Targa Resources (TRGP) 10-Q7 May 152015 Q1 Quarterly reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
Document and Entity Information	Mar. 31, 2015	1-May-15
Document and Entity Information [Abstract]
Entity Registrant Name	Targa Resources Corp.
Entity Central Index Key	1389170
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
Entity Common Stock, Shares Outstanding		56,022,051
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15

CONSOLIDATED_BALANCE_SHEETS_Un

CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Millions, unless otherwise specified	Mar. 31, 2015		Dec. 31, 2014
Current assets:
Cash and cash equivalents	$170.70		$81
Trade receivables, net of allowances of $0.0 million	675.6		567.3
Inventories	78.2		168.9
Deferred income taxes	0		0.1
Assets from risk management activities	126		44.4
Other current assets	17.1		20.9
Total current assets	1,067.60		882.6
Property, plant and equipment	11,624.60		6,521.10
Accumulated depreciation	-1,791.60		-1,696.50
Property, plant and equipment, net	9,833		4,824.60
Goodwill	628.5	[1],[2]	0
Intangible assets, net	1,602.40	[2]	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	119.7		88.4
Total assets	13,625.30	[1]	6,453.50
Current liabilities:
Accounts payable and accrued liabilities	736.8		638.5
Accounts receivable securitization facility	197.9		182.8
Deferred income taxes	47.6		0.6
Liabilities from risk management activities	0.6		5.2
Total current liabilities	982.9		827.1
Long-term debt	5,838.20		2,885.40
Long-term liabilities from risk management activities	1.8		0
Deferred income taxes	127.8		138.2
Other long-term liabilities	80.2		63.3
Contingencies (see Note 16)
Targa Resources Corp. stockholders' equity:
Common stock ($0.001 par value, 300,000,000 shares authorized)	0.1		0
Preferred stock ($0.001 par value, 100,000,000 shares authorized, no shares issued and outstanding)	0		0
Additional paid-in capital	1,532.60		164.9
Retained earnings	3.1		25.5
Accumulated other comprehensive income	5.3		4.8
Treasury stock, at cost (406,258 shares as of March 31, 2015 and 388,890 as of December 31, 2014)	-27		-25.4
Total Targa Resources Corp. stockholders' equity	1,514.10		169.8
Noncontrolling interests in subsidiaries	5,080.30		2,369.70
Total owners' equity	6,594.40		2,539.50
Total liabilities and owners' equity	$13,625.30		$6,453.50

[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 the preliminary acquisition fair value attributable to goodwill and intangible assets associated with the Atlas mergers.

CONSOLIDATED_BALANCE_SHEETS_Un1

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Current assets:
Trade receivables, allowances	$0	$0
Owners' equity:
Common stock, par value (in dollars per share)	$0.00	$0.00
Common stock, shares authorized (in shares)	300,000,000	300,000,000
Common stock, shares issued (in shares)	56,427,480	42,529,068
Common stock, shares outstanding (in shares)	56,021,222	42,162,178
Preferred stock, par value (in dollar per share)	$0.00	$0.00
Preferred stock, shares authorized (in shares)	100,000,000	100,000,000
Preferred stock, shares issued (in shares)	0	0
Preferred stock, shares outstanding (in shares)	0	0
Treasury Stock, shares (in shares)	406,258	388,890

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	111.4		104.3
Depreciation and amortization expenses	119.6		79.6
General and administrative expenses	42.6		38
Other operating (income) expense	0.5		-0.7
Income from operations	137.3		158.4
Other income (expense):
Interest expense, net	-55		-33.9
Equity earnings	1.7	[1]	4.9
Loss on debt redemptions and amendments	-9		0
Other	-25.2		0
Income before income taxes	49.8		129.4
Income tax (expense) benefit:
Current	-9.1		-23.9
Deferred	-6.1		1.4
Income tax expense total	-15.2		-22.5
Net income	34.6		106.9
Less: Net income attributable to noncontrolling interests	31.4		87.3
Net income (loss) available to Targa Resources Corp.	$3.20		$19.60
Net income (loss) available per common share - basic (in dollars per share)	$0.07		$0.47
Net income (loss) available per common share - diluted (in dollars per share)	$0.07		$0.47
Weighted average shares outstanding - basic (in shares)	45.8		42
Weighted average shares outstanding - diluted (in shares)	45.9		42.1

[1]	Includes equity earnings of acquired investments since the date of acquisition of February 27, 2015.

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
Targa Resources Corp.
Net income attributable to common shareholders	$3.20	$19.60
Commodity hedging contracts:
Change in fair value, pre-tax	1.8	-1.5
Change in fair value, related income tax	-0.7	0.6
Change in fair value, after tax	1.1	-0.9
Settlements reclassified to revenues, pre-tax	-0.9	0.8
Settlements reclassified to revenues, related income tax	0.3	-0.3
Settlements reclassified to revenues, after tax	-0.6	0.5
Interest rate swaps:
Settlements reclassified to interest expense, net, pre-tax	0	0.2
Settlements reclassified to interest expense, net, related income tax	0	-0.1
Settlements reclassified to interest expense, net, after tax	0	0.1
Other comprehensive income (loss) attributable to Targa Resources Corp., pre-tax	0.9	-0.5
Other comprehensive income (loss) attributable to Targa Resources Corp., related income tax	-0.4	0.2
Other comprehensive income (loss) attributable to Targa Resources Corp., after tax	0.5	-0.3
Comprehensive income attributable to Targa Resources Corp.	3.7	19.3
Noncontrolling interests
Net income attributable to noncontrolling interests	31.4	87.3
Commodity hedging contracts:
Change in fair value, pre-tax	23.4	-10.3
Change in fair value, related income tax	0	0
Change in fair value, after tax	23.4	-10.3
Settlements reclassified to revenues, pre-tax	-7.2	5.5
Settlements reclassified to revenues, related income tax	0	0
Settlements reclassified to revenues, after tax	-7.2	5.5
Interest rate swaps:
Settlements reclassified to interest expense, net, pre-tax	0	1.1
Settlements reclassified to interest expense, net, related income tax	0	0
Settlements reclassified to interest expense, net, after tax	0	1.1
Other comprehensive loss attributable to noncontrolling interests, pre-tax	16.2	-3.7
Other comprehensive loss attributable to noncontrolling interests, related income tax	0	0
Other comprehensive loss attributable to noncontrolling interests, after tax	16.2	-3.7
Comprehensive income attributable to noncontrolling interests	47.6	83.6
Total
Net income	34.6	106.9
Commodity hedging contracts:
Change in fair value, pre-tax	25.2	-11.8
Change in fair value, related income tax	-0.7	0.6
Change in fair value, after tax	24.5	-11.2
Settlements reclassified to revenues, pre-tax	-8.1	6.3
Settlements reclassified to revenues, related income tax	0.3	-0.3
Settlements reclassified to revenues, after tax	-7.8	6
Interest rate swap:
Settlements reclassified to interest expense, net, pre-tax	0	1.3
Settlements reclassified to interest expense, net, related income tax	0	-0.1
Settlements reclassified to interest expense, net, after tax	0	1.2
Other comprehensive income (loss) attributable to Targa Resources Corp, pre-tax	17.1	-4.2
Other comprehensive income (loss) attributable to Targa Resources Corp, related income tax	-0.4	0.2
Other comprehensive income (loss) attributable to Targa Resources Corp, after tax	16.7	-4
Total comprehensive income	$51.30	$102.90

