortized debt issuance costs of $46.4 million were included in Other long-term assets on the Consolidated Balance Sheets as of March 31, 2015.

Business_Acquisitions

Business Acquisitions	3 Months Ended
	Mar. 31, 2015
Business Acquisitions [Abstract]
Business Acquisitions	Note 4 –Business Acquisitions
	2015 Acquisition
	Atlas Mergers
	On February 27, 2015, (i) Targa completed the previously announced transactions contemplated by the Agreement and Plan of Merger, dated as of October 13, 2014 (the “ATLS Merger Agreement”), by and among Targa, Targa GP Merger Sub LLC, a Delaware limited liability company and a wholly owned subsidiary of Targa (“GP Merger Sub”), ATLS and Atlas Energy GP, LLC, a Delaware limited liability company and the general partner of ATLS (“ATLS GP”), and (ii) Targa and the Partnership completed the previously announced transactions contemplated by the Agreement and Plan of Merger (the “APL Merger Agreement” and, together with the ATLS Merger Agreement, the “Atlas Merger Agreements”) by and among Targa, the Partnership, our general partner, Trident MLP Merger Sub LLC, a Delaware limited liability company and a wholly owned subsidiary of the Partnership (“MLP Merger Sub”), ATLS, APL and Atlas Pipeline Partners GP, LLC, a Delaware limited liability company and the general partner of APL (“APL GP”). Pursuant to the terms and conditions set forth in the ATLS Merger Agreement, GP Merger Sub merged (the “ATLS merger”) with and into ATLS, with ATLS continuing as the surviving entity and as a subsidiary of Targa. Pursuant to the terms and conditions set forth in the APL Merger Agreement, MLP Merger Sub merged (the “APL merger” and, together with the ATLS merger, the “Atlas mergers”) with and into APL, with APL continuing as the surviving entity and as a subsidiary of the Partnership.
	In connection with the Atlas mergers, APL changed its name to “Targa Pipeline Partners LP,” which we refer to as TPL, and ATLS changed its name to “Targa Energy LP.”
	In addition, prior to the completion of the Atlas mergers, ATLS, pursuant to a Separation and Distribution Agreement entered into by and among ATLS, ATLS GP and Atlas Energy Group, LLC, a Delaware limited liability company (“AEG”), on February 27, 2015, (i) transferred its assets and liabilities other than those related to its “Atlas Pipeline Partners” segment, to AEG and (ii) effected a pro rata distribution to the ATLS unitholders of AEG common units representing a 100% interest in AEG (collectively, the “Spin-Off” and, together with the Atlas mergers, the “Atlas Transactions”).
	We acquired all of the outstanding units of APL for a total purchase price of approximately $5.3 billion (including $1.8 billion of acquired debt and all other assumed liabilities). Of the $1.8 billion of debt acquired and other liabilities assumed, approximately $1.2 billion of the acquired debt was tendered and settled upon the closing of the Atlas mergers via our January 2015 cash tender offers. These tender offers were in connection with, and conditioned upon, the consummation of the merger with APL. The merger with APL, however, was not conditioned on the consummation of the tender offers. On that same date, Targa acquired ATLS for a total purchase price of approximately $1.6 billion (including all assumed liabilities).
	On February 27, 2015, our Partnership Agreement was amended to provide for the issuance of a special general partner interest in us representing a capital account credit equal to the tax basis of the APL GP Interests acquired in the ATLS merger totaling $1.6 billion, which, through a series of transactions, was contributed by Targa to us immediately following the effective time of the ATLS merger and prior to the effective time of the APL merger. The Special GP Interest is not entitled to current distributions or allocations of net income or loss, and has no voting rights or other rights except for the limited right to receive deductions attributable to the contribution of APL GP. Pending finalization of our fair value acquisition accounting, we have attributed goodwill and intangible assets to this special capital account and have reflected the related financial effects in Owners’ Equity.
	Pursuant to the APL Merger Agreement, our general partner entered into an amendment to our partnership agreement in order to reduce aggregate distributions to TRC, as the holder of the Partnership’s IDRs by (a) $9,375,000 per quarter during the first four quarters following the APL merger, (b) $6,250,000 per quarter for the next four quarters, (c) $2,500,000 per quarter for the next four quarters and (d) $1,250,000 per quarter for the next four quarters, with the amount of such reductions to be distributed pro rata to the holders of our outstanding common units.
	TPL is a provider of natural gas gathering, processing and treating services primarily in the Anadarko, Arkoma and Permian Basins located in the southwestern and mid-continent regions of the United States and in the Eagle Ford Shale play in south Texas. The Atlas mergers add TPL’s Woodford/SCOOP, Mississippi Lime, Eagle Ford and additional Permian assets to the Partnership’s existing operations and creates a combined position across the Permian Basin that enhances service capabilities in one of the most active producing basins in North America, with a combined 1,439 MMcf/d of processing capacity and 10,500 miles of pipelines. The results of TPL will be reported in our Field Gathering and Processing segment.
	The APL merger was a unit-for-unit transaction with an exchange ratio of 0.5846 of our common units (the “APL Unit Consideration”) and $1.26 in cash for each APL common unit (the “APL Cash Consideration” and with the APL Unit Considerations, the “APL Merger Consideration”), a $128.0 million total cash payment, of which $0.6 million was expensed at the acquisition date as the cash payment representing accelerated vesting of a portion of retained employees' APL phantom awards. We issued 58,614,157 of our common units and awarded 629,231 replacement phantom unit awards with a combined value of approximately $2.6 billion as consideration for the APL merger (based on the $43.82 closing market price of a common unit on the NYSE on February 27, 2015). The cash component of the APL Merger also included $701.4 million for the mandatory repayment and extinguishment at closing of the APL Senior Secured Revolving Credit Facility that was to mature in May 2017 (the “APL Revolver”), $28.8 million related to change of control payments and $6.4 million of cash paid in lieu of unit issuances in connection with settlement of APL equity awards for AEG employees. In March 2015, Targa contributed $52.4 million to us to maintain its 2% general partner interest.
	In addition, pursuant to the APL Merger Agreement, APL exercised its right under the certificate of designations of the APL 8.25% Class E cumulative redeemable perpetual preferred units (“Class E Preferred Units”) to redeem the APL Class E Preferred Units immediately prior to the APL Effective Time.
	The ATLS merger was a stock-for-unit transaction with an exchange ratio of 0.1809 of Targa common stock, par value $0.001 per share (the “ATLS Stock Consideration”), and $9.12 in cash for each ATLS common unit (the “ATLS Cash Consideration” and with the ATLS Stock Consideration, the “ATLS Merger Consideration”), (a $514.7 million total cash payment). Targa issued 10,126,532 of its common shares and awarded 81,740 replacement restricted stock units with a combined value of approximately $1.0 billion for the ATLS merger (based on the $99.58 closing market price of a TRC common share on the NYSE on February 27, 2015). The cash component of the ATLS merger also included approximately $149.2 million for change of control payments and cash settlements of equity awards, $88.0 million for repayment of a portion of ATLS outstanding indebtedness and $11.0 million for reimbursement of certain transaction expenses. Approximately $4.5 million of the one-time cash payments and cash settlements of equity awards, which represent accelerated vesting of a portion of retained employees’ ATLS phantom units, were expensed at the acquisition date.
	ATLS owned, directly and indirectly, 5,754,253 APL common units immediately prior to closing. Targa’s acquisition of ATLS resulted in Targa acquiring these common units (converted to 3,363,935 of our common units) valued at approximately $147.4 million (based on the $43.82 closing market price of our common units on the NYSE on February 27, 2015) and the right to receive the units’ one-time cash payment of approximately $7.3 million, which reduced the consolidated purchase price by approximately $154.7 million.
	While these were two separate legal transactions involving different groups of unitholders, for GAAP reporting purposes these two mergers are viewed as a single integrated transaction.  As such, the financial effects of the Targa consideration related to the ATLS merger have been reflected in these financial statements. The preliminary fair value determination at the Targa level identified $984.2 million of intangible value and $0.4 million, net, of current liabilities, as of the acquisition date of February 27, 2015. The excess of the purchase price over the estimated fair value of net assets acquired was approximately $628.5 million, which was recorded as goodwill.
	All outstanding ATLS equity awards, whether vested or unvested, were adjusted in connection with the Spin-Off on the terms and conditions set forth in an Employee Matters Agreement entered into by ATLS, ATLS GP and AEG on February 27, 2015. Following the Spin-Off-related adjustment and at the ATLS Effective Time, each outstanding ATLS option and ATLS phantom unit award, whether vested or unvested, held by a person who became an employee of AEG became fully vested (to the extent not vested) and was cancelled and converted into the right to receive the ATLS Merger Consideration in respect of each ATLS common unit underlying the ATLS option or phantom unit award (in the case of options, net of the applicable exercise price). Each outstanding vested ATLS option held by an employee of APL who became an employee of Targa in connection with the Atlas Transactions (the “Midstream Employees”) was cancelled and converted into the right to receive the ATLS Merger Consideration in respect of each ATLS common unit underlying the vested ATLS option, net of the applicable exercise price. Each outstanding unvested ATLS option and each outstanding ATLS phantom unit award held by a Midstream Employee was cancelled and converted into the right to receive (1) the ATLS Cash Consideration in respect of each ATLS common unit underlying such ATLS option or phantom unit award and (2) a TRC restricted stock unit award with respect to a number of shares of TRC Common Stock equal to the product of the ATLS Stock Consideration multiplied by the number of ATLS common units underlying such ATLS option or phantom unit award (in the case of options, net of the applicable exercise price).
	In connection with the APL merger, each outstanding APL phantom unit award held by an employee of AEG became fully vested and was cancelled and converted into the right to receive the APL Merger Consideration in respect of each APL common unit underlying the APL phantom unit award. Each outstanding APL phantom unit award held by a Midstream Employee was cancelled and converted into the right to receive (1) the APL Cash Consideration in respect of each APL common unit underlying such APL phantom unit award and (2) a Partnership phantom unit award with respect to a number of our common units equal to the product of the APL Unit Consideration multiplied by the number of APL common units underlying such APL phantom unit award.
	Pro forma Impact of Atlas Mergers on Consolidated Statements of Operations
	The acquired business contributed revenues of $160.6 million and net income of $4.1 million to us for the period from February 27, 2015 to March 31, 2015, and is reported in our Field Gathering and Processing segment. In 2015, we incurred $13.7 million of acquisition-related costs. These expenses are included in other expense in our Consolidated Statement of Operations for the three months ended March 31, 2015.
	The following summarized unaudited pro forma consolidated statement of operations information for the three months ended March 31, 2015 and March 31, 2014 assumes that our acquisition of APL and Targa’s acquisition of ATLS had occurred as of January 1, 2014. We prepared the following summarized unaudited pro forma financial results for comparative purposes only. The summarized unaudited pro forma financial results may not be indicative of the results that would have occurred if we had completed the APL merger as of January 1, 2014, or that the results that will be attained in the future. Amounts presented below are in millions, except for the per unit amounts:
			31-Mar-15			31-Mar-14
			Pro forma			Pro forma
	Revenues		$	1,994.00		$	2,944.40
	Net income			71.7			129.2
	The pro forma consolidated results of operations amounts have been calculated after applying our accounting policies, and making adjustments to:
		·	Reflect the change in amortization expense resulting from the difference between the historical balances of APL’s intangible assets, net, and our preliminary estimate of the fair value of intangible assets acquired.
		·	Reflect the change in interest expense resulting from our financing activities directly related to the Atlas mergers as compared with APL’s historical interest expense.
		·	Reflect the changes in stock-based compensation expense related to the fair value of the unvested portion of replacement Partnership LTIP awards, which were issued in connection with the acquisition to APL phantom unitholders who will continue to provide service as Targa employees.
		·	Remove the results of operations attributable to APL businesses sold during the periods: (1) the May 2014 sale of APL’s 20% interest in West Texas LPG Pipeline Limited Partnership and (2) the February 2015 transfer of 100% of APL’s interest in gas gathering assets located in the Appalachian Basin of Tennessee to Atlas Resource Partners, L.P.
	·	Exclude $13.7 million of acquisition-related costs incurred in 2015 from pro forma net income for the three months ended March 31, 2015. Pro forma net income for the three months ended March 31, 2014 was adjusted to include these charges.
	The following table summarizes the consideration transferred to acquire ATLS and APL, which are viewed together as a single integrated transaction for GAAP reporting purposes:
	Fair Value of Consideration Transferred by Targa for ATLS:
	Cash, net of cash acquired (1)		$	745.7
	Common shares of TRC			1,008.50
	Replacement restricted stock units awarded (3)			5.2
	Less: value of  APL common units owned by ATLS			(147.4	)
	Total		$	1,612.00
	Fair Value of Consideration Transferred for APL:
	Cash, net of cash acquired (2)		$	852.3
	Common units of TRP			2,568.50
	Replacement phantom units awarded (3)			15
	Total		$	3,435.80
	Total fair value of consideration transferred		$	5,047.80
	___________
	-1	Targa acquired $5.5 million of cash. Targa also received $7.3 million in April 2015 as part of the Atlas mergers, representing the one-time cash payment from us for the APL common units owned by ATLS.
	-2	We acquired $11.7 million of cash.
	-3	The fair value of consideration transferred in the form of replacement restricted stock unit awards and replacement phantom unit awards represent the allocation of the fair value of the awards to the pre-combination service period. The fair value of the awards associated with the post-combination service period will be recognized over the remaining service period of the award.
	As of February 27, 2015, our preliminary fair value determination related to the Atlas mergers was as follows. The excess of the purchase price over the estimated fair value of net assets acquired was approximately $628.5 million, which was recorded as goodwill. This determination is based on our preliminary valuation and is subject to revisions pending the completion of valuation and other adjustments.
	Preliminary fair value determination:		27-Feb-15
	Trade and other current receivables, net		$	183.9
	Other current assets			26.5
	Assets from risk management activities			102.1
	Property, plant and equipment			4,944.00
	Investments in unconsolidated affiliates			273.7
	Intangible assets			1,035.00
	Other long-term assets			6.6
	Current liabilities, less current portion of long-term debt			(233.5	)
	Long-term debt			(1,573.8	)
	Deferred income tax liabilities, net			(30.2	)
	Other long-term liabilities			(10.7	)
	Noncontrolling interest in subsidiaries			(303.9	)
	Total identifiable net assets		$	4,419.70
	Current liabilities retained by Targa		$	(0.4	)
	Goodwill		$	628.5
Our valuation of the acquired assets and liabilities is ongoing and may result in future measurement period adjustments to these preliminary fair values. The fair values of property, plant and equipment, investments in unconsolidated affiliates, intangible assets representing the GP interest, IDRs, customer contracts and customer relationships, deferred income taxes related to APL Arkoma, Inc., a taxable subsidiary acquired, and noncontrolling interest, which is calculated as a proportionate share of the fair value of the acquired joint ventures’ net assets, are provisional pending completion of final valuations. As a result, goodwill is also provisional, as it has been recorded as the excess of the purchase price over the estimated fair value of net assets acquired.
The preliminary valuation of the acquired assets and liabilities was prepared using fair value methods and assumptions including projections of future production volumes and cash flows, benchmark analysis of comparable public companies, expectations regarding customer contracts and relationships, and other management estimates. The fair value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market and therefore represent Level 3 inputs, as defined in Note 14 – Fair Value Measurements. These inputs require significant judgments and estimates at the time of valuation.
The preliminary determination of goodwill of $628.5 million is attributable to the workforce of the acquired business and the significant synergies expected to arise after Targa’s acquisition of ATLS and our acquisition of APL. The goodwill is expected to be amortizable for tax purposes. The allocation of the goodwill to our reporting units will be completed in conjunction with our finalization of the fair value determination.
The fair value of assets acquired includes trade receivables of $180.9 million. The gross amount due under contracts is $180.9 million, all of which is expected to be collectible. The fair value of assets acquired includes receivables related to a contractual settlement with a counterparty of $3.0 million reported in current receivables and $4.5 million reported in other long-term assets both of which are expected to be collectible.
See Note 10, for additional disclosures regarding related financing activities associated with the Atlas mergers.
Contingent Consideration
A liability arising from the contingent consideration for APL’s previous acquisition of a gas gathering system and related assets has been recognized at fair value. APL agreed to pay up to an additional $6.0 million if certain volumes are achieved on the acquired gathering system within a specified time period. As of February 27, 2015, the fair value of the remaining contingent payment resulted in a $6.0 million long term liability, which is recorded within other long term liabilities on our Consolidated Balance Sheets. The range of the undiscounted amount that we could pay related to the remaining contingent payment is between $0.0 and $6.0 million. The fair value of this contingent liability is preliminary as of March 31, 2015 as we are in the process of assessing the probabilities of production forecast scenarios and the resulting impact on this contingent valuation.
Replacement Phantom Units
In connection with the Atlas mergers, we awarded replacement phantom units in accordance with and as required by the Atlas Merger Agreements to those APL employees who became Targa employees after the acquisition. The vesting dates and terms remained unchanged from the existing APL awards, and will vest over the remaining terms of the awards, which are either 25% per year over the original four year term or 33% per year over the original three year term.
Each replacement phantom unit will entitle the grantee to one common unit on the vesting date and is an equity-settled award. The replacement phantom units include distribution equivalent rights (“DERs”). When we declare and pay cash distributions, the holders of replacement phantom units will be entitled within 60 days to receive cash payment of DERs in an amount equal to the cash distributions the holders would have received if they were the holders of record on the record date of the number of our common units related to the replacement phantom units.
The fair value of the replacement phantom units was based on the closing price of our units at the close of trading on February 27, 2015. The fair value was allocated between the pre-acquisition and post-acquisition periods to determine the amount to be treated as purchase consideration and future compensation expense, respectively. Compensation cost will be recognized in general and administrative expense over the remaining service period of each award.