CONSOLIDATED_STATEMENTS_OF_CHA

CONSOLIDATED STATEMENTS OF CHANGES IN OWNERS' EQUITY (Unaudited) (USD $)	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings (Accumulated Deficit) [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Treasury Shares [Member]	Noncontrolling Interests [Member]	Total
In Millions, except Share data	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings (Accumulated Deficit) [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Treasury Shares [Member]	Noncontrolling Interests [Member]	Total
Balance at Dec. 31, 2013	$0	$151.60	$20.50	($0.50)	($22.80)	$1,942.50	$2,091.30
Balance (in shares) at Dec. 31, 2013	42,162,000				367,000
Compensation on equity grants	0	1.6	0	0	0	2.6	4.2
Compensation on equity grants (in shares)	5,000				0
Accrual of distribution equivalent rights	0	0	0	0	0	-0.6	-0.6
Repurchase of common stock	0	0	0	0	-0.8	0	-0.8
Repurchase of common stock (in shares)	-8,000				8,000
Common stock and Partnership units tendered for tax withholding obligations	0	0	0	0	0	0	0
Common stock and Partnership units tendered for tax withholding obligations (in shares)	0				0
Sale of Partnership limited partner interests	0	0	0	0	0	115.3	115.3
Receivables from Partnership unit offerings		-5.9	0	0	0	0	-5.9
Impact of Partnership equity transactions	0	7.1	0	0	0	-7.1	0
Dividends	0	-5.2	-20.5	0	0	0	-25.7
Dividends in excess of retained earnings	0	0	0	0	0	0	0
Distributions to noncontrolling interests	0	0	0	0	0	-81.7	-81.7
Other comprehensive income (loss)	0	0	0	-0.3	0	-3.7	-4
Net income	0	0	19.6	0	0	87.3	106.9
Balance at Mar. 31, 2014	0	149.2	19.6	-0.8	-23.6	2,054.60	2,199
Balance (in shares) at Mar. 31, 2014	42,159,000				375,000
Balance at Dec. 31, 2014	0	164.9	25.5	4.8	-25.4	2,369.70	2,539.50
Balance (in shares) at Dec. 31, 2014	42,143,000				389,000
Compensation on equity grants	0	2.1	0	0	0	3.8	5.9
Compensation on equity grants (in shares)	0				0
Accrual of distribution equivalent rights	0	-0.2	0	0	0	0	-0.2
Shares issued under compensation program	0	0	0	0	0	0	0
Shares issued under compensation program (in shares)	31,000				0
Common stock and Partnership units tendered for tax withholding obligations	0	0	0	0	-1.6	-0.6	-2.2
Common stock and Partnership units tendered for tax withholding obligations (in shares)	-17,000				17,000
Sale of Partnership limited partner interests	0	0	0	0	0	53	53
Receivables from Partnership unit offerings	0	-24.8	0	0	0	0	-24.8
Proceeds from equity issuances	0	336.2	0	0	0	0	336.2
Proceeds from equity issuances (in shares)	3,738,000				0
Impact of Partnership equity transactions	0	47.6	0	0	0	-47.6	0
Dividends	0	0	-25.6	0	0	0	-25.6
Dividends in excess of retained earnings	0	-6.8	0	0	0	3.4	-3.4
Distributions to noncontrolling interests	0	0	0	0	0	-88.6	-88.6
Contributions from noncontrolling interests	0	0	0	0		0	0
Noncontrolling interest in acquired subsidiaries	0	0	0	0	0	303.9	303.9
Common stock issued in ATLS merger		1,013.60	0	0	0	0	1,013.60
Common stock issued in ATLS merger (in shares)	10,126,000				0
Issuance of Partnership units in APL merger	0	0	0	0	0	2,435.70	2,435.70
Other comprehensive income (loss)	0	0	0	0.5	0	16.2	16.7
Net income	0	0	3.2	0	0	31.4	34.6
Balance at Mar. 31, 2015	0.1	1,532.60	3.1	5.3	-27	5,080.30	6,594.40
Balance (in shares) at Mar. 31, 2015	56,021,000				406,000
Balance at Feb. 28, 2015
Proceeds from equity issuances (in shares)	3,250,000
Balance at Mar. 31, 2015	$0.10
Balance (in shares) at Mar. 31, 2015	56,021,000

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	$34.60		$106.90
Adjustments to reconcile net income to net cash provided by operating activities:
Amortization in interest expense	3.2		3.6
Compensation on equity grants	5.9		4.2
Depreciation and amortization expense	119.6		79.6
Accretion of asset retirement obligations	1.3		1.2
Deferred income tax expense (benefit)	6.1		-1.4
Equity earnings of unconsolidated affiliate	-1.7	[1]	-4.9
Distributions received from unconsolidated affiliates	2.1		4.9
Risk management activities	6.5		-0.3
(Gain) loss on sale or disposition of assets	0.7		-0.8
Loss on debt redemptions and amendments	9.2		0
Changes in operating assets and liabilities:
Receivables and other assets	93.9		57.3
Inventory	102.4		60.6
Accounts payable and other liabilities	-91.2		7.8
Net cash provided by operating activities	292.6		318.7
Cash flows from investing activities
Outlays for property, plant and equipment	-187.6		-197.7
Outlays for business acquisitions, net of cash acquired	-1,598		0
Return of capital from unconsolidated affiliate	0.6		2.2
Other, net	-7.8		1.8
Net cash used in investing activities	-1,792.80		-193.7
Partnership debt obligations:
Proceeds from borrowings under credit facilities	975		460
Repayments of credit facilities	-135		-500
Proceeds from issuance of senior notes	1,100		0
Redemption of APL senior notes	-1,168.80		0
Proceeds from accounts receivable securitization facility	253.4		29.5
Repayments of accounts receivable securitization facility	-238.3		-75.7
Non-Partnership loan facility:
Proceeds from issuance of senior term loan	430		0
Repayments on senior term loan	-188		0
Proceeds from borrowings under credit facility	481		4
Repayments of credit facility	-123		-16
Costs incurred in connection with financing arrangements	-41.1		-1.2
Contributions from noncontrolling interests	0
Distributions to noncontrolling interests	-85.2		-81.7
Proceeds from equity offerings	336.2		0
Proceeds from sale of common units of the Partnership	28.2		110.6
Repurchase of common units under Partnership compensation plans	-0.6		0
Dividends to common shareholders	-32.4		-25.5
Repurchase of common stock under TRC compensation plans	-1.5		-0.8
Net cash provided by (used in) financing activities	1,589.90		-96.8
Net change in cash and cash equivalents	89.7		28.2
Cash and cash equivalents, beginning of period	81		66.7
Cash and cash equivalents, end of period	$170.70		$94.90

[1]	Includes equity earnings of acquired investments since the date of acquisition of February 27, 2015.

Organization

Organization	3 Months Ended
Organization	Mar. 31, 2015
Organization [Abstract]
Organization	Note 1 — Organization

	Targa Resources Corp. (“TRC”) is a publicly traded Delaware corporation formed in October 2005. Our common stock is listed on the New York Stock Exchange under the symbol “TRGP.” In this Quarterly Report, unless the context requires otherwise, references to “we,” “us,” “our,” “the Company” or “Targa” are intended to mean our consolidated business and operations.

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 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.

	One of our indirect subsidiaries is the sole general partner of Targa Resources Partners LP (“the Partnership” or “TRP”). Because we control the general partner of the Partnership, under GAAP, we must reflect our ownership interests in the Partnership on a consolidated basis. Accordingly, the Partnership’s financial results are included in our consolidated financial statements even though the distribution or transfer of Partnership assets is limited by the terms of the Partnership’s partnership agreement, as well as restrictive covenants in the Partnership’s lending agreements. The limited partner interests in the Partnership not owned by us are reflected in our consolidated results of operations as net income attributable to noncontrolling interests and in our consolidated balance sheet equity section as noncontrolling interests in subsidiaries. Throughout these footnotes, we make a distinction where relevant between financial results of the Partnership versus those of a standalone parent and its non-partnership subsidiaries.

	As of March 31, 2015, our interests in the Partnership consist of the following:

	·	a 2% general partner interest, which we hold through our 100% ownership interest in the general partner of the Partnership;

	·	all Incentive Distribution Rights (“IDRs”); and

	·	16,309,594 common units of the Partnership, representing a 9.1% limited partnership interest.

	The Partnership is 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 an analysis of our and the Partnership’s operations by business segment.

	The Partnership does not have any employees. We provide operational, general and administrative and other services to the Partnership, associated with the Partnership’s existing assets and assets acquired from third parties. We perform centralized corporate functions for the Partnership, 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 the Partnership and us, as general partner of the Partnership, governs the reimbursement of costs incurred on the behalf of the Partnership. We charge the Partnership for all the direct costs of the employees assigned to its operations, as well as all general and administrative support costs other than (1) costs attributable to our status as a separate reporting company and (2) our costs of providing management and support services to certain unaffiliated spun-off entities. The Partnership generally reimburses us monthly for cost allocations to the extent that we have made a cash outlay.

Significant_Accounting_Policie

Significant Accounting Policies	3 Months Ended
Significant Accounting Policies	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. 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.

	The Partnership evaluates goodwill for impairment at least annually, as of November 30^th for all affected reporting units. The Partnership also evaluates 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. The Partnership 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 the Partnership’s Consolidated Balance Sheets and a goodwill impairment loss on the Partnership’s 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 ASU 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 ASU. 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 $63.8 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
Business Acquisitions	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, the Partnership’s 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. 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.


	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”).

	On February 27, 2015, the Partnership Agreement was amended to provide for the issuance of a special general partner interest in the Partnership (the “Special GP Interest”) 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 us to the Partnership 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.
	The Partnership 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 the Partnership’s 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, we acquired ATLS for a total purchase price of approximately $1.6 billion (including all assumed liabilities).

	Pursuant to the APL Merger Agreement, Targa agreed to cause the general partner of the Partnership to enter into an amendment to the Partnership’s partnership agreement, which we refer to as the IDR Giveback Amendment in order to reduce aggregate distributions to us, 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 the Partnership’s 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 APL merger adds 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 are 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 the Partnership's 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's 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, which were expensed at the acquisition date.

	ATLS owned, directly and indirectly, 5,754,253 APL common units immediately prior to closing. Our acquisition of ATLS resulted in our acquiring these common units (converted to 3,363,935 Partnership common units) valued at approximately $147.4 million (based on the $43.82 closing market price of a Partnership common unit 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.

	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 the Company 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 the Partnership’s 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 the Company 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 $25.8 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 the Partnership’s acquisition of APL and our 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 this acquisition 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			18.7		83

	The pro forma consolidated results of operations amounts have been calculated after applying the Company’s 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 $25.8 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:

	Fair Value of Consideration Transferred:
	Cash paid, net of cash acquired (1)
	TRC		$	745.7
	TRP			852.3
	Common shares of TRC			1,008.50
	Replacement restricted stock units awarded (2)			5.2
	Common units of TRP			2,421.10
	Replacement phantom units awarded (2)			15
	Total		$	5,047.80



-1	Net of cash acquired of $17.2 million, including $7.3 million to be received by us as part of the Atlas mergers, representing the one-time cash payment from the Partnership for the APL common units owned by ATLS. The one-time cash payment was paid by the Partnership in February 2015 and received by us from the transfer agent in April 2015. The receivable from the transfer agent is reflected in Other, net cash flows from investing activities on the Consolidated Statements of Cash Flows as of March 31, 2015.
-2	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 the 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			6.7
Current liabilities, less current portion of long-term debt			(234.0	)
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 preliminary fair value determination		$	4,419.30
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 the Company’s acquisition of ATLS and 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 of $3.0 million reported in current receivables and $4.5 million reported in other long-term assets related to a legal settlement with a counterparty. The gross amount due under contracts for this settlement is $7.5 million, all of which is expected to be collectible.

See Note 10, Debt Obligations, 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 Restricted Stock Units (RSUs)

In connection with the ATLS merger, we awarded replacement restricted stock units (“RSUs”) in accordance with and as required by the Atlas Merger Agreements to those APL employees that who became Targa employees after the acquisition. The vesting dates and terms remained unchanged from the existing ATLS awards, and will vest over the remaining terms of the awards, which are either 25% per year over the original four year term or 25% after the third year of the original term and 75% after the fourth year of the original term.

Each RSU will entitle the grantee to one common share on the vesting date and is an equity-settled award. The RSUs include dividend equivalents. When we declare and pay cash dividends, the holders of RSUs will be entitled within 60 days to receive cash payment of dividend equivalents in an amount equal to the cash dividends the holders would have received if they were the holders of record on the record date of the number of our common shares related to the RSUs.

The fair value of the RSUs was based on the closing price of our common shares 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.

Replacement Phantom Units

In connection with the APL merger, the Partnership 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 the Partnership declares and pays 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 the Partnership’s common units related to the replacement phantom units.

The fair value of the replacement phantom units was based on the closing price of the Partnership’s 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
Inventories	Mar. 31, 2015
Inventories [Abstract]
Inventories	Note 5 — Inventories

		31-Mar-15		31-Dec-14
	Partnership:
	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
Property, Plant and Equipment and Intangible Assets	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
		Targa			TRC Non-			Targa			Targa			TRC			Targa			Estimated
		Resources			Partnership			Resources			Resources			Non-			Resources			Useful Lives
		Partners LP						Corp.			Partners LP			Partnership			Corp.			(In Years)
								Consolidated									Consolidated
	Gathering systems	$	6,113.80		$	-		$	6,113.80		$	2,588.60		$	-		$	2,588.60		5 to 40
	Processing and fractionation facilities		2,924.60			6.6			2,931.20			1,884.10			6.6			1,890.70		5 to 40
	Terminaling and storage facilities		1,043.00			-			1,043.00			1,038.90			-			1,038.90		5 to 25
	Transportation assets		432.9			-			432.9			359			-			359		10 to 25
	Other property, plant and equipment		219.9			0.2			220.1			149.1			0.2			149.3		3 to 40
	Land		101.4			-			101.4			95.6			-			95.6		-
	Construction in progress		782.2			-			782.2			399			-			399		-
	Property, plant and equipment		11,617.80			6.8			11,624.60			6,514.30			6.8			6,521.10
	Accumulated depreciation		(1,784.9	)		(6.7	)		(1,791.6	)		(1,689.7	)		(6.8	)		(1,696.5	)
	Property, plant and equipment, net	$	9,832.90		$	0.1		$	9,833.00		$	4,824.60		$	0		$	4,824.60

	Intangible assets	$	1,716.60		$	-		$	1,716.60		$	681.8		$	-		$	681.8		20
	Accumulated amortization		(114.2	)		-			(114.2	)		(89.9	)		-			(89.9	)
	Intangible assets, net	$	1,602.40		$	-		$	1,602.40		$	591.9		$	-		$	591.9

	Intangible assets consist of customer contracts and customer relationships acquired in our Atlas mergers and our Badlands business acquisitions. The fair values of these acquired intangible assets were determined at the date 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 preliminary 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.