Inventories

Inventories	3 Months Ended
	Mar. 31, 2015
Inventories [Abstract]
Inventories	Note 5 — Inventories
		31-Mar-15		31-Dec-14
	Commodities	$	66.9	$	157.4
	Materials and supplies		11.3		11.5
		$	78.2	$	168.9

Property_Plant_and_Equipment_a

Property, Plant and Equipment and Intangible Assets	3 Months Ended
	Mar. 31, 2015
Property, Plant and Equipment and Intangible Assets [Abstract]
Property, Plant and Equipment and Intangible Assets	Note 6 — Property, Plant and Equipment and Intangible Assets
		31-Mar-15			31-Dec-14			Estimated useful life
								(In years)
	Gathering systems	$	6,113.80		$	2,588.60		5 to 40
	Processing and fractionation facilities		2,924.60			1,884.10		5 to 40
	Terminaling and storage facilities		1,043.00			1,038.90		5 to 25
	Transportation assets		432.9			359		10 to 25
	Other property, plant and equipment		219.9			149.1		3 to 40
	Land		101.4			95.6		-
	Construction in progress		782.2			399		-
	Property, plant and equipment		11,617.80			6,514.30
	Accumulated depreciation		(1,784.9	)		(1,689.7	)
	Property, plant and equipment, net	$	9,832.90		$	4,824.60
	Intangible assets	$	1,716.60		$	681.8		20
	Accumulated amortization		(114.2	)		(89.9	)
	Intangible assets, net	$	1,602.40		$	591.9
	Intangible assets consist of customer contracts and customer relationships acquired in the Atlas mergers and our Badlands business acquisitions. The fair values of these acquired intangible assets were determined at the dates of acquisition based on the present values of estimated future cash flows. Key valuation assumptions include probability of contracts under negotiation, renewals of existing contracts, economic incentives to retain customers, past and future volumes, current and future capacity of the gathering system, pricing volatility and the discount rate.
	The fair values of intangible assets acquired in the Atlas mergers have been recorded at a provisional value of $1,035.0 million pending completion of final valuations. For the purpose of our preparing the accompanying financial statements (which include one month of amortization of these intangible assets) we have amortized these intangible assets over a 20 year life using a straight-line method. The amortization method and lives for the Atlas mergers intangible assets will be reviewed and possibly revised as we finalize the valuations over the upcoming months.
	Amortization expense attributable to our intangible assets related to the Badlands acquisition is recorded using a method that closely reflects the cash flow pattern underlying their intangible asset valuation. The estimated annual amortization expense for intangible assets, including the provisional Atlas valuation and straight-line treatment is approximately $123.2 million, $140.1 million, $133.3 million, $119.5 million and $108.6 million for each of the years 2015 through 2019.

Investments_in_Unconsolidated_

Investments in Unconsolidated Affiliates	3 Months Ended
	Mar. 31, 2015
Investments in Unconsolidated Affiliates [Abstract]
Investments in Unconsolidated Affiliates	Note 7 — Investments in Unconsolidated Affiliates
	At December 31, 2014, our unconsolidated investment consisted of a 38.8% ownership interest in Gulf Coast Fractionators LP (“GCF”). As of March 31, 2015, we continue to have a 38.8% ownership interest in GCF.
	On February 27, 2015, as part of the Atlas mergers, we acquired equity interests in three non-operated joint ventures in South Texas; (1) a 75% interest in T2 LaSalle, (2) a 50% interest in T2 Eagle Ford and (3) a 50% interest in T2 EF Co-Gen (together the “T2 Joint Ventures”). The T2 Joint Ventures were formed to provide services for the benefit of the joint interest owners. The T2 Joint Ventures have capacity lease agreements with the joint interest owners, which cover the costs of operations of the T2 Joint Ventures. The terms of these joint venture agreements do not afford us the degree of control required for consolidating them in our financial statements, but do afford us the significant influence required to employ the equity method of accounting.
	The following table shows the activity related to our investments in unconsolidated affiliates:
			Three Months Ended March 31, 2015
	Beginning of period		$	50.2
	Preliminary fair value of T2 Joint Ventures acquired (1)			273.7
	Equity earnings			1.7
	Cash distributions (2)			(2.7	)
	End of period		$	322.9
	___________
	-1	Includes equity earnings of acquired investments since the date of acquisition of February 27, 2015.
	-2	Includes $0.6 million distributions received in excess of our share of cumulative earnings for the three months ended March 31, 2015. Such excess distributions are considered a return of capital and are disclosed in cash flows from investing activities in the Consolidated Statements of Cash Flows.
	The allocated cost basis of the T2 Joint Ventures investment is based on preliminary fair values at the date of acquisition with a basis difference of approximately $99.1 million. This basis difference is being amortized over the preliminary estimated useful lives of the underlying assets of 20 years on a straight-line basis and is included as a component of equity earnings. See Note 4 for further information regarding the preliminary fair value determinations related to the Atlas mergers.

Accounts_Payable_and_Accrued_L

Accounts Payable and Accrued Liabilities	3 Months Ended
	Mar. 31, 2015
Accounts Payable and Accrued Liabilities [Abstract]
Accounts Payable and Accrued Liabilities	Note 8 — Accounts Payable and Accrued Liabilities
		31-Mar-15		31-Dec-14
	Commodities	$	445.8	$	416.7
	Other goods and services		169.8		108.9
	Interest		57		37.3
	Compensation and benefits		3.2		1.3
	Income and other taxes		20		13.6
	Other		15		14.9
		$	710.8	$	592.7

Asset_Retirement_Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligations [Abstract]
Asset Retirement Obligations	Note 9 — Asset Retirement Obligations
	Our asset retirement obligations (“ARO”) 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 March 31, 2015
	Beginning of period	$	56.8
	Preliminary fair value of ARO acquired with the APL merger		4.1
	Change in cash flow estimate		3.7
	Accretion expense		1.3
	End of period	$	65.9

Debt_Obligations

Debt Obligations	3 Months Ended
	Mar. 31, 2015
Debt Obligations [Abstract]
Debt Obligations	Note 10 — Debt Obligations
			31-Mar-15			31-Dec-14
	Current:
	Accounts receivable securitization facility, due December 2015		$	197.9		$	182.8
	Long-term:
	Senior secured revolving credit facility, variable rate, due October 2017 (1)			840			-
	Senior unsecured notes, 5% fixed rate, due January 2018			1,100.00			-
	Senior unsecured notes, 6⅞% fixed rate, due February 2021			483.6			483.6
	Unamortized discount			(24.5	)		(25.2	)
	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
	Senior unsecured notes, 4⅛% fixed rate, due November 2019			800			800
	Senior unsecured notes, 6⅝% fixed rate, due October 2020 (2)			355.1			-
	Unamortized premium			6			-
	Senior unsecured notes, 4¾% fixed rate, due November 2021 (2)			6.5			-
	Senior unsecured notes, 5⅞% fixed rate, due August 2023 (2)			48.1			-
	Unamortized premium			0.6			-
	Total long-term debt			5,140.40			2,783.40
	Total Debt		$	5,338.30		$	2,966.20
	Letters of credit outstanding		$	25		$	44.1
	________
	-1	As of March 31, 2015, availability under our $1.6 billion senior secured revolving credit facility was $735.0 million.
	-2	Senior unsecured notes issued by APL entities and acquired in the Atlas mergers.
	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, 2015:
		Range of Interest Rates Incurred		Weighted Average Interest Rate Incurred
	Senior secured revolving credit facility	1.90%		1.90%
	Accounts receivable securitization facility	0.90%		0.90%
	Compliance with Debt Covenants
	As of March 31, 2015, we were in compliance with the covenants contained in our various debt agreements.
	Merger Financing Activities
	Revolving Credit Agreement
	In February 2015, we entered into the First Amendment, Waiver and Incremental Commitment Agreement (the “First Amendment”) that amended our Second Amended and Restated Credit Agreement (the “Original Agreement”). The First Amendment increased available commitments to $1.6 billion from $1.2 billion while retaining our ability to request up to an additional $300.0 million in commitment increases. In addition, the First Amendment amends certain provisions of the Original Agreement and designates each of APL and its subsidiaries as an “Unrestricted Subsidiary.” We used proceeds from borrowings under the credit facility to fund cash components of the APL merger, including $701.4 million for the repayments of the APL Revolver and $28.8 million related to change of control payments.
	Senior Unsecured Notes
	In January 2015, we privately placed $1,100.0 million in aggregate principal amount of 5% Senior Notes due 2018 (the “5% Notes”). The 5% Notes resulted in approximately $1,089.8 million of net proceeds, which were used with borrowings under our revolver to fund the APL Note Tender Offers (as defined below). The 5% Notes are unsecured senior obligations that have the same terms and covenants as our other senior notes.
	APL Senior Notes Tender Offers
	In January 2015, we commenced cash tender offers for any and all of the outstanding fixed rate senior notes acquired in the APL merger (“APL Notes”), referred to as the APL Note Tender Offers, which totaled $1,550.0 million.
	The results of the APL Note Tender Offers were:
	Senior Notes		Outstanding Note Balance			Amount Tendered			Premium Paid		Accrued Interest Paid		Total Tender Offer payments		% Tendered			Note Balance after Tender Offers
			($ amounts in millions)
	6⅝% due 2020		$	500		$	140.1		$	2.1	$	3.7	$	145.9		28.02	%	$	359.9
	4¾% due 2021			400			393.5			5.9		5.3		404.7		98.38	%		6.5
	5⅞% due 2023			650			601.9			8.7		2.6		613.2		92.6	%		48.1
	Total		$	1,550.00		$	1,135.50		$	16.7	$	11.6	$	1,163.80				$	414.5
	In connection with the APL Notes Tender Offers, on February 27, 2015, (i) the First Supplemental Indenture (the “2021 APL Notes Supplemental Indenture”) to the Indenture, dated as of May 10, 2013, by and among the APL Issuers, the Subsidiary Guarantors named therein and U.S. Bank National Association, as trustee, governing the 2021 APL Notes, became operative, and (ii) the Third Supplemental Indenture (the “2023 APL Notes Supplemental Indenture” and, together with the 2021 APL Notes Supplemental Indenture, the “February APL Supplemental Indentures”) to the Indenture, dated as of February 11, 2013, by and among the APL Issuers, the Subsidiary Guarantors named therein and U.S. Bank National Association, as trustee, governing the 2023 APL Notes, became operative. The February APL Supplemental Indentures eliminate substantially all of the restrictive covenants and certain events of default applicable to the 2021 APL Notes and the 2023 APL Notes that were not accepted for payment. The indenture governing the 2020 APL Notes (the “2020 APL Notes Indenture”) remained unchanged at such time.
	Not having achieved the minimum tender condition on the 2020 APL Notes, the change of control terms of the 2020 APL Notes Indenture required the APL Issuers to offer holders $1,010 for each $1,000 principal amount of outstanding notes plus accrued and unpaid interest from the most recent interest payment date. As permitted by the 2020 APL Notes Indenture, in lieu of the APL issuers, we made a change of control offer for any and all of the 2020 APL Notes and in advance of, and conditioned upon, the consummation of the APL merger. Holders representing $4.8 million of the outstanding 2020 APL Notes tendered their notes requiring a payment of $5.0 million, which included the change of control premium and accrued interest.
	Payments made under the APL Notes Tender Offers and Change of Control Offer totaling $1,168.8 million are presented as financing activities in the Statement of Cash Flows.
	Subsequent event. On April 13, 2015, we and Targa Resources Partners Finance Corporation (collectively, the “Partnership Issuers” commenced an offer to exchange (the “Exchange Offer”) any and all of the outstanding 2020 APL Notes, which had an aggregate principal amount outstanding of $355.1 million, for an equal amount of new unsecured 6 5/8% Senior Notes due 2020 issued by the Partnership Issuers (the “6 5/8% Notes”). On April 27, 2015, the Partnership Issuers had received tenders and consents from holders of approximately $341.9 million in aggregate principal amount of the 2020 APL Notes, representing approximately 96.3% of the total outstanding $355.1 million in aggregate principal amount of the 2020 APL Notes. As a result, the minimum tender condition to the Exchange Offer and related consent solicitation has been satisfied, and the APL Issuers executed a supplemental indenture (the “APL Supplemental Indenture”) effecting the proposed amendments with respect to the 2020 APL Notes, which satisfied the second condition.
	The APL Supplemental Indenture eliminates substantially all of the restrictive covenants and certain events of default applicable to the 2020 APL Notes. Consummation of the Exchange Offer, however, remains subject to certain other customary conditions. Settlement of the Exchange Offer will occur promptly after the Exchange Offer expires, which will be at 11:59 p.m., New York City time, on May 8, 2015, unless otherwise extended or terminated by the Partnership Issuers. The APL Supplemental Indenture will become operative upon settlement of the Exchange Offer.
	Subsequent Event
	In April 2015, we filed with the SEC a universal shelf registration statement that allows us to issue up to an aggregate of $1.0 billion of debt or equity securities (the "April 2015 Shelf"). The April 2015 Shelf expires in April 2018.