Asset_Retirement_Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligations [Abstract]
Asset Retirement Obligations	Note 7 — Asset Retirement Obligations

	The Partnership’s 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
		31-Mar-15
	Beginning of period	$	57.3
	Fair value of ARO acquired with Atlas mergers		4.1
	Change in cash flow estimate		3.7
	Accretion expense		1.3
	End of period	$	66.4

Investment_in_Unconsolidated_A

Investment in Unconsolidated Affiliates	3 Months Ended
	Mar. 31, 2015
Investment in Unconsolidated Affiliate [Abstract]
Investment in Unconsolidated Affiliate	Note 8 – Investment in Unconsolidated Affiliates

	At December 31, 2014, the Partnership’s unconsolidated investment consisted of a 38.8% ownership interest in Gulf Coast Fractionators LP (“GCF”). As of March 31, 2015, the Partnership continues to have a 38.8% ownership interest in GCF.

	On February 27, 2015, as part of the Atlas mergers, the Partnership acquired equity interests in three non-operated joint ventures, (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 the Partnership the degree of control required for consolidating them in our financial statements, but, they do afford the Partnership significant influence required to employ the equity method of accounting.

	The following table shows the activity related to the Partnership’s investments in unconsolidated affiliates:

			Three Months Ended
			31-Mar-15
	Beginning of period		$	50.2
	Fair value of T2 Joint Ventures			273.7
	Equity earnings (1)			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 the Partnership’s share of cumulative earnings for the three months ended March 31, 2015. Such excess distributions are considered a return of capital and disclosed in cash flows from investing activities in the Consolidated Statements of Cash Flows.

	The Partnership’s 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 the Partnership’s 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
Accounts Payable and Accrued Liabilities	Mar. 31, 2015
Accounts Payable and Accrued Liabilities [Abstract]
Accounts Payable and Accrued Liabilities	Note 9 — Accounts Payable and Accrued Liabilities

		31-Mar-15							31-Dec-14
		Targa		TRC Non-			Targa		Targa		TRC Non-			Targa
		Resources		Partnership			Resources		Resources		Partnership			Resources
		Partners LP					Corp.		Partners LP					Corp.
							Consolidated							Consolidated
	Commodities	$	445.8	$	-		$	445.8	$	416.7	$	-		$	416.7
	Other goods and services		169.8		2.9			172.7		108.9		2.2			111.1
	Interest		57		1.3			58.3		37.3		-			37.3
	Compensation and benefits		3.2		18.4			21.6		1.3		44.8			46.1
	Income and other taxes		20		(1.0	)		19		13.6		(1.9	)		11.7
	Other		15		4.4			19.4		14.9		0.7			15.6
		$	710.8	$	26		$	736.8	$	592.7	$	45.8		$	638.5

Debt_Obligations

Debt Obligations	3 Months Ended
Debt Obligations	Mar. 31, 2015
Debt Obligations [Abstract]
Debt Obligations	Note 10 — Debt Obligations

			31-Mar-15				31-Dec-14
	Current:
	Partnership
	Accounts receivable securitization facility, due December 2015 (1)		$	197.9			$	182.8
	Long-term:
	Non-Partnership obligations:
	TRC Senior secured revolving credit facility, variable rate, due February 2020 (2)			460				-
	TRC Senior secured term loan, variable rate, due February 2022			242				-
	Unamortized discount			(4.2	)			-
	TRC Senior secured revolving credit facility, variable rate, due October 2017			-				102
	Obligations of the Partnership: (1)
	Senior secured revolving credit facility, variable rate, due October 2017 (3)			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 (4)			355.1				-
	Unamortized premium			6				-
	Senior unsecured notes, 4¾% fixed rate, due November 2021 (4)			6.5				-
	Senior unsecured notes, 5⅞% fixed rate, due August 2023 (4)			48.1				-
	Unamortized premium			0.6				-
	Total long-term debt			5,838.20				2,885.40
	Total debt		$	6,036.10			$	3,068.20
	Irrevocable standby letters of credit:
	Letters of credit outstanding under TRC Senior secured credit facility (2)		$	-			$	-
	Letters of credit outstanding under the Partnership senior secured revolving credit facility (3)			25				44.1
			$	25			$	44.1



	-1	While we consolidate the debt of the Partnership in our financial statements, we do not have the obligation to make interest payments or debt payments with respect to the debt of the Partnership.
	-2	As of March 31, 2015, availability under TRC’s $670 million senior secured revolving credit facility was $210.0 million.
	-3	As of March 31, 2015, availability under the Partnership’s $1.6 billion senior secured revolving credit facility (“TRP Revolver”) was $735.0 million.
	-4	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 variable-rate debt obligations during the three months ended March 31, 2015:

			Range of Interest				Weighted Average
			Rates Incurred				Interest Rate Incurred
	TRC senior secured revolving credit facility			2.9	%			2.9	%
	TRC senior secured term loan			5.75	%			5.75	%
	Partnership's senior secured revolving credit facility			1.9	%			1.9	%
	Partnership's accounts receivable securitization facility			0.9	%			0.9	%

	Compliance with Debt Covenants

	As of March 31, 2015, both the Partnership and we were in compliance with the covenants contained in our various debt agreements.

	Partnership Financing Activities

	Revolving Credit Agreement

	In February 2015, the Partnership entered into the First Amendment, Waiver and Incremental Commitment Agreement (the “First Amendment”) that amended its 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 the Partnership’s ability to request up to an additional $300.0 million in commitment increases. In addition, the First Amendment amended certain provisions of the Original Agreement to designate each of APL and its subsidiaries as an “Unrestricted Subsidiary” under the Original Agreement. The Partnership 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, the Partnership 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 the TRP Revolver to fund the APL Notes Tender Offers and the Change of Control Offer. The 5% Notes are unsecured senior obligations that have the same terms and covenants as the Partnership’s other senior notes.

	Merger Financing Activities

ATLS Merger Financing Activities

In connection with the closing of the Atlas mergers, we entered into a Credit Agreement (the “TRC Credit Agreement”), dated as of February 27, 2015, among us, each lender from time to time party thereto and Bank of America, N.A. as administrative agent, collateral agent, swing line lender and letter of credit issuer. The TRC Credit Agreement provides for a new five year revolving credit facility in an aggregate principal amount up to $670 million and a seven year term loan facility in an aggregate principal amount of $430 million. We used the net proceeds from the term loan issuance and the revolving credit facility to fund cash components of the ATLS merger, including cash merger consideration and approximately $160 million related to change of control payments made by ATLS, cash settlements of equity awards and transaction fees and expenses. In March 2015, we repaid $188.0 million of the term loan and wrote off $3.3 million of the discount and $5.7 million of debt issuance costs. The write off of the discount and debt issuance costs are reflected as Loss on debt redemptions and amendments on the Consolidated Statements of Operations for the three months ended March 31, 2015.

APL Senior Notes Tender Offers
In January 2015, the Partnership commenced cash tender offers for any and all of the outstanding fixed rate senior secured notes acquired in the APL merger (“APL Notes”) which totaled $1,550.0 million, which we refer to as the APL Notes Tender Offers.

The results of the APL Notes Tender Offers were:

Senior Notes		Outstanding				Amount				Premium		Accrued		Total Tender		% Tendered			Note Balance
		Note Balance				Tendered				Paid		Interest		Offer					after Tender
												Paid		payments					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, the Partnership 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 Consolidated Statement of Cash Flows.

Subsequent event. On April 13, 2015, the Partnership and Targa Resources Partners Finance Corporation (collectively, the “Partnership Issuers” commenced an offer to exchange (the “Exchange Offer”) for 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 Events

In April 2015, the Partnership filed with the SEC a universal shelf registration statement that allows it 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

Public Offerings of Common Units

As part of the APL mergers, the Partnership issued 58,614,157 common units to former Atlas unitholders as consideration for the APL merger, of which 3,363,935 common units represented ATLS’s common unit ownership in APL, which were issued to us.

In May 2014, the Partnership entered into an additional Equity Distribution Agreement under the July 2013 Shelf (the “May 2014 EDA”), pursuant to which it may sell through its sales agents, at its option, up to an aggregate of $400.0 million of its common units. During the three months ended March 31, 2015, the Partnership 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. We contributed $1.1 million to the Partnership to maintain its 2% general partner interest, of which $0.8 million was received in April 2015.

Subsequent Event

During April 2015, the Partnership issued 2,318,950 common units under the May 2014 EDA, receiving net proceeds of $100.1 million. We contributed $2.1 million to the Partnership to maintain our 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

In accordance with the Partnership Agreement, the Partnership must distribute all of its 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 the Partnership for the three months ended March 31, 2015.

Distributions

Three Months

Date Paid or to

Limited

General Partner

Distributions to

Distributions

Ended

be Paid

Partners

Targa

per limited

Resources

partner unit

Common

Incentive

Total

Corp.

(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

51.6

0.81

Common_Stock_and_Related_Matte

Common Stock and Related Matters

3 Months Ended

Mar. 31, 2015

Common Stock and Related Matters [Abstract]

Common Stock and Related Matters

Note 12 — Common Stock and Related Matters

On February 27, 2015, we issued 10,126,532 shares of our common stock valued at approximately $1.0 billion in exchange for ATLS common units as part of the ATLS merger (based on the $99.58 closing market price of our common shares on the NYSE as of February 27, 2015). In addition, we awarded 81,740 replacement restricted stock units in connection with the ATLS mergers.

Public Offering

During March 2015, we sold, in a public offering, 3,250,000 shares of our common stock under a registration statement on Form S-3 at a price of $91 per share of common stock, providing net proceeds of $292.8 million to us. Pursuant to the exercise of the underwriters’ overallotment option, we also sold an additional 487,500 shares of our common stock, providing additional net proceeds of $43.9 million. The proceeds from this offering were used to repay a portion of the outstanding borrowings under our credit facility and to make a capital contribution of $52.4 million to the Partnership to maintain our 2% general partnership interest in the Partnership and for general corporate purposes.

The following table details the dividends declared and/or paid by us for the three months ended March 31, 2015:

Three Months Ended

Date Paid or To

Total

Amount of

Accrued

Dividend

Be Paid

Dividend

Dividends (1)

Declared per

Declared

Paid

Share of

Common Stock

(In millions, except per share amounts)

31-Mar-15

18-May-15

46.6

46.4

0.2

0.83

31-Dec-14

17-Feb-15

32.6

32.4

0.2

0.775

-1

Represents accrued dividends on restricted stock units that are payable upon vesting.

Dividends declared are recorded as a reduction of retained earnings to the extent that retained earnings was available at the close of the prior quarter, with any excess recorded as a reduction of additional paid-in capital.

Earnings_per_Common_Share

Earnings per Common Share	3 Months Ended
Earnings per Common Share	Mar. 31, 2015
Earnings per Common Share [Abstract]
Earnings per Common Share	Note 13 — Earnings per Common Share

	The following table sets forth a reconciliation of net income and weighted average shares outstanding used in computing basic and diluted net income per common share:

		Three Months Ended March 31,
		2015		2014
	Net income	$	34.6	$	106.9
	Less: Net income attributable to noncontrolling interests		31.4		87.3
	Net income attributable to common shareholders	$	3.2	$	19.6

	Weighted average shares outstanding - basic		45.8		42

	Net income available per common share - basic	$	0.07	$	0.47

	Weighted average shares outstanding		45.8		42
	Dilutive effect of unvested stock awards		0.1		0.1
	Weighted average shares outstanding - diluted		45.9		42.1

	Net income available per common share - diluted	$	0.07	$	0.47

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	3 Months Ended
Derivative Instruments and Hedging Activities	Mar. 31, 2015
Derivative Instruments and Hedging Activities [Abstract]
Derivative Instruments and Hedging Activities	Note 14 — Derivative Instruments and Hedging Activities

	The Partnership’s Commodity Hedges

	The primary purpose of the Partnership’s commodity risk management activities is to manage its exposure to commodity price risk and reduce volatility in its operating cash flow due to fluctuations in commodity prices. The Partnership has hedged the commodity prices associated with a portion of its expected (i) natural gas equity volumes in its Field Gathering and Processing segment and (ii) NGL and condensate equity volumes predominately in its Field Gathering and Processing segment and the LOU business unit in its 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. The Partnership has 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 the Partnership’s physical equity volumes. The Partnership's 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 the Partnership’s 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. The Partnership’s natural gas and NGL hedges are settled using published index prices for delivery at various locations.

	The Partnership hedges a portion of its 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 the Partnership to a market differential risk if the NYMEX futures do not move in exact parity with the sales price of its 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, the Partnership 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 the Partnership’s first quarter 2015 earnings. These crude oil options expire during 2015. Additionally the 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 the Partnership’s 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

	The Partnership also enters into derivative instruments to help manage other short-term commodity-related business risks. The Partnership has not designated these derivatives as hedges and records changes in fair value and cash settlements to revenues.

	The Partnership’s 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
	31-Mar-15		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				-				72.0				-
	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			103.7				-				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

The Partnership’s payment obligations in connection with substantially all of these hedging transactions are secured by a first priority lien in the collateral securing its senior secured indebtedness that ranks equal in right of payment with liens granted in favor of its senior secured lenders.