Partnership_Units_and_Related_

Partnership Units and Related Matters	3 Months Ended
	Mar. 31, 2015
Partnership Units and Related Matters [Abstract]
Partnership Units and Related Matters	Note 11 — Partnership Units and Related Matters
	Issuances of Common Units
	As part of the APL mergers, we issued 58,614,157 common units to former APL unitholders as consideration for the APL mergers, of which 3,363,935 common units represented ATLS’s common unit ownership in APL and were issued to Targa.
	In May 2014, we entered into an additional Equity Distribution Agreement under a shelf registrations statement filed in July 2013 (the “May 2014 EDA”), pursuant to which we may sell through our sales agents, at option, up to an aggregate of $400.0 million of our common units. During the three months ended March 31, 2015, we issued 1,271,876 common units under the May 2014 EDA, receiving total net proceeds of $53.0 million (net of commissions up to 1% of gross proceeds to our sales agent) of which $24.8 million was received in April. Targa contributed $1.1 million to us to maintain its 2% general partner interest, of which $0.8 million was received in April 2015.
	Subsequent Event
	During April 2015, we issued 2,318,950 common units under the May 2014 EDA, receiving net proceeds of $100.1 million. Targa contributed $2.1 million to us to maintain its 2% general partner interest. As of April 20, 2015, approximately $4.2 million of the aggregate offering amount remained available for sale pursuant to the May 2014 EDA.
	Distributions
	We must distribute all of our available cash, as defined in the Partnership Agreement, and 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, 2015.
				Distributions
	Three Months Ended		Date Paid or to be Paid	Limited Partners		General Partner							Distributions per Limited Partner Unit
				Common			Incentive Distribution Rights		2%		Total
				(In millions, except per unit amounts)
	31-Mar-15		15-May-15	$	148.3		$	41.7	$	3.9	$	193.9	$	0.82
	31-Dec-14		13-Feb-15	$	96.3		$	38.4	$	2.7	$	137.4	$	0.81
	____________
	-1	Pursuant to the IDR Giveback Amendment in conjunction with the Atlas mergers, IDR’s of $9.375 million were allocated to common unitholders in the first quarter of 2015. The IDR Giveback Amendment covers sixteen quarterly distribution declarations following the February 27, 2015 Atlas mergers and will result in reallocation of IDR payments to common unitholders at the following amounts - $9.375 million per quarter for 2015, $6.25 million per quarter for 2016, $2.5 million per quarter for 2017 and $1.25 million per quarter for 2018.

Earnings_per_Limited_Partner_U

Earnings per Limited Partner Unit	3 Months Ended
	Mar. 31, 2015
Earnings per Limited Partner Unit [Abstract]
Earnings per Limited Partner Unit	Note 12 — 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 unit:
		Three Months Ended March 31,
		2015		2014
	Net income	$	76.5	$	131.3
	Less: Net income attributable to noncontrolling interests		4.9		8.9
	Net income attributable to Targa Resources Partners LP	$	71.6	$	122.4
	Net income attributable to general partner	$	42.5	$	33.8
	Net income attributable to limited partners		29.1		88.6
	Net income attributable to Targa Resources Partners LP	$	71.6	$	122.4
	Weighted average units outstanding - basic		137.1		112.4
	Net income available per limited partner unit - basic	$	0.21	$	0.79
	Weighted average units outstanding		137.1		112.4
	Dilutive effect of unvested stock awards		0.4		0.6
	Weighted average units outstanding - diluted		137.5		113
	Net income available per limited partner unit - diluted	$	0.21	$	0.78

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities [Abstract]
Derivative Instruments and Hedging Activities	Note 13 — 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 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 delivery points of our physical equity volumes. Our natural gas hedges are a mixture of specific gas delivery points and Henry Hub. 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.
	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.
	As part of the Atlas mergers, outstanding APL derivative contracts with a fair value of $102.1 million as of the acquisition date were novated to the Partnership, intended as cash flow hedges related to future TPL equity volumes. As the fair value of these APL derivative contracts settle, we will receive cash representing the future benefit of these contracts. For the quarter ended March 31, 2015, $7.8 million of the acquisition date fair value of the APL derivative contracts was received as a component of the derivative contract settlements.
	The "off-market" nature of these acquired derivatives can introduce a degree of ineffectiveness for accounting purposes due to an embedded financing element representing the amount that would have to be paid or received as of the acquisition date to settle the derivative contract. The resulting ineffectiveness can either potentially disqualify the derivative contract in its entirety for hedge accounting or alternatively affect the amount of unrealized gains or losses on qualifying derivatives that can be deferred from inclusion in periodic net income. Certain novated APL crude options with a fair value of $7.7 million as of the acquisition date did not fall within the “highly effective” correlation range required to qualify as a hedging instrument for accounting purposes and resulted in $0.5 million of mark-to-market gains included in our first quarter 2015 earnings. These crude oil options expire during 2015. Additionally our first quarter included $1.0 million of ineffectiveness gains related to otherwise qualifying APL derivatives, primarily natural gas swaps.
	At March 31, 2015, the notional volumes of our commodity hedges were:
	Commodity		Instrument		Unit			2015		2016		2017
	Natural Gas		Swaps		MMBtu/d			125,439		68,205		23,082
	Natural Gas		Basis Swaps		MMBtu/d			23,782		-		-
	NGL		Swaps		Bbl/d			5,928		2,254		658
	NGL		Options		Bbl/d			899		790		790
	Condensate		Swaps		Bbl/d			1,991		1,082		500
	Condensate		Options		Bbl/d			1,198		380		380
	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 within the same Targa entity. 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, 2015								Fair Value as of December 31, 2014
			Balance Sheet		Derivative				Derivative				Derivative				Derivative
			Location		Assets				Liabilities				Assets				Liabilities
	Derivatives designated as hedging instruments
	Commodity contracts		Current		$	117.8			$	0.4			$	44.4			$	-
			Long-term			51.2				1.8				15.8				-
	Total derivatives designated as hedging instruments				$	169			$	2.2			$	60.2			$	-
	Derivatives not designated as hedging instruments
	Commodity contracts		Current		$	8.2			$	0.2			$	-			$	5.2
	Total derivatives not designated as hedging instruments				$	8.2			$	0.2			$	-			$	5.2
	Total current position				$	126			$	0.6			$	44.4			$	5.2
	Total long-term position					51.2				1.8				15.8				-
	Total derivatives				$	177.2			$	2.4			$	60.2			$	5.2
	The pro forma impact of reporting derivatives in the Consolidated Balance Sheets on a net basis is as follows:
			Gross Presentation								Pro forma Net Presentation
			Asset				Liability				Asset				Liability
	31-Mar-15		Position				Position				Position				Position
	Current position
	Counterparties with offsetting position		$	54			$	0.6			$	53.4			$	-
	Counterparties without offsetting position - assets			72				-				72				-
	Counterparties without offsetting position - liabilities			-				-				-				-
				126				0.6				125.4				-
	Long-term position
	Counterparties with offsetting position			19.4				1.8				17.6				-
	Counterparties without offsetting position - assets			31.8				-				31.8				-
	Counterparties without offsetting position - liabilities			-				-				-				-
				51.2				1.8				49.4				-
	Total derivatives
	Counterparties with offsetting position			73.4				2.4				71				-
	Counterparties without offsetting position - assets			103.8				-				103.8				-
	Counterparties without offsetting position - liabilities			-				-				-				-
			$	177.2			$	2.4			$	174.8			$	-
	31-Dec-14
	Current position
	Counterparties with offsetting position		$	35.5			$	4.4			$	31.1			$	-
	Counterparties without offsetting position - assets			8.9				-				8.9				-
	Counterparties without offsetting position - liabilities			-				0.8				-				0.8
				44.4				5.2				40				0.8
	Long-term position
	Counterparties with offsetting position			-				-				-				-
	Counterparties without offsetting position - assets			15.8				-				15.8				-
	Counterparties without offsetting position - liabilities			-				-				-				-
				15.8				-				15.8				-
	Total derivatives
	Counterparties with offsetting position			35.5				4.4				31.1				-
	Counterparties without offsetting position - assets			24.7				-				24.7				-
Counterparties without offsetting position - liabilities			-				0.8				-				0.8
		$	60.2			$	5.2			$	55.8			$	0.8
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 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 asset of $174.8 million as of March 31, 2015. 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.
The following tables reflect amounts recorded in Other Comprehensive Income (“OCI”) and amounts reclassified from OCI to revenue and expense for the periods indicated:
		Gain (Loss) Recognized in OCI on Derivatives
		(Effective Portion)
Derivatives in Cash Flow Hedging Relationships		Three Months Ended March 31,
		2015				2014
Commodity contracts		$	25.2			$	(11.9	)
		Gain (Loss) Reclassified from OCI into Income
		(Effective Portion)
Location of Gain (Loss)		Three Months Ended March 31,
		2015				2014
Interest expense, net		$	-			$	(1.3	)
Revenues			8.1				(6.3	)
		$	8.1			$	(7.6	)
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 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 in Income on Derivatives
Derivatives Not Designated as Hedging Instruments		Location of Gain Recognized in Income on Derivatives		31-Mar-15				31-Mar-14
Commodity contracts		Revenue		$	7.2			$	(0.2	)
The following table shows the deferred gains (losses) included in accumulated OCI, which will be reclassified into earnings through the end of 2017 based on year-end valuations.
		31-Mar-15				31-Dec-14
Commodity hedges (1)		$	77.4			$	60.3
___________
-1	Includes deferred net gains of $53.3 million as of March 31, 2015 related to contracts that will be settled and reclassified to revenue over the next 12 months.
See Note 14 for additional disclosures related to derivative instruments and hedging activities.

Fair_Value_Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2015
Fair Value Measurements [Abstract]
Fair Value Measurements	Note 14 — 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. 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 present value methods or standard option valuation models with assumptions about commodity prices based on those observed in underlying 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 of these derivatives at March 31, 2015, a net asset position of $174.8 million, 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 asset of $132.7 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 $199.2 million, ignoring an adjustment for counterparty credit risk.
	Fair Value of Other Financial Instruments
	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. Long-term debt is primarily the other financial instrument for which carrying value could vary significantly from fair value. We determined the supplemental fair value disclosures for our long-term debt as follows:
		·	The senior secured revolving credit facility (the “TRP Revolver”)  and our accounts receivable securitization facility (the “Securitization Facility”) are based on carrying value, which approximates fair value as the interest rates are 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-15
			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)		$	177.2		$	177.2	$	-	$	172.9	$	4.3
	Liabilities from commodity derivative contracts (1)			2.4			2.4		-		1.6		0.8
	Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
	Cash and cash equivalents			63.5			63.5		-		-		-
	Senior secured revolving credit facility			840			840		-		840		-
	Senior unsecured notes			4,300.40			4,384.90		-		4,384.90		-
	Accounts receivable securitization facility			197.9			197.9		197.9		-		-
	______________
	-1	The fair value of our derivative contracts in this table is presented on a different basis than the Consolidated Balance Sheets presentation as disclosed in Note 13. The above fair values reflect the total value of each derivative contract taken as a whole, whereas the Consolidated Balance Sheets 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 Consolidated Balance Sheets classification purposes.
	Additional Information Regarding Level 3 Fair Value Measurements Included in Our Consolidated Balance Sheets
	We reported certain of our swaps and option contracts 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 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, 2015, we had 13 commodity swaps and options contracts categorized as Level 3. The significant unobservable inputs used in the fair value measurements of our Level 3 derivatives are the forward natural gas 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, 2014			(1.7	)
	Settlements included in Revenue			-
	Unrealized gains included in OCI			(1.1	)
	Transfers into Level 3			(0.6	)
	Transfers out of Level 3			(0.1	)
	Balance, March 31, 2015		$	(3.5	)
	For the three months ended March 31, 2015, the Partnership transferred $0.1 million in derivative liabilities out of Level 3 and into Level 2. This transfer related to long-term over-the-counter swaps for natural gas and NGL products with deliveries for which observable market prices were available.

Related_Party_Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2015
Related Party Transactions [Abstract]
Related Party Transactions	Note 15 — Related Party Transactions
	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,
		2015		2014
	Targa billings of payroll and related costs included in operating expense	$	34.9	$	29.9
	Targa allocation of general and administrative expense		38.3		33.4
	Cash distributions to Targa based on unit ownership		51.6		41.5
			53.6		2.4
	Cash contributions from Targa to maintain its 2% general partner ownership

Contingencies

Contingencies	3 Months Ended
	Mar. 31, 2015
Contingencies [Abstract]
Contingencies	Note 16 - Contingencies
	Legal Proceedings
	Targa Shareholder Litigation
	On January 28, 2015, a public shareholder of Targa (the “TRC Plaintiff”) filed a putative class action and derivative lawsuit against Targa (as a nominal defendant), its directors at the time of the ATLS merger (the “TRC Director Defendants”), and ATLS (together with Targa and the TRC Director Defendants, the “TRC Lawsuit Defendants”). This lawsuit is styled Inspired Investors v. Joe Bob Perkins, et al., Cause No. 2015-04961, in the District Court of Harris County, Texas (the “TRC Lawsuit”).
	The TRC Plaintiff alleged a variety of causes of action challenging the ATLS merger and the disclosures related to the ATLS merger. Generally, the TRC Plaintiff alleged that the TRC Director Defendants breached their fiduciary duties.  The TRC Plaintiff further alleged that the registration statement filed on January 22, 2015 fails to disclose allegedly material details concerning (i) Wells Fargo Securities, LLC’s and the TRC Director Defendants’ supposed conflicts of interest with respect to the ATLS merger, (ii) Targa’s financial projections, (iii) the background of the ATLS merger, and (iv) Wells Fargo Securities, LLC’s analysis of the ATLS merger. The TRC Plaintiff also alleged that Targa overpaid to acquire ATLS.
	Based on these allegations, the TRC Plaintiff sought to enjoin the TRC Lawsuit Defendants from proceeding with or consummating the ATLS merger. The TRC Plaintiff also seeks rescission, damages, and attorneys’ fees. On February 25, 2015, the Harris County trial court denied the TRC Plaintiff’s request for a preliminary injunction. The ATLS merger occurred on February 27, 2015.  The TRC Plaintiff has indicated that it intends to dismiss the TRC Lawsuit with prejudice. Should the TRC Plaintiff decide not to dismiss, TRC Lawsuit Defendants will seek dismissal of the TRC Lawsuit.
	Atlas Unitholder Litigation
	Between October and December 2014, five public unitholders of APL (the “APL Plaintiffs”) filed putative class action lawsuits against APL, ATLS, APL GP, its managers, Targa, the Partnership, the general partner and MLP Merger Sub (the “APL Lawsuit Defendants”). These lawsuits are styled (a) Michael Evnin v. Atlas Pipeline Partners, L.P., et al., in the Court of Common Pleas for Allegheny County, Pennsylvania; (b) William B. Federman Family Wealth Preservation Trust v. Atlas Pipeline Partners, L.P., et al., in the District Court of Tulsa County, Oklahoma (the “Tulsa Lawsuit”); (c) Greenthal Living Trust U/A 01/26/88 v. Atlas Pipeline Partners, L.P., et al., in the Court of Common Pleas for Allegheny County, Pennsylvania; (d) Mike Welborn v. Atlas Pipeline Partners, L.P., et al., in the Court of Common Pleas for Allegheny County, Pennsylvania; and (e) Irving Feldbaum v. Atlas Pipeline Partners, L.P., et al., in the Court of Common Pleas for Allegheny County, Pennsylvania, though the Tulsa Lawsuit has since been voluntarily dismissed. The Evnin, Greenthal, Welborn and Feldbaum lawsuits have been consolidated as In re Atlas Pipeline Partners, L.P. Unitholder Litigation, Case No. GD-14-019245, in the Court of Common Pleas for Allegheny County, Pennsylvania (the “Consolidated APL Lawsuit”). In October and November 2014, two public unitholders of ATLS (the “ATLS Plaintiffs” and, together with the APL Plaintiffs, the “Atlas Lawsuit Plaintiffs”) filed putative class action lawsuits against ATLS, ATLS Energy GP, LLC, the general partner of ATLS (“ATLS GP”), its managers, Targa and GP Merger Sub (the “ATLS Lawsuit Defendants” and, together with the APL Lawsuit Defendants, the “Atlas Lawsuit Defendants”). These lawsuits are styled (a) Rick Kane v. Atlas Energy, L.P., et al., in the Court of Common Pleas for Allegheny County, Pennsylvania and (b) Jeffrey Ayers v. Atlas Energy, L.P., et al., in the Court of Common Pleas for Allegheny County, Pennsylvania (the “ATLS Lawsuits”). The ATLS Lawsuits have been consolidated as In re Atlas Energy, L.P. Unitholder Litigation, Case No. GD-14-019658, in the Court of Common Pleas for Allegheny County, Pennsylvania (the “Consolidated ATLS Lawsuit” and, together with the Consolidated APL Lawsuit, the “Consolidated Atlas Lawsuits”), though the Tulsa lawsuit and the Kane lawsuit have been dismissed.
	The Atlas Lawsuit Plaintiffs allege a variety of causes of action challenging the Atlas mergers. Generally, the APL Plaintiffs alleged that (a) APL GP’s managers have breached the covenant of good faith and/or their fiduciary duties and (b) Targa, the Partnership, the general partner, MLP Merger Sub, APL, ATLS and APL GP have aided and abetted in these alleged breaches of the covenant of good faith and/or fiduciary duties. The APL Plaintiffs further alleged that (a) the premium offered to APL’s unitholders is inadequate, (b) APL agreed to contractual terms that will allegedly dissuade other potential acquirers from seeking to acquire APL, and (c) APL GP’s managers favored their self-interests over the interests of APL’s unitholders. The APL Plaintiffs in the Consolidated APL Lawsuit also allege that the registration statement filed on November 19, 2014 fails, among other things, to disclose allegedly material details concerning (i) Stifel, Nicolaus & Company, Incorporated’s analysis of the ATLS merger and APL merger (the “Transactions”); (ii) APL and the Partnership’s financial projections; and (iii) the background of the Transactions. Generally, the ATLS Plaintiffs alleged that (a) ATLS GP’s directors have breached the covenant of good faith and/or their fiduciary duties and (b) Targa, GP Merger Sub, and ATLS have aided and abetted in these alleged breaches of the covenant of good faith and/or fiduciary duties. The ATLS Plaintiffs further alleged that (a) the premium offered to the ATLS unitholders was inadequate, (b) ATLS agreed to contractual terms that would allegedly dissuade other potential acquirers from seeking to acquire ATLS, (c) ATLS GP’s directors favored their self-interests over the interests of the ATLS unitholders and (d) the registration statement failed to disclose allegedly material details concerning, among other things, (i) Wells Fargo Securities, LLC, Stifel, Nicolaus & Company, Incorporated, and Deutsche Bank Securities Inc.’s analyses of the Transactions; (ii) the Partnership, Targa, APL, and ATLS’ financial projections; and (iii) the background of the Transactions.
	Based on these allegations, the Atlas Lawsuit Plaintiffs sought to enjoin the Atlas Lawsuit Defendants from proceeding with or consummating the Atlas mergers unless and until APL and ATLS adopted and implemented processes to obtain the best possible terms for their respective unitholders. The Atlas Lawsuit Plaintiffs also sought rescission, damages and attorneys’ fees.
	The parties to the Consolidated Atlas Lawsuits agreed to settle the Consolidated Atlas Lawsuits on February 9, 2015. In general, the settlements provide that in consideration for the dismissal of the Consolidated Atlas Lawsuits, ATLS and APL will provide supplemental disclosures regarding the Atlas mergers in a filing with the SEC on Form 8-K, which ATLS and APL did on February 11, 2015. The Atlas Lawsuit Defendants agreed to make such supplemental disclosures solely to avoid the uncertainty, risk, burden, and expense inherent in litigation and deny that any supplemental disclosure was or is required under any applicable rule, statute, regulation or law. The parties to the Consolidated Atlas Lawsuits are drafting settlement agreements and expect to seek court approval of the settlements.
	We are also a party to various legal, administrative and regulatory proceedings that have arisen in the ordinary course of our business.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information	3 Months Ended
	Mar. 31, 2015
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	Note 17 — Supplemental Cash Flow Information
			Three Months Ended March 31,
			2015		2014
	Cash:
	Interest paid, net of capitalized interest (1)		$	28.9	$	23
	Income taxes paid, net of refunds			0.1		(0.2	)
	Non-cash Investing and Financing balance sheet movements:
	Deadstock commodity inventories transferred to property, plant and equipment			-		1.1
	Accrued distribution equivalent rights on equity awards under share compensation arrangements			-		0.6
	Receivables from equity issuances			24.6		7.1
	Capital expenditure accruals			31		22.7
	Transfers from materials and supplies inventory to property, plant and equipment			0.6		0.4
	Change in ARO liability and property, plant and equipment due to revised future ARO cash flow estimate			3.7		2.1
	___________
	-1	Interest capitalized on major projects was $2.4 million and $6.9 million for three months ended March 31, 2015 and 2014.
	See Note 4 for information on non-cash transaction related to the Atlas mergers.

Segment_Information

Segment Information	3 Months Ended
	Mar. 31, 2015
Segment Information [Abstract]
Segment Information	Note 18 — 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 on reported profits 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 and Southeast New Mexico, South Texas, Oklahoma, Kansas 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 the LPG export market; 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.
	We are reviewing our segment disclosures as a result of the merger and integration efforts related to the Atlas mergers.
	Our reportable segment information is shown in the following tables:
			Three Months Ended March 31, 2015
			Field Gathering and Processing			Coastal Gathering and Processing			Logistics Assets		Marketing and Distribution		Other			Corporate and Eliminations			Total
	Revenues
	Sales of commodities		$	168		$	52.7		$	27.4	$	1,132.30	$	21.7		$	0.1		$	1,402.20
	Fees from midstream services			63.3			8.8			87.7		117.7		-			-			277.5
				231.3			61.5			115.1		1,250.00		21.7			0.1			1,679.70
	Intersegment revenues
	Sales of commodities			215.4			62.8			1.1		78.5		-			(357.8	)		-
	Fees from midstream services			2			-			72.4		4.4		-			(78.8	)		-
				217.4			62.8			73.5		82.9		-			(436.6	)		-
	Revenues		$	448.7		$	124.3		$	188.6	$	1,332.90	$	21.7		$	(436.5	)	$	1,679.70
	Operating margin		$	79.3		$	7.8		$	125.4	$	65.9	$	21.7		$	-		$	300.1
	Other financial information:
	Segment assets before Special GP Interest (1)		$	7,262.80		$	352.9		$	1,764.60	$	487	$	177.3		$	1,786.60		$	11,831.20
	Special GP Interest (2)
	Goodwill			628.5			-			-		-		-			-			628.5
	Intangible assets			979.9			-			-		-		-			-			979.9
	Total assets		$	8,871.20			352.9			1,764.60		487		177.3			1,786.60		$	13,439.60
	Capital expenditures		$	94.4		$	1.1		$	57.7	$	3	$	-		$	1.1		$	157.3
	Business acquisition		$	5,047.80		$	-		$	-	$	-	$	-		$	-		$	5,047.80
	________
	-1	Corporate assets at the Segment level primarily include investment in unconsolidated subsidiaries and debt issuance costs associated with our long-term debt.
	-2	Represents preliminary acquisition fair value attributable to the Special GP Interest attributable to goodwill and intangible assets.
			Three Months Ended March 31, 2014
			Field Gathering and Processing			Coastal Gathering and Processing			Logistics Assets		Marketing and Distribution		Other			Corporate and Eliminations			Total
	Revenues
	Sales of commodities		$	45.8		$	100.5		$	21	$	1,924.00	$	(6.1	)	$	(0.1	)	$	2,085.10
	Fees from midstream services			40.8			7.7			68.1		92.8		-			0.2			209.6
				86.6			108.2			89.1		2,016.80		(6.1	)		0.1			2,294.70
	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	$	2,155.10	$	(6.1	)	$	(783.5	)	$	2,294.70
	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
	The following table shows our consolidated revenues by product and service for the periods presented:
			Three Months Ended March 31,
			2015			2014
	Sales of commodities
	Natural gas		$	302.1		$	391.8
	NGL			1,030.70			1,650.90
	Condensate			21.3			28.4
	Petroleum products			26.4			20.1
	Derivative activities			21.7			(6.1	)
				1,402.20			2,085.10
	Fees from midstream services
	Fractionating and treating			49.8			46.5
	Storage, terminaling, transportation and export			136.2			101.2
	Gathering and processing			68.4			42.6
	Other			23.1			19.3
				277.5			209.6
	Total revenues		$	1,679.70		$	2,294.70
The following table shows a reconciliation of operating margin to net income for the periods presented:
		Three Months Ended March 31,
		2015			2014
Reconciliation of operating margin to net income:
Operating margin		$	300.1		$	275.3
Depreciation and amortization expense			(119.6	)		(79.5	)
General and administrative expense			(40.3	)		(35.9	)
Interest expense, net			(50.9	)		(33.1	)
Other, net			(11.7	)		5.6
Income tax expense			(1.1	)		(1.1	)
Net income		$	76.5		$	131.3

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2015
Significant Accounting Policies [Abstract]
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. We have updated our policies during the three months ended March 31, 2015 to include our accounting policy for goodwill related to the Atlas mergers.
Goodwill and Intangible Assets	Goodwill results when the cost of an acquisition exceeds the fair value of the net identifiable assets of the acquired business. Goodwill is not amortized, but is assessed annually to determine whether its carrying value has been impaired.
	Impairment testing for goodwill is performed at the reporting unit level. A reporting unit is an operating segment or one level below an operating segment (also known as a component). A component of an operating segment is a reporting unit if the component constitutes a business for which discrete financial information is available, and segment management regularly reviews the operating results of that component.
	We evaluate goodwill for impairment at least annually, as of November 30th for all affected reporting units. We also evaluate goodwill for impairment whenever events or changes in circumstances indicate it is more likely than not the fair value of a reporting unit is less than its carrying amount. We may first assess qualitative factors to evaluate whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount (including assigned goodwill) as the basis for determining whether it is necessary to perform the two-step goodwill impairment test. If a two-step process goodwill impairment test is required, the first step involves comparing the fair value of the reporting unit to which goodwill has been allocated with its carrying amount. If the carrying amount of a reporting unit exceeds its fair value, the second step of the process involves comparing the implied fair value to the carrying value of the goodwill for that reporting unit. If the carrying value of the goodwill of a reporting unit exceeds the implied fair value of that goodwill, the excess of the carrying value over the implied fair value is recognized as a reduction of goodwill on our Consolidated Balance Sheets and a goodwill impairment loss on our Consolidated Statements of Operations.
Recent Accounting Pronouncements	Recent Accounting Pronouncements
	In February 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standard Update (“ASU”) No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis. The amendments are intended to simplify the consolidation evaluation for reporting organizations that are required to evaluate whether they should consolidate certain legal entities and modify the evaluation of whether limited partnerships and similar legal entities are variable interest entities or voting interest entities. The amendments are effective for us in 2016, with early adoption permitted. We are currently evaluating the effect of the amendments on our consolidated financial statements and related disclosures.
	In April 2015, the FASB issued ASU 2015-03, Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. The amendments in this update require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this update. The amendments are effective for us in 2016, with early adoption permitted. We anticipate adopting the amendments on January 1, 2016. Unamortized debt issuance costs of $46.4 million were included in Other long-term assets on the Consolidated Balance Sheets as of March 31, 2015.

Business_Acquisitions_Tables

Business Acquisitions (Tables)	3 Months Ended
	Mar. 31, 2015
Business Acquisitions [Abstract]
Pro Forma Consolidated Results of Operations	The following summarized unaudited pro forma consolidated statement of operations information for the three months ended March 31, 2015 and March 31, 2014 assumes that our acquisition of APL and Targa’s acquisition of ATLS had occurred as of January 1, 2014. We prepared the following summarized unaudited pro forma financial results for comparative purposes only. The summarized unaudited pro forma financial results may not be indicative of the results that would have occurred if we had completed the APL merger as of January 1, 2014, or that the results that will be attained in the future. Amounts presented below are in millions, except for the per unit amounts:
			31-Mar-15			31-Mar-14
			Pro forma			Pro forma
	Revenues		$	1,994.00		$	2,944.40
	Net income			71.7			129.2
Consideration Transferred to Acquire ATLS and APL	The following table summarizes the consideration transferred to acquire ATLS and APL, which are viewed together as a single integrated transaction for GAAP reporting purposes:
	Fair Value of Consideration Transferred by Targa for ATLS:
	Cash, net of cash acquired (1)		$	745.7
	Common shares of TRC			1,008.50
	Replacement restricted stock units awarded (3)			5.2
	Less: value of  APL common units owned by ATLS			(147.4	)
	Total		$	1,612.00
	Fair Value of Consideration Transferred for APL:
	Cash, net of cash acquired (2)		$	852.3
	Common units of TRP			2,568.50
	Replacement phantom units awarded (3)			15
	Total		$	3,435.80
	Total fair value of consideration transferred		$	5,047.80
	___________
	-1	Targa acquired $5.5 million of cash. Targa also received $7.3 million in April 2015 as part of the Atlas mergers, representing the one-time cash payment from us for the APL common units owned by ATLS.
	-2	We acquired $11.7 million of cash.
	-3	The fair value of consideration transferred in the form of replacement restricted stock unit awards and replacement phantom unit awards represent the allocation of the fair value of the awards to the pre-combination service period. The fair value of the awards associated with the post-combination service period will be recognized over the remaining service period of the award.
Preliminary Fair Value Determination Related to the Atlas Mergers	As of February 27, 2015, our preliminary fair value determination related to the Atlas mergers was as follows. The excess of the purchase price over the estimated fair value of net assets acquired was approximately $628.5 million, which was recorded as goodwill. This determination is based on our preliminary valuation and is subject to revisions pending the completion of valuation and other adjustments.
	Preliminary fair value determination:		27-Feb-15
	Trade and other current receivables, net		$	183.9
	Other current assets			26.5
	Assets from risk management activities			102.1
	Property, plant and equipment			4,944.00
	Investments in unconsolidated affiliates			273.7
	Intangible assets			1,035.00
	Other long-term assets			6.6
	Current liabilities, less current portion of long-term debt			(233.5	)
	Long-term debt			(1,573.8	)
	Deferred income tax liabilities, net			(30.2	)
	Other long-term liabilities			(10.7	)
	Noncontrolling interest in subsidiaries			(303.9	)
	Total identifiable net assets		$	4,419.70
	Current liabilities retained by Targa		$	(0.4	)
	Goodwill		$	628.5

Inventories_Tables

Inventories (Tables)	3 Months Ended
	Mar. 31, 2015
Inventories [Abstract]
Components of Inventories		31-Mar-15		31-Dec-14
	Commodities	$	66.9	$	157.4
	Materials and supplies		11.3		11.5
		$	78.2	$	168.9

Property_Plant_and_Equipment_a1

Property, Plant and Equipment and Intangible Assets (Tables)	3 Months Ended
	Mar. 31, 2015
Property, Plant and Equipment and Intangible Assets [Abstract]
Property, Plant and Equipment and Intangible Assets		31-Mar-15			31-Dec-14			Estimated useful life
								(In years)
	Gathering systems	$	6,113.80		$	2,588.60		5 to 40
	Processing and fractionation facilities		2,924.60			1,884.10		5 to 40
	Terminaling and storage facilities		1,043.00			1,038.90		5 to 25
	Transportation assets		432.9			359		10 to 25
	Other property, plant and equipment		219.9			149.1		3 to 40
	Land		101.4			95.6		-
	Construction in progress		782.2			399		-
	Property, plant and equipment		11,617.80			6,514.30
	Accumulated depreciation		(1,784.9	)		(1,689.7	)
	Property, plant and equipment, net	$	9,832.90		$	4,824.60
	Intangible assets	$	1,716.60		$	681.8		20
	Accumulated amortization		(114.2	)		(89.9	)
	Intangible assets, net	$	1,602.40		$	591.9

Investments_in_Unconsolidated_1

Investments in Unconsolidated Affiliates (Tables)	3 Months Ended
	Mar. 31, 2015
Investments in Unconsolidated Affiliates [Abstract]
Activity Related to Investment in Unconsolidated Affiliate	The following table shows the activity related to our investments in unconsolidated affiliates:
			Three Months Ended March 31, 2015
	Beginning of period		$	50.2
	Preliminary fair value of T2 Joint Ventures acquired (1)			273.7
	Equity earnings			1.7
	Cash distributions (2)			(2.7	)
	End of period		$	322.9
	___________
	-1	Includes equity earnings of acquired investments since the date of acquisition of February 27, 2015.
	-2	Includes $0.6 million distributions received in excess of our share of cumulative earnings for the three months ended March 31, 2015. Such excess distributions are considered a return of capital and are 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, 2015
Accounts Payable and Accrued Liabilities [Abstract]
Schedule of Accounts Payable and Accrued Liabilities		31-Mar-15		31-Dec-14
	Commodities	$	445.8	$	416.7
	Other goods and services		169.8		108.9
	Interest		57		37.3
	Compensation and benefits		3.2		1.3
	Income and other taxes		20		13.6
	Other		15		14.9
		$	710.8	$	592.7