The fair value of the Partnership’s 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 the Partnership’s 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		Three Months Ended March 31,
Hedging Relationships		2015				2014
Commodity contracts		$	25.2			$	(11.8	)

		Gain (Loss) Reclassified from OCI into Income (Effective Portion)
		Three Months Ended March 31,
Location of Gain (Loss)			2015				2014
Interest expense, net		$	-			$	(1.3	)
Revenues			8.1				(6.3	)
		$	8.1			$	(7.6	)

Our consolidated earnings are also affected by the Partnership’s 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		Location of Gain Recognized in		31-Mar-15				31-Mar-14
Hedging Instruments		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 before income taxes through the end of 2017 based on year-end valuations.

	31-Mar-15				31-Dec-14
Commodity hedges, before tax (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 15 for additional disclosures related to derivative instruments and hedging activities.

Fair_Value_Measurements

Fair Value Measurements	3 Months Ended
Fair Value Measurements	Mar. 31, 2015
Fair Value Measurements [Abstract]
Fair Value Measurements	Note 15 — 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

	The Partnership’s derivative instruments consist of financially settled commodity swaps and option contracts and fixed-price commodity contracts with certain counterparties. The Partnership determines the fair value of its derivative contracts using present value methods or standard option valuation models with assumptions about commodity prices based on those observed in underlying markets. The Partnership has consistently applied these valuation techniques in all periods presented and we believe the Partnership has obtained the most accurate information available for the types of derivative contracts the Partnership holds.

	The fair values of the Partnership’s 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 the Partnership expects to receive or pay in the future on its 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 Partnership’s senior secured revolving credit facilities and the Partnership’s accounts receivable securitization facility (“Securitization Facility”) are based on carrying value, which approximates fair value as their 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			Fair Value
			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			170.7			170.7		-		-		-
	TRC Senior secured revolving credit facility			460			460		-		460		-
	TRC Term Loan			237.8			243.1		-		243.1		-
	Partnership's Senior secured revolving credit facility			840			840		-		840		-
	Partnership's Senior unsecured notes			4,300.40			4,384.90		-		4,384.90		-
	Partnership's accounts receivable securitization facility			197.9			197.9		197.9		-		-


	-1	The fair value of the derivative contracts in this table is presented on a different basis than the Consolidated Balance Sheets presentation as disclosed in Note 14. 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 the Partnership’s 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, the Partnership had 13 commodity swaps and option contracts categorized as Level 3. The significant unobservable inputs used in the fair value measurements of the Partnership’s 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 gain 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.

Contingencies

Contingencies	3 Months Ended
Contingencies	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 since been voluntarily dismissed.

	The Atlas Lawsuit Plaintiffs alleged 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 alleged 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 allege 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 allege 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
Supplemental Cash Flow Information	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)		$	31.4	$	23.7
	Income taxes paid, net of refunds			0.8		0.1
	Non-cash Investing and Financing balance sheet movements:
	Deadstock commodity inventories transferred to property, plant and equipment			-		1.1
	Accrued dividends on unvested equity awards			0.5		0.2
	Receivables from equity issuances			24.8		5.9
	Capital expenditure accruals			30.9		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 the 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
Segment Information	Mar. 31, 2015
Segment Information [Abstract]
Segment Information	Note 18 — Segment Information

	The Partnership reports its 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 its hedging activities on reported profits are reported in Other.

	The Partnership’s 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.

	The Partnership’s Logistics and Marketing division is also referred to as its Downstream Business. The Partnership’s 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 the Partnership’s other operations, including services to LPG exporters, as well as transporting natural gas and NGLs.

	The Partnership’s 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 the Partnership’s Gathering and Processing segments and are predominantly located in Mont Belvieu, and Galena Park, Texas and Lake Charles, Louisiana.

	The Partnership’s 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 the Partnership’s 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 the Partnership from its 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 the Partnership’s 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 both the merger and integrations effort of the Atlas mergers.

	Reportable segment information is shown in the following tables. We have segregated the following segment information between Partnership and non-Partnership activities.

			Three Months Ended March 31, 2015
			Partnership
			Field			Coastal			Logistics			Marketing			Other				Corporate				Total		TRC Non-			Consolidated
			Gathering			Gathering			Assets			and							and				Partnership		Partnership
			and			and						Distribution							Eliminations
			Processing			Processing
	Revenues
	Sales of commodities		$	168		$	52.7		$	27.4		$	1,132.30		$	21.7			$	0.1			$	1,402.20	$	-		$	1,402.20
	Fees from midstream services			63.3			8.8			87.7			117.7			-				-				277.5		-			277.5
				231.3			61.5			115.1			1,250.00			21.7				0.1				1,679.70		-			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	$	-		$	1,679.70
	Operating margin		$	79.3		$	7.8		$	125.4		$	65.9		$	21.7			$	-			$	-	$	(0.1	)	$	300
	Other financial information:
	Segment assets (1)		$	7,262.80		$	352.9		$	1,764.60		$	487		$	177.3			$	1,786.60			$	11,831.20	$	185.7		$	12,016.90
	Special GP
	interest (2)
	Goodwill			628.5			-			-			-			-				-				628.5		-			628.5
	Intangible assets			979.9			-			-			-			-				-				979.9		-			979.9
	Total assets		$	8,871.20		$	352.9		$	1764.6		$	487		$	177.3			$	1786.6			$	13,439.60		185.7		$	13,625.30
	Capital expenditures		$	94.4		$	1.1		$	57.7		$	3		$	-			$	1.1			$	157.3	$	-		$	157.3
	Business acquisitions		$	5,047.80		$	-		$	-		$	-		$	-			$	-			$	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 the preliminary acquisition fair value attributable to goodwill and intangible assets associated with the Atlas mergers.

			Three Months Ended March 31, 2014
			Partnership
			Field			Coastal			Logistics			Marketing			Other				Corporate				TRC Non-			Consolidated
			Gathering			Gathering			Assets			and							and				Partnership
			and			and						Distribution							Eliminations
			Processing			Processing
	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			$	78.9		$	6,055.20
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		$	275.3
Depreciation and amortization expense			(119.6	)		(79.6	)
General and administrative expense			(42.6	)		(38.0	)
Interest expense, net			(55.0	)		(33.9	)
Other, net			(33.0	)		5.6
Income tax expense			(15.2	)		(22.5	)
Net income		$	34.6		$	106.9

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	3 Months Ended
Significant Accounting Policies (Policies)	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. 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.