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligations [Abstract]
Changes in Aggregate Asset Retirement Obligations	The changes in our aggregate asset retirement obligations are as follows:
		Three Months Ended March 31, 2015
	Beginning of period	$	56.8
	Preliminary fair value of ARO acquired with the APL merger		4.1
	Change in cash flow estimate		3.7
	Accretion expense		1.3
	End of period	$	65.9

Debt_Obligations_Tables

Debt Obligations (Tables)	3 Months Ended
	Mar. 31, 2015
Debt Obligations [Abstract]
Schedule of Outstanding Debt			31-Mar-15			31-Dec-14
	Current:
	Accounts receivable securitization facility, due December 2015		$	197.9		$	182.8
	Long-term:
	Senior secured revolving credit facility, variable rate, due October 2017 (1)			840			-
	Senior unsecured notes, 5% fixed rate, due January 2018			1,100.00			-
	Senior unsecured notes, 6⅞% fixed rate, due February 2021			483.6			483.6
	Unamortized discount			(24.5	)		(25.2	)
	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
	Senior unsecured notes, 4⅛% fixed rate, due November 2019			800			800
	Senior unsecured notes, 6⅝% fixed rate, due October 2020 (2)			355.1			-
	Unamortized premium			6			-
	Senior unsecured notes, 4¾% fixed rate, due November 2021 (2)			6.5			-
	Senior unsecured notes, 5⅞% fixed rate, due August 2023 (2)			48.1			-
	Unamortized premium			0.6			-
	Total long-term debt			5,140.40			2,783.40
	Total Debt		$	5,338.30		$	2,966.20
	Letters of credit outstanding		$	25		$	44.1
	________
	-1	As of March 31, 2015, availability under our $1.6 billion senior secured revolving credit facility was $735.0 million.
	-2	Senior unsecured notes issued by APL entities and acquired in the Atlas mergers.
Interest Rates Incurred on Variable-Rate Debt Obligations	The following table shows the range of interest rates and weighted average interest rate incurred on our variable-rate debt obligations during the three months ended March 31, 2015:
		Range of Interest Rates Incurred		Weighted Average Interest Rate Incurred
	Senior secured revolving credit facility	1.90%		1.90%
	Accounts receivable securitization facility	0.90%		0.90%
Summary of Results of Tender Offers	The results of the APL Note Tender Offers were:
	Senior Notes		Outstanding Note Balance			Amount Tendered			Premium Paid		Accrued Interest Paid		Total Tender Offer payments		% Tendered			Note Balance after Tender Offers
			($ amounts in millions)
	6⅝% due 2020		$	500		$	140.1		$	2.1	$	3.7	$	145.9		28.02	%	$	359.9
	4¾% due 2021			400			393.5			5.9		5.3		404.7		98.38	%		6.5
	5⅞% due 2023			650			601.9			8.7		2.6		613.2		92.6	%		48.1
	Total		$	1,550.00		$	1,135.50		$	16.7	$	11.6	$	1,163.80				$	414.5

Partnership_Units_and_Related_1

Partnership Units and Related Matters (Tables)	3 Months Ended
	Mar. 31, 2015
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, 2015.
				Distributions
	Three Months Ended		Date Paid or to be Paid	Limited Partners		General Partner							Distributions per Limited Partner Unit
				Common			Incentive Distribution Rights		2%		Total
				(In millions, except per unit amounts)
	31-Mar-15		15-May-15	$	148.3		$	41.7	$	3.9	$	193.9	$	0.82
	31-Dec-14		13-Feb-15	$	96.3		$	38.4	$	2.7	$	137.4	$	0.81
	____________
	-1	Pursuant to the IDR Giveback Amendment in conjunction with the Atlas mergers, IDR’s of $9.375 million were allocated to common unitholders in the first quarter of 2015. The IDR Giveback Amendment covers sixteen quarterly distribution declarations following the February 27, 2015 Atlas mergers and will result in reallocation of IDR payments to common unitholders at the following amounts - $9.375 million per quarter for 2015, $6.25 million per quarter for 2016, $2.5 million per quarter for 2017 and $1.25 million per quarter for 2018.

Earnings_per_Limited_Partner_U1

Earnings per Limited Partner Unit (Tables)	3 Months Ended
	Mar. 31, 2015
Earnings per Limited Partner Unit [Abstract]
Computation of Basic and Diluted Net Income per Limited Partner	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 unit:
		Three Months Ended March 31,
		2015		2014
	Net income	$	76.5	$	131.3
	Less: Net income attributable to noncontrolling interests		4.9		8.9
	Net income attributable to Targa Resources Partners LP	$	71.6	$	122.4
	Net income attributable to general partner	$	42.5	$	33.8
	Net income attributable to limited partners		29.1		88.6
	Net income attributable to Targa Resources Partners LP	$	71.6	$	122.4
	Weighted average units outstanding - basic		137.1		112.4
	Net income available per limited partner unit - basic	$	0.21	$	0.79
	Weighted average units outstanding		137.1		112.4
	Dilutive effect of unvested stock awards		0.4		0.6
	Weighted average units outstanding - diluted		137.5		113
	Net income available per limited partner unit - diluted	$	0.21	$	0.78

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities [Abstract]
Notional Volume of Commodity Hedges	At March 31, 2015, the notional volumes of our commodity hedges were:
	Commodity		Instrument		Unit			2015		2016		2017
	Natural Gas		Swaps		MMBtu/d			125,439		68,205		23,082
	Natural Gas		Basis Swaps		MMBtu/d			23,782		-		-
	NGL		Swaps		Bbl/d			5,928		2,254		658
	NGL		Options		Bbl/d			899		790		790
	Condensate		Swaps		Bbl/d			1,991		1,082		500
	Condensate		Options		Bbl/d			1,198		380		380
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, 2015								Fair Value as of December 31, 2014
			Balance Sheet		Derivative				Derivative				Derivative				Derivative
			Location		Assets				Liabilities				Assets				Liabilities
	Derivatives designated as hedging instruments
	Commodity contracts		Current		$	117.8			$	0.4			$	44.4			$	-
			Long-term			51.2				1.8				15.8				-
	Total derivatives designated as hedging instruments				$	169			$	2.2			$	60.2			$	-
	Derivatives not designated as hedging instruments
	Commodity contracts		Current		$	8.2			$	0.2			$	-			$	5.2
	Total derivatives not designated as hedging instruments				$	8.2			$	0.2			$	-			$	5.2
	Total current position				$	126			$	0.6			$	44.4			$	5.2
	Total long-term position					51.2				1.8				15.8				-
	Total derivatives				$	177.2			$	2.4			$	60.2			$	5.2
Pro Forma Impact of Derivatives Net in Consolidated Balance Sheet	The pro forma impact of reporting derivatives in the Consolidated Balance Sheets on a net basis is as follows:
			Gross Presentation								Pro forma Net Presentation
			Asset				Liability				Asset				Liability
	31-Mar-15		Position				Position				Position				Position
	Current position
	Counterparties with offsetting position		$	54			$	0.6			$	53.4			$	-
	Counterparties without offsetting position - assets			72				-				72				-
	Counterparties without offsetting position - liabilities			-				-				-				-
				126				0.6				125.4				-
	Long-term position
	Counterparties with offsetting position			19.4				1.8				17.6				-
	Counterparties without offsetting position - assets			31.8				-				31.8				-
	Counterparties without offsetting position - liabilities			-				-				-				-
				51.2				1.8				49.4				-
	Total derivatives
	Counterparties with offsetting position			73.4				2.4				71				-
	Counterparties without offsetting position - assets			103.8				-				103.8				-
	Counterparties without offsetting position - liabilities			-				-				-				-
			$	177.2			$	2.4			$	174.8			$	-
	31-Dec-14
	Current position
	Counterparties with offsetting position		$	35.5			$	4.4			$	31.1			$	-
	Counterparties without offsetting position - assets			8.9				-				8.9				-
	Counterparties without offsetting position - liabilities			-				0.8				-				0.8
				44.4				5.2				40				0.8
	Long-term position
	Counterparties with offsetting position			-				-				-				-
	Counterparties without offsetting position - assets			15.8				-				15.8				-
	Counterparties without offsetting position - liabilities			-				-				-				-
				15.8				-				15.8				-
	Total derivatives
	Counterparties with offsetting position			35.5				4.4				31.1				-
	Counterparties without offsetting position - assets			24.7				-				24.7				-
	Counterparties without offsetting position - liabilities			-				0.8				-				0.8
			$	60.2			$	5.2			$	55.8			$	0.8
Amounts Recorded in OCI and Amounts Reclassified from OCI to Revenue and Expense	The following tables reflect amounts recorded in Other Comprehensive Income (“OCI”) and amounts reclassified from OCI to revenue and expense for the periods indicated:
			Gain (Loss) Recognized in OCI on Derivatives
			(Effective Portion)
	Derivatives in Cash Flow Hedging Relationships		Three Months Ended March 31,
			2015				2014
	Commodity contracts		$	25.2			$	(11.9	)
			Gain (Loss) Reclassified from OCI into Income
			(Effective Portion)
	Location of Gain (Loss)		Three Months Ended March 31,
			2015				2014
	Interest expense, net		$	-			$	(1.3	)
	Revenues			8.1				(6.3	)
			$	8.1			$	(7.6	)
Gain (Loss) Recognized in Income on Derivatives	The changes in fair value of these instruments are recorded on the balance sheet and through earnings 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 in Income on Derivatives
	Derivatives Not Designated as Hedging Instruments		Location of Gain Recognized in Income on Derivatives		31-Mar-15				31-Mar-14
	Commodity contracts		Revenue		$	7.2			$	(0.2	)
Deferred Gains (Losses) Included in Accumulated OCI	The following table shows the deferred gains (losses) included in accumulated OCI, which will be reclassified into earnings through the end of 2017 based on year-end valuations.
			31-Mar-15				31-Dec-14
	Commodity hedges (1)		$	77.4			$	60.3
	___________
	-1	Includes deferred net gains of $53.3 million as of March 31, 2015 related to contracts that will be settled and reclassified to revenue over the next 12 months.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2015
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-15
			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)		$	177.2		$	177.2	$	-	$	172.9	$	4.3
	Liabilities from commodity derivative contracts (1)			2.4			2.4		-		1.6		0.8
	Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
	Cash and cash equivalents			63.5			63.5		-		-		-
	Senior secured revolving credit facility			840			840		-		840		-
	Senior unsecured notes			4,300.40			4,384.90		-		4,384.90		-
	Accounts receivable securitization facility			197.9			197.9		197.9		-		-
	______________
	-1	The fair value of our derivative contracts in this table is presented on a different basis than the Consolidated Balance Sheets presentation as disclosed in Note 13. The above fair values reflect the total value of each derivative contract taken as a whole, whereas the Consolidated Balance Sheets 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 Consolidated Balance Sheets 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, 2014			(1.7	)
	Settlements included in Revenue			-
	Unrealized gains included in OCI			(1.1	)
	Transfers into Level 3			(0.6	)
	Transfers out of Level 3			(0.1	)
	Balance, March 31, 2015		$	(3.5	)

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2015
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,
		2015		2014
	Targa billings of payroll and related costs included in operating expense	$	34.9	$	29.9
	Targa allocation of general and administrative expense		38.3		33.4
	Cash distributions to Targa based on unit ownership		51.6		41.5
			53.6		2.4
	Cash contributions from Targa to maintain its 2% general partner ownership

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 2015
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information			Three Months Ended March 31,
			2015		2014
	Cash:
	Interest paid, net of capitalized interest (1)		$	28.9	$	23
	Income taxes paid, net of refunds			0.1		(0.2	)
	Non-cash Investing and Financing balance sheet movements:
	Deadstock commodity inventories transferred to property, plant and equipment			-		1.1
	Accrued distribution equivalent rights on equity awards under share compensation arrangements			-		0.6
	Receivables from equity issuances			24.6		7.1
	Capital expenditure accruals			31		22.7
	Transfers from materials and supplies inventory to property, plant and equipment			0.6		0.4
	Change in ARO liability and property, plant and equipment due to revised future ARO cash flow estimate			3.7		2.1
	___________
	-1	Interest capitalized on major projects was $2.4 million and $6.9 million for three months ended March 31, 2015 and 2014.

Segment_Information_Tables

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2015
Segment Information [Abstract]
Information by Segment	Our reportable segment information is shown in the following tables:
			Three Months Ended March 31, 2015
			Field Gathering and Processing			Coastal Gathering and Processing			Logistics Assets		Marketing and Distribution		Other			Corporate and Eliminations			Total
	Revenues
	Sales of commodities		$	168		$	52.7		$	27.4	$	1,132.30	$	21.7		$	0.1		$	1,402.20
	Fees from midstream services			63.3			8.8			87.7		117.7		-			-			277.5
				231.3			61.5			115.1		1,250.00		21.7			0.1			1,679.70
	Intersegment revenues
	Sales of commodities			215.4			62.8			1.1		78.5		-			(357.8	)		-
	Fees from midstream services			2			-			72.4		4.4		-			(78.8	)		-
				217.4			62.8			73.5		82.9		-			(436.6	)		-
	Revenues		$	448.7		$	124.3		$	188.6	$	1,332.90	$	21.7		$	(436.5	)	$	1,679.70
	Operating margin		$	79.3		$	7.8		$	125.4	$	65.9	$	21.7		$	-		$	300.1
	Other financial information:
	Segment assets before Special GP Interest (1)		$	7,262.80		$	352.9		$	1,764.60	$	487	$	177.3		$	1,786.60		$	11,831.20
	Special GP Interest (2)
	Goodwill			628.5			-			-		-		-			-			628.5
	Intangible assets			979.9			-			-		-		-			-			979.9
	Total assets		$	8,871.20			352.9			1,764.60		487		177.3			1,786.60		$	13,439.60
	Capital expenditures		$	94.4		$	1.1		$	57.7	$	3	$	-		$	1.1		$	157.3
	Business acquisition		$	5,047.80		$	-		$	-	$	-	$	-		$	-		$	5,047.80
	________
	-1	Corporate assets at the Segment level primarily include investment in unconsolidated subsidiaries and debt issuance costs associated with our long-term debt.
	-2	Represents preliminary acquisition fair value attributable to the Special GP Interest attributable to goodwill and intangible assets.
			Three Months Ended March 31, 2014
			Field Gathering and Processing			Coastal Gathering and Processing			Logistics Assets		Marketing and Distribution		Other			Corporate and Eliminations			Total
	Revenues
	Sales of commodities		$	45.8		$	100.5		$	21	$	1,924.00	$	(6.1	)	$	(0.1	)	$	2,085.10
	Fees from midstream services			40.8			7.7			68.1		92.8		-			0.2			209.6
				86.6			108.2			89.1		2,016.80		(6.1	)		0.1			2,294.70
	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	$	2,155.10	$	(6.1	)	$	(783.5	)	$	2,294.70
	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
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,
			2015			2014
	Sales of commodities
	Natural gas		$	302.1		$	391.8
	NGL			1,030.70			1,650.90
	Condensate			21.3			28.4
	Petroleum products			26.4			20.1
	Derivative activities			21.7			(6.1	)
				1,402.20			2,085.10
	Fees from midstream services
	Fractionating and treating			49.8			46.5
	Storage, terminaling, transportation and export			136.2			101.2
	Gathering and processing			68.4			42.6
	Other			23.1			19.3
				277.5			209.6
	Total revenues		$	1,679.70		$	2,294.70
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,
			2015			2014
	Reconciliation of operating margin to net income:
	Operating margin		$	300.1		$	275.3
	Depreciation and amortization expense			(119.6	)		(79.5	)
	General and administrative expense			(40.3	)		(35.9	)
	Interest expense, net			(50.9	)		(33.1	)
	Other, net			(11.7	)		5.6
	Income tax expense			(1.1	)		(1.1	)
	Net income		$	76.5		$	131.3

Organization_and_Operations_De

Organization and Operations (Details)	3 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Organization and Operations [Abstract]
General partner interest (in hundredths)	2.00%
Ownership interest by related party and parents (in hundredths)	11.00%
General partner units outstanding (in units)	3,642,543	2,420,124
Common units held by related party (in units)	16,309,594
Increasing cash distributions as percentage of distributable cash for a quarter (in hundredths)	48.00%

Basis_of_Presentation_Details

Basis of Presentation (Details) (USD $)	0 Months Ended
In Billions, unless otherwise specified	Feb. 27, 2015	Feb. 27, 2015
		Transaction
Business Acquisition [Line Items]
Number of separate legal transactions involved in mergers	2	2
Atlas Energy [Member]
Business Acquisition [Line Items]
Number of separate legal transactions involved in mergers	2	2
Total general partner interest acquired	$1.60
Atlas Pipeline Partners [Member]
Business Acquisition [Line Items]
Total general partner interest acquired	$5.30

Significant_Accounting_Policie2

Significant Accounting Policies (Details) (USD $)	Mar. 31, 2015
In Millions, unless otherwise specified
Significant Accounting Policies [Abstract]
Unamortized debt issuance costs	$46.40

Business_Acquisitions_Details

Business Acquisitions (Details) (USD $)	0 Months Ended		1 Months Ended		3 Months Ended			1 Months Ended
	Feb. 27, 2015		Mar. 31, 2015		Mar. 31, 2015		Mar. 31, 2014	Apr. 30, 2015	Dec. 31, 2014	Feb. 28, 2015
Business Acquisition [Line Items]
Cash payments related to acquisition					$5,047,800,000
Percentage of general partner's interest maintained (in hundredths)					2.00%
Acquisition-related expenses					13,700,000
Number of separate legal transactions involved in mergers	2
Revenues from acquired business			160,600,000
Net income from acquired business			4,100,000
Pro forma consolidated results of operations [Abstract]
Revenues					1,994,000,000		2,944,400,000
Net income					71,700,000		129,200,000
Fair Value of Consideration Transferred: [Abstract]
Cash paid, net of cash acquired					852,300,000		0
Total	5,047,800,000
Preliminary fair value determination: [Abstract]
Trade and other current receivables, net	183,900,000
Other current assets	26,500,000
Assets from risk management activities	102,100,000
Property, plant and equipment	4,944,000,000
Investments in unconsolidated affiliates	273,700,000
Intangible assets	1,035,000,000		1,035,000,000		1,035,000,000
Other long-term assets	6,600,000
Current liabilities, less current portion of long-term debt	-233,500,000
Long-term debt	-1,573,800,000
Deferred income tax liabilities, net	-30,200,000
Other long-term liabilities	-10,700,000
Noncontrolling interest in subsidiaries	-303,900,000
Total identifiable net assets	4,419,700,000
Current liabilities retained by Targa	-400,000
Goodwill	628,500,000		628,500,000	[1]	628,500,000	[1]			0
Trade receivables, gross amount	180,900,000
Contractual receivables included in current receivables	3,000,000
Contractual receivables included in other long term assets	4,500,000
Phantom Units Awards [Member]
Preliminary fair value determination: [Abstract]
Number of common units called by replacement equity unit (in shares)			1		1
Dividend payment period					60 days
Phantom Units Awards [Member] | Vesting Term One [Member]
Preliminary fair value determination: [Abstract]
Vesting percentage original term (in hundredths)					25.00%
Vesting period of original term					4 years
Phantom Units Awards [Member] | Vesting Term Two [Member]
Preliminary fair value determination: [Abstract]
Vesting percentage original term (in hundredths)					33.00%
Vesting period of original term					3 years
Atlas Pipeline Partners [Member]
Business Acquisition [Line Items]
Purchase consideration	5,300,000,000
Debt and all other assumed liabilities included purchase consideration	1,800,000,000
Payments for notes tendered and settled upon closing of merger	1,200,000,000
Number of successive quarters, annual distribution is paid					4
Processing capacity (in MMcf/D)					1,439
Length of pipelines (in miles)					10,500
Distribution of common units/shares for each common unit (in shares)	0.5846
Cash payment (in dollars per common unit)	$1.26
Total distribution of common shares (in shares)	58,614,157
Common units acquired	2,600,000,000
Closing market price of common unit (in dollars per share)	$43.82
Cash payment related to change of control payments	28,800,000									28,800,000
Cash paid in lieu of unit issuances	6,400,000
Contribution made by Targa to general partner's interest					52,400,000
Percentage of general partner's interest maintained (in hundredths)					2.00%
Fair Value of Consideration Transferred: [Abstract]
Cash paid, net of cash acquired	852,300,000	[2]
Less: value of APL common units owned by ATLS	2,600,000,000
Total	3,435,800,000
Preliminary fair value determination: [Abstract]
Contingent consideration additional amount					6,000,000
Contingent liability acquired in business combination	6,000,000
Contingent consideration liability lower range			0		0
Contingent consideration liability higher range			6,000,000		6,000,000
Atlas Pipeline Partners [Member] | Class E Preferred Units [Member]
Business Acquisition [Line Items]
Percentage of cumulative redeemable perpetual preferred units (in hundredths)					8.25%
Atlas Pipeline Partners [Member] | Common Unit Holders [Member]
Business Acquisition [Line Items]
Cash payments related to acquisition	128,000,000
Total distribution of common shares (in shares)	58,614,157
Atlas Pipeline Partners [Member] | Atlas Energy [Member]
Business Acquisition [Line Items]
Total distribution of common shares (in shares)	3,363,935
Atlas Pipeline Partners [Member] | Phantom Units Awards [Member]
Business Acquisition [Line Items]
Cash payment representing accelerated vesting of a portion of employees APL phantom awards	600,000
Total distribution of common shares (in shares)	629,231
Fair Value of Consideration Transferred: [Abstract]
Common shares	15,000,000	[3]
Atlas Pipeline Partners [Member] | Common Units [Member]
Fair Value of Consideration Transferred: [Abstract]
Cash acquired from acquisition	11,700,000
Atlas Pipeline Partners [Member] | Common Units [Member] | Atlas Energy [Member]
Business Acquisition [Line Items]
Common units owned by parent prior to closing (in units)	5,754,253
Atlas Pipeline Partners [Member] | Common Units [Member] | Targa Resources Corp [Member]
Business Acquisition [Line Items]
Total distribution of common shares (in shares)	3,363,935
Atlas Pipeline Partners [Member] | Common Units [Member] | Targa Resources Corp [Member] | Common Unit Holders [Member] | Subsequent Event [Member]
Business Acquisition [Line Items]
Cash payments related to acquisition								7,300,000
Atlas Pipeline Partners [Member] | Common Stock [Member]
Fair Value of Consideration Transferred: [Abstract]
Common shares	2,568,500,000
Atlas Pipeline Partners [Member] | Common Stock [Member] | Targa Resources Corp [Member]
Business Acquisition [Line Items]
Common units acquired	-147,400,000
Fair Value of Consideration Transferred: [Abstract]
Less: value of APL common units owned by ATLS	-147,400,000
Atlas Pipeline Partners [Member] | Revolving Credit Facility [Member]
Business Acquisition [Line Items]
Cash payments related to acquisition	701,400,000
Atlas Pipeline Partners [Member] | Distribution Rights Year 1 [Member]
Business Acquisition [Line Items]
Reduction in incentive distribution					9,375,000
Atlas Pipeline Partners [Member] | Distribution Rights Year 2 [Member]
Business Acquisition [Line Items]
Reduction in incentive distribution					6,250,000
Atlas Pipeline Partners [Member] | Distribution Rights Year 3 [Member]
Business Acquisition [Line Items]
Reduction in incentive distribution					2,500,000
Atlas Pipeline Partners [Member] | Distribution Rights Year 4 [Member]
Business Acquisition [Line Items]
Reduction in incentive distribution					1,250,000
Atlas Energy [Member]
Business Acquisition [Line Items]
Purchase consideration	1,600,000,000
Number of separate legal transactions involved in mergers	2
Atlas Energy [Member] | Targa Resources Corp [Member]
Business Acquisition [Line Items]
Percentage of interest in common units (in hundredths)	100.00%
Distribution of common units/shares for each common unit (in shares)	0.1809
Cash payment (in dollars per common unit)	$9.12
Cash payments related to acquisition	514,700,000
Common units acquired	1,000,000,000
Closing market price of common unit (in dollars per share)	$99.58
Common units par value (in dollars per share)	$0.00
Cash payment related to change of control payments and settlement of equity awards	149,200,000
Cash payment for repayment of ATLS outstanding indebtedness	88,000,000
Acquisition-related expenses	11,000,000
Reduction in purchase price	-154,700,000
Preliminary fair value of intangible assets	984,200,000
Other assets and liabilities, net acquired	5,000,000
Fair Value of Consideration Transferred: [Abstract]
Cash paid, net of cash acquired	745,700,000	[4]
Less: value of APL common units owned by ATLS	1,000,000,000
Total	1,612,000,000
Cash acquired from acquisition	5,500,000
Atlas Energy [Member] | Restricted Stock Units (RSUs) [Member] | Targa Resources Corp [Member]
Fair Value of Consideration Transferred: [Abstract]
Common shares	5,200,000	[3]
Atlas Energy [Member] | Phantom Units Awards [Member]
Business Acquisition [Line Items]
Cash payment representing accelerated vesting of a portion of employees APL phantom awards	4,500,000
Cash payment related to one-time cash payments and cash settlements of equity awards	4,500,000
Atlas Energy [Member] | Phantom Units Awards [Member] | Targa Resources Corp [Member]
Business Acquisition [Line Items]
Total distribution of common shares (in shares)	81,740
Atlas Energy [Member] | Common Units [Member] | Targa Resources Corp [Member]
Business Acquisition [Line Items]
Total distribution of common shares (in shares)	10,126,532
Common units acquired	147,400,000
Fair Value of Consideration Transferred: [Abstract]
Less: value of APL common units owned by ATLS	147,400,000
Atlas Energy [Member] | Common Stock [Member] | Targa Resources Corp [Member]
Fair Value of Consideration Transferred: [Abstract]
Common shares	$1,008,500,000
West Texas LPG Pipeline Limited Partnership [Member]
Preliminary fair value determination: [Abstract]
Percentage of equity interest sold (in hundredths)					20.00%
Atlas Resource Partners, LP [Member]
Preliminary fair value determination: [Abstract]
Percentage of equity interest sold (in hundredths)					100.00%
[1]	Represents preliminary acquisition fair value attributable to the Special GP Interest attributable to goodwill and intangible assets.
[2]	We acquired $11.7 million of cash.
[3]	The fair value of consideration transferred in the form of replacement restricted stock unit awards and replacement phantom unit awards represent the allocation of the fair value of the awards to the pre-combination service period. The fair value of the awards associated with the post-combination service period will be recognized over the remaining service period of the award.
[4]	Targa acquired $5.5 million of cash. Targa also received $7.3 million as part of the Atlas mergers, representing the one-time cash payment from us for the APL common units owned by ATLS.

Inventories_Details

Inventories (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Components of inventory [Abstract]
Commodities	$66.90	$157.40
Materials and supplies	11.3	11.5
Total inventory	$78.20	$168.90

Property_Plant_and_Equipment_a2

Property, Plant and Equipment and Intangible Assets (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Feb. 27, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$11,617.80		$6,514.30
Accumulated depreciation	-1,784.90		-1,689.70
Property, plant and equipment, net	9,832.90		4,824.60
Finite-lived intangible assets, net [Abstract]
Intangible assets	1,716.60		681.8
Accumulated amortization	-114.2		-89.9
Intangible assets, net	1,602.40		591.9
Estimated useful life (In years)	20 years
Provisional value of intangible assets acquired	1,035	1,035
Amortization period of acquired intangible assets used for preparing financial statements	1 month
Estimated annual amortization expense for intangible assets [Abstract]
2015	123.2
2016	140.1
2017	133.3
2018	119.5
2019	108.6
Gathering systems [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	6,113.80		2,588.60
Processing and fractionation facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,924.60		1,884.10
Terminaling and storage facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,043		1,038.90
Transportation assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	432.9		359
Other property, plant and equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	219.9		149.1
Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	101.4		95.6
Construction in progress [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$782.20		$399
Minimum [Member] | Gathering systems [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives (In years)	5 years
Minimum [Member] | Processing and fractionation facilities [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives (In years)	5 years
Minimum [Member] | Terminaling and storage facilities [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives (In years)	5 years
Minimum [Member] | Transportation assets [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives (In years)	10 years
Minimum [Member] | Other property, plant and equipment [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives (In years)	3 years
Maximum [Member] | Gathering systems [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives (In years)	40 years
Maximum [Member] | Processing and fractionation facilities [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives (In years)	40 years
Maximum [Member] | Terminaling and storage facilities [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives (In years)	25 years
Maximum [Member] | Transportation assets [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives (In years)	25 years
Maximum [Member] | Other property, plant and equipment [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives (In years)	40 years

Investments_in_Unconsolidated_2

Investments in Unconsolidated Affiliates (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014	Dec. 31, 2014
	JointVenture
Schedule of Equity Method Investments [Line Items]
Number of non-operated joint ventures	3
Return of capital from unconsolidated affiliate	$0.60		$2.20
Beginning of period	50.2
Preliminary fair value of T2 Joint Ventures acquired	273.7	[1]
Equity earnings	1.7		4.9
Cash distributions	-2.7	[2]
End of period	322.9
Basis difference on preliminary fair values	$99.10
Preliminary estimated useful lives of the underlying assets	20 years
Gulf Coast Fractionators LP. [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest (in hundredths)	38.80%			38.80%
T2 La Salle [Member]
Schedule of Equity Method Investments [Line Items]
Percentage of equity interest (in hundredths)	75.00%
T2 Eagle Ford [Member]
Schedule of Equity Method Investments [Line Items]
Percentage of equity interest (in hundredths)	50.00%
T2 EF Co-Gen [Member]
Schedule of Equity Method Investments [Line Items]
Percentage of equity interest (in hundredths)	50.00%
[1]	Includes equity earnings of acquired investments since the date of acquisition of February 27, 2015.
[2]	Includes $0.6 million distributions received in excess of our share of cumulative earnings for the three months ended March 31, 2015. Such excess distributions are considered a return of capital and are 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, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Accounts Payable and Accrued Liabilities [Abstract]
Commodities	$445.80	$416.70
Other goods and services	169.8	108.9
Interest	57	37.3
Compensation and benefits	3.2	1.3
Income and other taxes	20	13.6
Other	15	14.9
Total accounts payable and accrued liabilities	$710.80	$592.70

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Changes in aggregate asset retirement obligations [Roll Forward]
Beginning of period	$56.80
Preliminary fair value of ARO acquired with the APL merger	4.1
Change in cash flow estimate	3.7	2.1
Accretion expense	1.3	1.2
End of period	$65.90