	The Partnership evaluates goodwill for impairment at least annually, as of November 30^th for all affected reporting units. The Partnership also evaluates 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. The Partnership 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 the Partnership’s Consolidated Balance Sheets and a goodwill impairment loss on the Partnership’s 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 ASU 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 ASU. 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 $63.8 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
Business Acquisitions (Tables)	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 the Partnership’s acquisition of APL and our 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 this acquisition 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			18.7			83
Consideration Transferred to Acquire ATLS and APL	The following table summarizes the consideration transferred to acquire ATLS and APL:

	Fair Value of Consideration Transferred:
	Cash paid, net of cash acquired (1)
	TRC		$	745.7
	TRP			852.3
	Common shares of TRC			1,008.50
	Replacement restricted stock units awarded (2)			5.2
	Common units of TRP			2,421.10
	Replacement phantom units awarded (2)			15
	Total		$	5,047.80



	-1	Net of cash acquired of $17.2 million, including $7.3 million to be received by us as part of the Atlas mergers, representing the one-time cash payment from the Partnership for the APL common units owned by ATLS. The one-time cash payment was paid by the Partnership in February 2015 and received by us from the transfer agent in April 2015. The receivable from the transfer agent is reflected in Other, net cash flows from investing activities on the Consolidated Statements of Cash Flows as of March 31, 2015.
	-2	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 the 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			6.7
	Current liabilities, less current portion of long-term debt			(234.0	)
	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 preliminary fair value determination		$	4,419.30
	Goodwill		$	628.5

Inventories_Tables

Inventories (Tables)	3 Months Ended
Inventories (Tables)	Mar. 31, 2015
Inventories [Abstract]
Components of Inventories		31-Mar-15		31-Dec-14
	Partnership:
	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
		Targa			TRC Non-			Targa			Targa			TRC			Targa			Estimated
		Resources			Partnership			Resources			Resources			Non-			Resources			Useful Lives
		Partners LP						Corp.			Partners LP			Partnership			Corp.			(In Years)
								Consolidated									Consolidated
	Gathering systems	$	6,113.80		$	-		$	6,113.80		$	2,588.60		$	-		$	2,588.60		5 to 40
	Processing and fractionation facilities		2,924.60			6.6			2,931.20			1,884.10			6.6			1,890.70		5 to 40
	Terminaling and storage facilities		1,043.00			-			1,043.00			1,038.90			-			1,038.90		5 to 25
	Transportation assets		432.9			-			432.9			359			-			359		10 to 25
	Other property, plant and equipment		219.9			0.2			220.1			149.1			0.2			149.3		3 to 40
	Land		101.4			-			101.4			95.6			-			95.6		-
	Construction in progress		782.2			-			782.2			399			-			399		-
	Property, plant and equipment		11,617.80			6.8			11,624.60			6,514.30			6.8			6,521.10
	Accumulated depreciation		(1,784.9	)		(6.7	)		(1,791.6	)		(1,689.7	)		(6.8	)		(1,696.5	)
	Property, plant and equipment, net	$	9,832.90		$	0.1		$	9,833.00		$	4,824.60		$	0		$	4,824.60

	Intangible assets	$	1,716.60		$	-		$	1,716.60		$	681.8		$	-		$	681.8		20
	Accumulated amortization		(114.2	)		-			(114.2	)		(89.9	)		-			(89.9	)
	Intangible assets, net	$	1,602.40		$	-		$	1,602.40		$	591.9		$	-		$	591.9

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
		31-Mar-15
	Beginning of period	$	57.3
	Fair value of ARO acquired with Atlas mergers		4.1
	Change in cash flow estimate		3.7
	Accretion expense		1.3
	End of period	$	66.4

Investment_in_Unconsolidated_A1

Investment in Unconsolidated Affiliates (Tables)	3 Months Ended
Investment in Unconsolidated Affiliates (Tables)	Mar. 31, 2015
Investment in Unconsolidated Affiliate [Abstract]
Activity Related to Investment in Unconsolidated Affiliate	The following table shows the activity related to the Partnership’s investments in unconsolidated affiliates:

			Three Months Ended
			31-Mar-15
	Beginning of period		$	50.2
	Fair value of T2 Joint Ventures			273.7
	Equity earnings (1)			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 the Partnership’s share of cumulative earnings for the three months ended March 31, 2015. Such excess distributions are considered a return of capital and disclosed in cash flows from investing activities in the Consolidated Statements of Cash Flows.

Accounts_Payable_and_Accrued_L1

Accounts Payable and Accrued Liabilities (Tables)	3 Months Ended
Accounts Payable and Accrued Liabilities (Tables)	Mar. 31, 2015
Accounts Payable and Accrued Liabilities [Abstract]
Schedule of Accounts Payable and Accrued Liabilities		31-Mar-15							31-Dec-14
		Targa		TRC Non-			Targa		Targa		TRC Non-			Targa
		Resources		Partnership			Resources		Resources		Partnership			Resources
		Partners LP					Corp.		Partners LP					Corp.
							Consolidated							Consolidated
	Commodities	$	445.8	$	-		$	445.8	$	416.7	$	-		$	416.7
	Other goods and services		169.8		2.9			172.7		108.9		2.2			111.1
	Interest		57		1.3			58.3		37.3		-			37.3
	Compensation and benefits		3.2		18.4			21.6		1.3		44.8			46.1
	Income and other taxes		20		(1.0	)		19		13.6		(1.9	)		11.7
	Other		15		4.4			19.4		14.9		0.7			15.6
		$	710.8	$	26		$	736.8	$	592.7	$	45.8		$	638.5

Debt_Obligations_Tables

Debt Obligations (Tables)	3 Months Ended
Debt Obligations (Tables)	Mar. 31, 2015
Debt Obligations [Abstract]
Schedule of Outstanding Debt			31-Mar-15			31-Dec-14
	Current:
	Partnership
	Accounts receivable securitization facility, due December 2015 (1)		$	197.9		$	182.8
	Long-term:
	Non-Partnership obligations:
	TRC Senior secured revolving credit facility, variable rate, due February 2020 (2)			460			-
	TRC Senior secured term loan, variable rate, due February 2022			242			-
	Unamortized discount			(4.2	)		-
	TRC Senior secured revolving credit facility, variable rate, due October 2017			-			102
	Obligations of the Partnership: (1)
	Senior secured revolving credit facility, variable rate, due October 2017 (3)			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 (4)			355.1			-
	Unamortized premium			6			-
	Senior unsecured notes, 4¾% fixed rate, due November 2021 (4)			6.5			-
	Senior unsecured notes, 5⅞% fixed rate, due August 2023 (4)			48.1			-
	Unamortized premium			0.6			-
	Total long-term debt			5,838.20			2,885.40
	Total debt		$	6,036.10		$	3,068.20
	Irrevocable standby letters of credit:
	Letters of credit outstanding under TRC Senior secured credit facility (2)		$	-		$	-
	Letters of credit outstanding under the Partnership senior secured revolving credit facility (3)			25			44.1
			$	25		$	44.1



	-1	While we consolidate the debt of the Partnership in our financial statements, we do not have the obligation to make interest payments or debt payments with respect to the debt of the Partnership.
	-2	As of March 31, 2015, availability under TRC’s $670 million senior secured revolving credit facility was $210.0 million.
	-3	As of March 31, 2015, availability under the Partnership’s $1.6 billion senior secured revolving credit facility (“TRP Revolver”) was $735.0 million.
	-4	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 variable-rate debt obligations during the three months ended March 31, 2015:

			Range of Interest			Weighted Average
			Rates Incurred			Interest Rate Incurred
	TRC senior secured revolving credit facility			2.9	%		2.9	%
	TRC senior secured term loan			5.75	%		5.75	%
	Partnership's senior secured revolving credit facility			1.9	%		1.9	%
	Partnership's accounts receivable securitization facility			0.9	%		0.9	%
Summary of Results of Tender Offers	The results of the APL Notes Tender Offers were:

	Senior Notes		Outstanding			Amount			Premium		Accrued		Total Tender		% Tendered			Note Balance
			Note Balance			Tendered			Paid		Interest		Offer					after Tender
											Paid		payments					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 the Partnership for the three months ended March 31, 2015.