Debt_Obligations_Details

Debt Obligations (Details) (USD $)	3 Months Ended			0 Months Ended	1 Months Ended		0 Months Ended
	Mar. 31, 2015		Mar. 31, 2014	Feb. 27, 2015	Apr. 30, 2015	Jan. 31, 2015	Feb. 28, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Long-term debt	$5,140,400,000							$2,783,400,000
Total Debt	5,338,300,000							2,966,200,000
Letters of credit outstanding	25,000,000							44,100,000
Range of interest rates and weighted average interest rate [Abstract]
Cash payments related to acquisition	5,047,800,000
Net proceeds from issuance of senior notes	1,100,000,000		0
Atlas Pipeline Partners [Member]
Range of interest rates and weighted average interest rate [Abstract]
Cash payment related to change of control payments				28,800,000			28,800,000
Results of tender offers [Abstract]
Amount Tendered and Paid				1,200,000,000
Senior Unsecured Notes Due October 2020 [Member] | Atlas Pipeline Partners [Member]
Results of tender offers [Abstract]
Amount to be received per $1,000 principal by APL noteholders pursuant to Change of Control Offer						1,010
Senior Unsecured Notes Due October 2020 [Member] | Atlas Pipeline Partners [Member] | Subsequent Event [Member]
Results of tender offers [Abstract]
Amount Tendered and Paid					341,900,000
Tendered percentage (in hundredths)					96.30%
Note Balance after Tender Offers					355,100,000
APL Senior Notes [Member] | Atlas Pipeline Partners [Member]
Results of tender offers [Abstract]
Amount Tendered and Paid						1,168,800,000
Shelf Offering April 2015 [Member] | Subsequent Event [Member]
Results of tender offers [Abstract]
Aggregate amount of debt or equity securities allowed under shelf agreement					1,000,000,000
Revolving Credit Facility [Member] | Atlas Pipeline Partners [Member]
Range of interest rates and weighted average interest rate [Abstract]
Cash payments related to acquisition							701,400,000
Revolving Credit Facility [Member] | Revolving Credit Facility Due 2017 [Member]
Debt Instrument [Line Items]
Long-term debt	840,000,000	[1]						0	[1]
Maturity Date	31-Oct-17
Maximum borrowing capacity	1,600,000,000					1,200,000,000	1,600,000,000
Remaining borrowing capacity	735,000,000
Range of interest rates and weighted average interest rate [Abstract]
Range of Interest Rates Incurred (in hundredths)	1.90%
Weighted Average Interest Rate Incurred (in hundredths)	1.90%
Additional commitment increase available upon request						300,000,000	300,000,000
Senior Unsecured Notes [Member] | Senior Unsecured Notes due 2018 [Member]
Debt Instrument [Line Items]
Long-term debt	1,100,000,000							0
Maturity Date	31-Jan-18
Interest rate on fixed rate debt (in hundredths)	5.00%
Range of interest rates and weighted average interest rate [Abstract]
Aggregate principal amount						1,100,000,000
Net proceeds from issuance of senior notes						1,089,800,000
Senior Unsecured Notes [Member] | Senior Unsecured Notes due 2021 [Member]
Debt Instrument [Line Items]
Long-term debt	483,600,000							483,600,000
Maturity Date	28-Feb-21
Interest rate on fixed rate debt (in hundredths)	6.88%
Senior Unsecured Notes [Member] | Senior Unsecured Notes due 2021 Unamortized Discount [Member]
Debt Instrument [Line Items]
Unamortized discount	-24,500,000							-25,200,000
Senior Unsecured Notes [Member] | Senior Unsecured Notes due 2022 [Member]
Debt Instrument [Line Items]
Long-term debt	300,000,000							300,000,000
Maturity Date	31-Aug-22
Interest rate on fixed rate debt (in hundredths)	6.38%
Senior Unsecured Notes [Member] | Senior Unsecured Notes due May 2023 [Member]
Debt Instrument [Line Items]
Long-term debt	600,000,000							600,000,000
Maturity Date	31-May-23
Interest rate on fixed rate debt (in hundredths)	5.25%
Senior Unsecured Notes [Member] | Senior Unsecured Notes due November 2023 [Member]
Debt Instrument [Line Items]
Long-term debt	625,000,000							625,000,000
Maturity Date	30-Nov-23
Interest rate on fixed rate debt (in hundredths)	4.25%
Senior Unsecured Notes [Member] | Senior Unsecured Notes due November 2019 [Member]
Debt Instrument [Line Items]
Long-term debt	800,000,000							800,000,000
Maturity Date	30-Nov-19
Interest rate on fixed rate debt (in hundredths)	4.13%
Senior Unsecured Notes [Member] | Senior Unsecured Notes Due October 2020 [Member]
Debt Instrument [Line Items]
Long-term debt	355,100,000	[2]						0	[2]
Unamortized premium	6,000,000							0
Maturity Date	31-Oct-20
Interest rate on fixed rate debt (in hundredths)	6.63%
Senior Unsecured Notes [Member] | Senior Unsecured Notes Due November 2021 [Member]
Debt Instrument [Line Items]
Long-term debt	6,500,000	[2]						0	[2]
Maturity Date	30-Nov-21
Interest rate on fixed rate debt (in hundredths)	4.75%
Senior Unsecured Notes [Member] | Senior Unsecured Notes Due August 2023 [Member]
Debt Instrument [Line Items]
Long-term debt	48,100,000	[2]						0	[2]
Unamortized premium	600,000							0
Maturity Date	31-Aug-23
Interest rate on fixed rate debt (in hundredths)	5.88%
APL Senior Notes Tender Offers [Member]
Results of tender offers [Abstract]
Outstanding Note Balance	1,550,000,000					1,550,000,000
Amount Tendered and Paid	1,135,500,000
Premium Paid	16,700,000
Accrued Interest Paid	11,600,000
Total Tender Offer payments	1,163,800,000
Note Balance after Tender Offers	414,500,000
APL Senior Notes Tender Offers [Member] | Senior Unsecured Notes Due October 2020 [Member]
Results of tender offers [Abstract]
Outstanding Note Balance	500,000,000					500,000,000
Amount Tendered and Paid	140,100,000
Premium Paid	2,100,000
Accrued Interest Paid	3,700,000
Total Tender Offer payments	145,900,000
Tendered percentage (in hundredths)	28.02%
Note Balance after Tender Offers	359,900,000
APL Senior Notes Tender Offers [Member] | Senior Unsecured Notes Due November 2021 [Member]
Results of tender offers [Abstract]
Outstanding Note Balance	400,000,000					400,000,000
Amount Tendered and Paid	393,500,000
Premium Paid	5,900,000
Accrued Interest Paid	5,300,000
Total Tender Offer payments	404,700,000
Tendered percentage (in hundredths)	98.38%
Note Balance after Tender Offers	6,500,000
APL Senior Notes Tender Offers [Member] | Senior Unsecured Notes Due August 2023 [Member]
Results of tender offers [Abstract]
Outstanding Note Balance	650,000,000					650,000,000
Amount Tendered and Paid	601,900,000
Premium Paid	8,700,000
Accrued Interest Paid	2,600,000
Total Tender Offer payments	613,200,000
Tendered percentage (in hundredths)	92.60%
Note Balance after Tender Offers	48,100,000
APL Senior Notes with Offers Tendered [Member] | Senior Unsecured Notes Due October 2020 [Member] | Atlas Pipeline Partners [Member]
Results of tender offers [Abstract]
Amount Tendered and Paid				4,800,000
Total Tender Offer payments				5,000,000
Accounts Receivable Securitization Facility [Member]
Debt Instrument [Line Items]
Maturity Date	31-Dec-15
Range of interest rates and weighted average interest rate [Abstract]
Range of Interest Rates Incurred (in hundredths)	0.90%
Weighted Average Interest Rate Incurred (in hundredths)	0.90%
Accounts Receivable Securitization Facility [Member] | Accounts Receivable Securitization Facility due December 2015 [Member]
Debt Instrument [Line Items]
Current debt	$197,900,000	[1]						$182,800,000	[1]
[1]	As of March 31, 2015, availability under our $1.6 billion senior secured revolving credit facility was $735.0 million.
[2]	Senior unsecured notes issued by APL entities and acquired in the Atlas mergers.

Partnership_Units_and_Related_2

Partnership Units and Related Matters (Details) (USD $)	3 Months Ended			0 Months Ended	1 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014	Feb. 27, 2015	Apr. 30, 2015	Apr. 20, 2015
Partnership Equity [Abstract]
General partner interest (in hundredths)	2.00%
Number of days from end of each quarter by when cash is distributed to unitholders	45 days
Distributions Made to Members or Limited Partners [Abstract]
Total distributions to general and limited partners	$137,400,000	$115,800,000
Distributions Declared [Member]
Distributions Made to Members or Limited Partners [Abstract]
Date Paid or to be paid	15-May-15
Distribution to limited partners common	148,300,000
Distributions to general partners (Incentive distribution rights)	47,100,000
Distributions to general partners (2%)	3,900,000
Total distributions to general and limited partners	193,900,000
Distributions per limited partner per unit (in dollars per unit)	$0.82
Distributions Paid [Member]
Distributions Made to Members or Limited Partners [Abstract]
Date Paid or to be paid			13-Feb-15
Distributions to limited partners Common			96,300,000
Distributions to general partners (Incentive distribution rights)			38,400,000
Distributions to general partners (2%)			2,700,000
Total distributions to general and limited partners			137,400,000
Distributions per limited partner per unit (in dollars per unit)			$0.81
Atlas Pipeline Partners [Member]
Partnership Equity [Abstract]
Number of common units included in public offerings (in shares)				58,614,157
General partner interest (in hundredths)	2.00%
Atlas Pipeline Partners [Member] | Atlas Energy [Member]
Partnership Equity [Abstract]
Number of common units included in public offerings (in shares)				3,363,935
Atlas Pipeline Partners [Member] | Distribution Rights Year 1 [Member]
Partnership Equity [Abstract]
Reduction in incentive distribution	9,375,000
Atlas Pipeline Partners [Member] | Distribution Rights Year 2 [Member]
Partnership Equity [Abstract]
Reduction in incentive distribution	6,250,000
Atlas Pipeline Partners [Member] | Distribution Rights Year 3 [Member]
Partnership Equity [Abstract]
Reduction in incentive distribution	2,500,000
Atlas Pipeline Partners [Member] | Distribution Rights Year 4 [Member]
Partnership Equity [Abstract]
Reduction in incentive distribution	1,250,000
May 2014 EDA [Member]
Partnership Equity [Abstract]
Number of common units included in public offerings (in shares)	1,271,876
Proceeds from public offering, net of commissions	53,000,000				24,800,000
Commissions to sales agents, maximum (in hundredths)	1.00%
General partner contributed to maintain general partner ownership percentage	1,100,000				800,000
General partner interest (in hundredths)	2.00%
Dollar amount of Common Units able to sell from Equity Distribution Agreement	400,000,000
May 2014 EDA [Member] | Subsequent Event [Member]
Partnership Equity [Abstract]
Number of common units included in public offerings (in shares)					2,318,950
Proceeds from public offering, net of commissions					100,100,000
General partner contributed to maintain general partner ownership percentage					2,100,000
General partner interest (in hundredths)					2.00%
Aggregate offering amount remained available for sale pursuant to agreement						$4,200,000

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, 2015	Mar. 31, 2014
Earnings per Limited Partner Unit [Abstract]
Net income	$76.50	$131.30
Less: Net income attributable to noncontrolling interests	4.9	8.9
Net income attributable to Targa Resources Partners LP	71.6	122.4
Net income attributable to general partner	42.5	33.8
Net income attributable to limited partners	29.1	88.6
Net income attributable to Targa Resources Partners LP	$71.60	$122.40
Weighted average units outstanding - basic (in shares)	137.1	112.4
Net income available per limited partner unit - basic (in dollars per share)	$0.21	$0.79
Weighted average units outstanding (in shares)	137.1	112.4
Dilutive effect of unvested stock awards (in shares)	0.4	0.6
Weighted average units outstanding - diluted (in shares)	137.5	113
Net income available per limited partner unit - diluted (in dollars per share)	$0.21	$0.78

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Feb. 27, 2015
Derivative [Line Items]
Fair value of outstanding derivative contracts	$174.80
Atlas Pipeline Partners [Member]
Derivative [Line Items]
Fair value of outstanding derivative contracts		102.1
Fair value of derivative contracts received as component of derivative contract settlement	7.8
Mark-to-market gains	0.5
Ineffectiveness gains	1
Swaps [Member] | Natural Gas [Member] | Year 2015 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day)	125,439
Swaps [Member] | Natural Gas [Member] | Year 2016 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day)	68,205
Swaps [Member] | Natural Gas [Member] | Year 2017 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day)	23,082
Swaps [Member] | NGL [Member] | Year 2015 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	5,928
Swaps [Member] | NGL [Member] | Year 2016 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	2,254
Swaps [Member] | NGL [Member] | Year 2017 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	658
Swaps [Member] | Condensate [Member] | Year 2015 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	1,991
Swaps [Member] | Condensate [Member] | Year 2016 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	1,082
Swaps [Member] | Condensate [Member] | Year 2017 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	500
Basis Swaps [Member] | Natural Gas [Member] | Year 2015 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day)	23,782
Basis Swaps [Member] | Natural Gas [Member] | Year 2016 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day)	0
Basis Swaps [Member] | Natural Gas [Member] | Year 2017 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in MMBtu per day)	0
Options [Member] | NGL [Member] | Year 2015 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	899
Options [Member] | NGL [Member] | Year 2016 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	790
Options [Member] | NGL [Member] | Year 2017 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	790
Options [Member] | Condensate [Member] | Year 2015 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	1,198
Options [Member] | Condensate [Member] | Year 2016 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	380
Options [Member] | Condensate [Member] | Year 2017 [Member]
Derivative [Line Items]
Notional volumes of commodity hedges (in Bbl per day)	380
Options [Member] | Crude Oil [Member] | Atlas Pipeline Partners [Member]
Derivative [Line Items]
Fair value of outstanding derivative contracts		$7.70

Derivative_Instruments_and_Hed3

Derivative Instruments and Hedging Activities, Fair Values Derivatives, Balance Sheet Location, By Derivative Contract Type (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Derivatives, Fair Value [Line Items]
Derivative assets	$177.20	$60.20
Derivative liabilities	2.4	5.2
Current Assets from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	126	44.4
Long-term Assets from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	51.2	15.8
Current Liabilities from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	0.6	5.2
Long-term Liabilities from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	1.8	0
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	169	60.2
Derivative liabilities	2.2	0
Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Assets from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	117.8	44.4
Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Long-term Assets from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	51.2	15.8
Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Liabilities from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	0.4	0
Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Long-term Liabilities from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	1.8	0
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	8.2	0
Derivative liabilities	0.2	5.2
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Assets from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	8.2	0
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Current Liabilities from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities	$0.20	$5.20

Derivative_Instruments_and_Hed4

Derivative Instruments and Hedging Activities, Pro Forma Impact - Offsetting Assets (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Derivative Asset [Abstract]
Pro forma net presentation, asset	$174.80
Gross asset	177.2	60.2
Pro forma net presentation, asset, total	174.8	55.8
Counterparties with Offsetting Position [Member]
Derivative Asset [Abstract]
Gross asset	73.4	35.5
Gross liability	2.4	4.4
Pro forma net presentation, asset	71	31.1
Counterparties without Offsetting Position [Member]
Derivative Asset [Abstract]
Gross asset	103.8	24.7
Current Position [Member]
Derivative Asset [Abstract]
Gross asset	126	44.4
Pro forma net presentation, asset, current	125.4	40
Current Position [Member] | Counterparties with Offsetting Position [Member]
Derivative Asset [Abstract]
Gross asset	54	35.5
Gross liability	0.6	4.4
Pro forma net presentation, asset	53.4	31.1
Current Position [Member] | Counterparties without Offsetting Position [Member]
Derivative Asset [Abstract]
Gross asset	72	8.9
Long-term Position [Member]
Derivative Asset [Abstract]
Gross asset	51.2	15.8
Pro forma net presentation, asset, noncurrent	49.4	15.8
Long-term Position [Member] | Counterparties with Offsetting Position [Member]
Derivative Asset [Abstract]
Gross asset	19.4	0
Gross liability	1.8	0
Pro forma net presentation, asset	17.6	0
Long-term Position [Member] | Counterparties without Offsetting Position [Member]
Derivative Asset [Abstract]
Gross asset	$31.80	$15.80

Derivative_Instruments_and_Hed5

Derivative Instruments and Hedging Activities, Pro Forma Impact - Offsetting Liabilities (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Derivative Liability [Abstract]
Pro forma net presentation, liability	$174.80
Gross liability	2.4	5.2
Pro forma net presentation, liability, total	0	0.8
Counterparties with Offsetting Position [Member]
Derivative Liability [Abstract]
Pro forma net presentation, liability	71	31.1
Counterparties without Offsetting Position [Member]
Derivative Liability [Abstract]
Gross liability	0	0.8
Current Position [Member]
Derivative Liability [Abstract]
Gross liability	0.6	5.2
Pro forma net presentation, liability, current	0	0.8
Current Position [Member] | Counterparties without Offsetting Position [Member]
Derivative Liability [Abstract]
Gross liability	0	0.8
Long-term Position [Member]
Derivative Liability [Abstract]
Gross liability	1.8	0
Pro forma net presentation, liability, noncurrent	0	0
Long-term Position [Member] | Counterparties without Offsetting Position [Member]
Derivative Liability [Abstract]
Gross liability	$0	$0

Derivative_Instruments_and_Hed6

Derivative Instruments and Hedging Activities, Amounts Included in OCI, Income and AOCI (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014	Dec. 31, 2014
Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from OCI into income (effective portion)	$8.10		($7.60)
Net gains on commodity hedges recorded in OCI that are expected to be reclassified to revenue within twelve months	53.3
Cash Flow Hedging [Member] | Interest Expense, Net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from OCI into income (effective portion)	0		-1.3
Cash Flow Hedging [Member] | Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from OCI into income (effective portion)	8.1		-6.3
Cash Flow Hedging [Member] | Commodity Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) recognized in OCI on derivatives (effective portion)	25.2		-11.9
Deferred gains (losses) included in accumulated OCI	77.4	[1]		60.3	[1]
Not Designated as Hedging Instrument [Member] | Commodity Contracts [Member] | Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) recognized in income on derivatives	$7.20		($0.20)
[1]	Includes deferred net gains of $53.3 million as of March 31, 2015 related to contracts that will be settled and reclassified to revenue over the next 12 months.

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Dec. 31, 2014
Fair Value Measurements [Abstract]
Derivatives financial instruments, fair value, net	$174.80
Derivative fair value of net asset if commodity price increases by 10 percent	132.7
Derivative fair value of net asset if commodity price decreases by 10 percent	199.2
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]
Assets from commodity derivative contracts	174.8		55.8
Liability from commodity derivative contracts	0		0.8
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Number of natural gas basis swaps categorized as Level 3	13
Commodity Derivative Contracts Asset/ (Liability)
Fair Value Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Balance, beginning of period	-1.7
Settlements included in Revenue	0
Unrealized gains included in OCI	-1.1
Transfers into Level 3	-0.6
Transfers out of Level 3	-0.1
Balance, end of period	-3.5
Carrying Value [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]
Assets from commodity derivative contracts	177.2	[1]
Liability from commodity derivative contracts	2.4	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Cash and cash equivalents	63.5
Carrying Value [Member] | Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	840
Carrying Value [Member] | Senior Unsecured Notes [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	4,300.40
Carrying Value [Member] | Accounts Receivable Securitization Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	197.9
Fair Value [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]
Assets from commodity derivative contracts	177.2	[1]
Liability from commodity derivative contracts	2.4	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Cash and cash equivalents	63.5
Fair Value [Member] | Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	840
Fair Value [Member] | Senior Unsecured Notes [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	4,384.90
Fair Value [Member] | Accounts Receivable Securitization Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	197.9
Fair Value [Member] | Level 1 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]
Assets from commodity derivative contracts	0	[1]
Liability from commodity derivative contracts	0	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Cash and cash equivalents	0
Fair Value [Member] | Level 1 [Member] | Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Fair Value [Member] | Level 1 [Member] | Senior Unsecured Notes [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Fair Value [Member] | Level 1 [Member] | Accounts Receivable Securitization Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	197.9
Fair Value [Member] | Level 2 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]
Assets from commodity derivative contracts	172.9	[1]
Liability from commodity derivative contracts	1.6	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Cash and cash equivalents	0
Fair Value [Member] | Level 2 [Member] | Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	840
Fair Value [Member] | Level 2 [Member] | Senior Unsecured Notes [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	4,384.90
Fair Value [Member] | Level 2 [Member] | Accounts Receivable Securitization Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Fair Value [Member] | Level 3 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]
Assets from commodity derivative contracts	4.3	[1]
Liability from commodity derivative contracts	0.8	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Cash and cash equivalents	0
Fair Value [Member] | Level 3 [Member] | Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Fair Value [Member] | Level 3 [Member] | Senior Unsecured Notes [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Fair Value [Member] | Level 3 [Member] | Accounts Receivable Securitization Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	$0
[1]	The fair value of our derivative contracts in this table is presented on a different basis than the Consolidated Balance Sheets presentation as disclosed in Note 13. The above fair values reflect the total value of each derivative contract taken as a whole, whereas the Consolidated Balance Sheets 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 Consolidated Balance Sheets classification purposes.

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Summary of transactions with Targa [Abstract]
Cash contributions from Targa to maintain its 2% general partner ownership	$53.60
General partner interest (in hundredths)	2.00%
Targa Resources Corp. [Member]
Summary of transactions with Targa [Abstract]
Targa billings of payroll and related costs included in operating expense	34.9	29.9
Targa allocation of general and administrative expense	38.3	33.4
Cash distributions to Targa based on unit ownership	51.6	41.5
Cash contributions from Targa to maintain its 2% general partner ownership	$53.60	$2.40
General partner interest (in hundredths)	2.00%

Contingencies_Details

Contingencies (Details) (Atlas Unitholder Litigation [Member])	3 Months Ended	2 Months Ended
	Dec. 31, 2014	Nov. 30, 2014
	Unitholder	Unitholder
Atlas Pipeline Partners [Member]
Loss Contingencies [Line Items]
Number of public unitholders who filed lawsuits	5
Atlas Energy [Member]
Loss Contingencies [Line Items]
Number of public unitholders who filed lawsuits		2

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Cash [Abstract]
Interest paid, net of capitalized interest	$28.90	[1]	$23	[1]
Income taxes paid, net of refunds	0.1		-0.2
Non-cash Investing and Financing balance sheet movements [Abstract]
Deadstock commodity inventories transferred to property, plant and equipment	0		1.1
Accrued distribution equivalent rights on equity awards under share compensation arrangements	0		0.6
Receivables from equity issuances	24.6		7.1
Capital expenditure accruals	31		22.7
Transfers from materials and supplies inventory to property, plant and equipment	0.6		0.4
Change in ARO liability and property, plant and equipment due to revised future ARO cash flow estimate	3.7		2.1
Interest capitalized on major projects	$2.40		$6.90
[1]	Interest capitalized on major projects was $2.4 million and $6.9 million for three months ended March 31, 2015 and 2014.

Segment_Information_Details

Segment Information (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014	Feb. 27, 2015	Dec. 31, 2014
	Division
Segment Information [Abstract]
Number of divisions	2
Segment Reporting Information [Line Items]
Sales of commodities	$1,402.20		$2,085.10
Fees from midstream services	277.5		209.6
Revenues	1,679.70		2,294.70
Operating margin	300.1		275.3
Special GP Interest [Abstract]
Goodwill	628.5	[1]		628.5	0
Intangible assets	1,602.40	[1]			591.9
Total assets	13,439.60	[2]	5,976.30		6,377.20
Capital expenditures	157.3		175.4
Business acquisition	5,047.80
Special GP Interest [Member]
Special GP Interest [Abstract]
Goodwill	628.5	[1]
Intangible assets	979.9	[1]
Reportable Segments [Member]
Special GP Interest [Abstract]
Total assets	11,831.20	[2]
Gathering and Processing [Member]
Segment Reporting Information [Line Items]
Number of reportable segments per division	2
Field Gathering and Processing [Member] | Reportable Segments [Member]
Segment Reporting Information [Line Items]
Revenues	448.7		488.1
Operating margin	79.3		94.1
Special GP Interest [Abstract]
Total assets	8,871.20
Coastal Gathering and Processing [Member] | Reportable Segments [Member]
Segment Reporting Information [Line Items]
Revenues	124.3		285.2
Operating margin	7.8		26.1
Special GP Interest [Abstract]
Total assets	352.9
Logistics and Marketing [Member]
Segment Reporting Information [Line Items]
Number of reportable segments per division	2
Logistics Assets [Member] | Reportable Segments [Member]
Segment Reporting Information [Line Items]
Revenues	188.6		155.9
Operating margin	125.4		96.6
Special GP Interest [Abstract]
Total assets	1,764.60
Marketing and Distribution [Member] | Reportable Segments [Member]
Segment Reporting Information [Line Items]
Revenues	1,332.90		2,155.10
Operating margin	65.9		64.6
Special GP Interest [Abstract]
Total assets	487
Other Segment [Member]
Special GP Interest [Abstract]
Total assets	177.3
Corporate And Elimination [Member]
Segment Reporting Information [Line Items]
Revenues	-436.5		-783.5
Operating margin	0		0
Special GP Interest [Abstract]
Total assets	1,786.60	[2]	128.8
Capital expenditures	1.1		0.5
Business acquisition	0
Corporate And Elimination [Member] | Special GP Interest [Member]
Special GP Interest [Abstract]
Goodwill	0	[1]
Intangible assets	0	[1]
Operating Segments [Member] | Field Gathering and Processing [Member] | Reportable Segments [Member]
Segment Reporting Information [Line Items]
Sales of commodities	168		45.8
Fees from midstream services	63.3		40.8
Revenues	231.3		86.6
Special GP Interest [Abstract]
Total assets	7,262.80	[2]	3,275.10
Capital expenditures	94.4		98.9
Business acquisition	5,047.80
Operating Segments [Member] | Field Gathering and Processing [Member] | Reportable Segments [Member] | Special GP Interest [Member]
Special GP Interest [Abstract]
Goodwill	628.5	[1]
Intangible assets	979.9	[1]
Operating Segments [Member] | Coastal Gathering and Processing [Member] | Reportable Segments [Member]
Segment Reporting Information [Line Items]
Sales of commodities	52.7		100.5
Fees from midstream services	8.8		7.7
Revenues	61.5		108.2
Special GP Interest [Abstract]
Total assets	352.9	[2]	385.1
Capital expenditures	1.1		4.3
Business acquisition	0
Operating Segments [Member] | Coastal Gathering and Processing [Member] | Reportable Segments [Member] | Special GP Interest [Member]
Special GP Interest [Abstract]
Goodwill	0	[1]
Intangible assets	0	[1]
Operating Segments [Member] | Logistics Assets [Member] | Reportable Segments [Member]
Segment Reporting Information [Line Items]
Sales of commodities	27.4		21
Fees from midstream services	87.7		68.1
Revenues	115.1		89.1
Special GP Interest [Abstract]
Total assets	1,764.60	[2]	1,568.70
Capital expenditures	57.7		68.6
Business acquisition	0
Operating Segments [Member] | Logistics Assets [Member] | Reportable Segments [Member] | Special GP Interest [Member]
Special GP Interest [Abstract]
Goodwill	0	[1]
Intangible assets	0	[1]
Operating Segments [Member] | Marketing and Distribution [Member] | Reportable Segments [Member]
Segment Reporting Information [Line Items]
Sales of commodities	1,132.30		1,924
Fees from midstream services	117.7		92.8
Revenues	1,250		2,016.80
Special GP Interest [Abstract]
Total assets	487	[2]	614.1
Capital expenditures	3		3.1
Business acquisition	0
Operating Segments [Member] | Marketing and Distribution [Member] | Reportable Segments [Member] | Special GP Interest [Member]
Special GP Interest [Abstract]
Goodwill	0	[1]
Intangible assets	0	[1]
Operating Segments [Member] | Other Segment [Member]
Segment Reporting Information [Line Items]
Sales of commodities	21.7		-6.1
Fees from midstream services	0		0
Revenues	21.7		-6.1
Operating margin	21.7		-6.1
Special GP Interest [Abstract]
Total assets	177.3	[2]	4.5
Capital expenditures	0		0
Business acquisition	0
Operating Segments [Member] | Other Segment [Member] | Special GP Interest [Member]
Special GP Interest [Abstract]
Goodwill	0	[1]
Intangible assets	0	[1]
Operating Segments [Member] | Corporate And Elimination [Member]
Segment Reporting Information [Line Items]
Sales of commodities	0.1		-0.1
Fees from midstream services	0		0.2
Revenues	0.1		0.1
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Sales of commodities	0		0
Fees from midstream services	0		0
Intersegment revenues	0		0
Intersegment Eliminations [Member] | Field Gathering and Processing [Member] | Reportable Segments [Member]
Segment Reporting Information [Line Items]
Sales of commodities	215.4		400.4
Fees from midstream services	2		1.1
Intersegment revenues	217.4		401.5
Intersegment Eliminations [Member] | Coastal Gathering and Processing [Member] | Reportable Segments [Member]
Segment Reporting Information [Line Items]
Sales of commodities	62.8		177
Fees from midstream services	0		0
Intersegment revenues	62.8		177
Intersegment Eliminations [Member] | Logistics Assets [Member] | Reportable Segments [Member]
Segment Reporting Information [Line Items]
Sales of commodities	1.1		0.6
Fees from midstream services	72.4		66.2
Intersegment revenues	73.5		66.8
Intersegment Eliminations [Member] | Marketing and Distribution [Member] | Reportable Segments [Member]
Segment Reporting Information [Line Items]
Sales of commodities	78.5		130.4
Fees from midstream services	4.4		7.9
Intersegment revenues	82.9		138.3
Intersegment Eliminations [Member] | Other Segment [Member]
Segment Reporting Information [Line Items]
Sales of commodities	0		0
Fees from midstream services	0		0
Intersegment revenues	0		0
Intersegment Eliminations [Member] | Corporate And Elimination [Member]
Segment Reporting Information [Line Items]
Sales of commodities	-357.8		-708.4
Fees from midstream services	-78.8		-75.2
Intersegment revenues	($436.60)		($783.60)
[1]	Represents preliminary acquisition fair value attributable to the Special GP Interest attributable to goodwill and intangible assets.
[2]	Corporate assets at the Segment level primarily include investment in unconsolidated subsidiaries and debt issuance costs associated with our long-term debt.

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, 2015	Mar. 31, 2014
Revenue from External Customer [Line Items]
Sales of commodities	$1,402.20	$2,085.10
Fees from midstream services	277.5	209.6
Revenues	1,679.70	2,294.70
Reconciliation of operating margin to net income [Abstract]
Operating margin	300.1	275.3
Depreciation and amortization expense	-119.6	-79.5
General and administrative expense	-40.3	-35.9
Interest expense, net	-50.9	-33.1
Other, net	-11.7	5.6
Income tax expense	-1.1	-1.1
Net income	76.5	131.3
Natural Gas [Member]
Revenue from External Customer [Line Items]
Sales of commodities	302.1	391.8
NGL [Member]
Revenue from External Customer [Line Items]
Sales of commodities	1,030.70	1,650.90
Condensate [Member]
Revenue from External Customer [Line Items]
Sales of commodities	21.3	28.4
Petroleum Products [Member]
Revenue from External Customer [Line Items]
Sales of commodities	26.4	20.1
Derivative Activities [Member]
Revenue from External Customer [Line Items]
Sales of commodities	21.7	-6.1
Fractionating and Treating [Member]
Revenue from External Customer [Line Items]
Fees from midstream services	49.8	46.5
Storage, Terminaling, Transportation and Export [Member]
Revenue from External Customer [Line Items]
Fees from midstream services	136.2	101.2
Gathering and Processing [Member]
Revenue from External Customer [Line Items]
Fees from midstream services	68.4	42.6
Other [Member]
Revenue from External Customer [Line Items]
Fees from midstream services	$23.10	$19.30