Distributions

Three Months

Date Paid or to

Limited

General Partner

Distributions to

Distributions

Ended

be Paid

Partners

Targa

per limited

Resources

partner unit

Common

Incentive

Total

Corp.

(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

51.6

0.81

Common_Stock_and_Related_Matte1

Common Stock and Related Matters (Tables)

3 Months Ended

Mar. 31, 2015

Common Stock and Related Matters [Abstract]

Distributions Declared and/or Paid

The following table details the dividends declared and/or paid by us for the three months ended March 31, 2015:

Three Months Ended

Date Paid or To

Total

Amount of

Accrued

Dividend

Be Paid

Dividend

Dividends (1)

Declared per

Declared

Paid

Share of

Common Stock

(In millions, except per share amounts)

31-Mar-15

18-May-15

46.6

46.4

0.2

0.83

31-Dec-14

17-Feb-15

32.6

32.4

0.2

0.775

-1

Represents accrued dividends on restricted stock units that are payable upon vesting.

Earnings_per_Common_Share_Tabl

Earnings per Common Share (Tables)	3 Months Ended
Earnings per Common Share (Tables)	Mar. 31, 2015
Earnings per Common Share [Abstract]
Earnings per Common Share	The following table sets forth a reconciliation of net income and weighted average shares outstanding used in computing basic and diluted net income per common share:

		Three Months Ended March 31,
		2015		2014
	Net income	$	34.6	$	106.9
	Less: Net income attributable to noncontrolling interests		31.4		87.3
	Net income attributable to common shareholders	$	3.2	$	19.6

	Weighted average shares outstanding - basic		45.8		42

	Net income available per common share - basic	$	0.07	$	0.47

	Weighted average shares outstanding		45.8		42
	Dilutive effect of unvested stock awards		0.1		0.1
	Weighted average shares outstanding - diluted		45.9		42.1

	Net income available per common share - diluted	$	0.07	$	0.47

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Tables)	3 Months Ended
Derivative Instruments and Hedging Activities (Tables)	Mar. 31, 2015
Derivative Instruments and Hedging Activities [Abstract]
Notional Volume of Commodity Hedges	At March 31, 2015, the notional volumes of the Partnership’s 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
	31-Mar-15		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				-				72.0			-
	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			103.7				-				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		Three Months Ended March 31,
	Hedging Relationships		2015				2014
	Commodity contracts		$	25.2			$	(11.8	)

			Gain (Loss) Reclassified from OCI into Income (Effective Portion)
			Three Months Ended March 31,
	Location of Gain (Loss)			2015				2014
	Interest expense, net		$	-			$	(1.3	)
	Revenues			8.1				(6.3	)
			$	8.1			$	(7.6	)
Gain (Loss) Recognized in Income on Derivatives					Gain (Loss) Recognized in Income on Derivatives
	Derivatives Not Designated as		Location of Gain Recognized in		31-Mar-15				31-Mar-14
	Hedging Instruments		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 before income taxes through the end of 2017 based on year-end valuations.

		31-Mar-15				31-Dec-14
	Commodity hedges, before tax (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
Fair Value Measurements (Tables)	Mar. 31, 2015
Fair Value Measurements [Abstract]
Breakdown by Fair Value Hierarchy Category for Financial Instruments Included in Consolidated Balance Sheets	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			Fair Value
			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			170.7			170.7		-		-		-
	TRC Senior secured revolving credit facility			460			460		-		460		-
	TRC Term Loan			237.8			243.1		-		243.1		-
	Partnership's Senior secured revolving credit facility			840			840		-		840		-
	Partnership's Senior unsecured notes			4,300.40			4,384.90		-		4,384.90		-
	Partnership's accounts receivable securitization facility			197.9			197.9		197.9		-		-


	-1	The fair value of the derivative contracts in this table is presented on a different basis than the Consolidated Balance Sheets presentation as disclosed in Note 14. 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 gain included in OCI			(1.1	)
	Transfers into Level 3			(0.6	)
	Transfers out of Level 3			(0.1	)
	Balance, March 31, 2015		$	(3.5	)

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	3 Months Ended
Supplemental Cash Flow Information (Tables)	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)		$	31.4	$	23.7
	Income taxes paid, net of refunds			0.8		0.1
	Non-cash Investing and Financing balance sheet movements:
	Deadstock commodity inventories transferred to property, plant and equipment			-		1.1
	Accrued dividends on unvested equity awards			0.5		0.2
	Receivables from equity issuances			24.8		5.9
	Capital expenditure accruals			30.9		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 the three months ended March 31, 2015 and 2014.

Segment_Information_Tables

Segment Information (Tables)	3 Months Ended
Segment Information (Tables)	Mar. 31, 2015
Segment Information [Abstract]
Information by Segment	Reportable segment information is shown in the following tables. We have segregated the following segment information between Partnership and non-Partnership activities.

			Three Months Ended March 31, 2015
			Partnership
			Field			Coastal			Logistics		Marketing		Other			Corporate			Total		TRC Non-			Consolidated
			Gathering			Gathering			Assets		and					and			Partnership		Partnership
			and			and					Distribution					Eliminations
			Processing			Processing
	Revenues
	Sales of commodities		$	168		$	52.7		$	27.4	$	1,132.30	$	21.7		$	0.1		$	1,402.20	$	-		$	1,402.20
	Fees from midstream services			63.3			8.8			87.7		117.7		-			-			277.5		-			277.5
				231.3			61.5			115.1		1,250.00		21.7			0.1			1,679.70		-			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	$	-		$	1,679.70
	Operating margin		$	79.3		$	7.8		$	125.4	$	65.9	$	21.7		$	-		$	-	$	(0.1	)	$	300
	Other financial information:
	Segment assets (1)		$	7,262.80		$	352.9		$	1,764.60	$	487	$	177.3		$	1,786.60		$	11,831.20	$	185.7		$	12,016.90
	Special GP
	interest (2)
	Goodwill			628.5			-			-		-		-			-			628.5		-			628.5
	Intangible assets			979.9			-			-		-		-			-			979.9		-			979.9
	Total assets		$	8,871.20		$	352.9		$	1764.6	$	487	$	177.3		$	1786.6		$	13,439.60		185.7		$	13,625.30
	Capital expenditures		$	94.4		$	1.1		$	57.7	$	3	$	-		$	1.1		$	157.3	$	-		$	157.3
	Business acquisitions		$	5,047.80		$	-		$	-	$	-	$	-		$	-		$	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 the preliminary acquisition fair value attributable to goodwill and intangible assets associated with the Atlas mergers.

			Three Months Ended March 31, 2014
			Partnership
			Field			Coastal			Logistics		Marketing		Other			Corporate			TRC Non-			Consolidated
			Gathering			Gathering			Assets		and					and			Partnership
			and			and					Distribution					Eliminations
			Processing			Processing
	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		$	78.9		$	6,055.20
	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		$	275.3
	Depreciation and amortization expense			(119.6	)		(79.6	)
	General and administrative expense			(42.6	)		(38.0	)
	Interest expense, net			(55.0	)		(33.9	)
	Other, net			(33.0	)		5.6
	Income tax expense			(15.2	)		(22.5	)
	Net income		$	34.6		$	106.9

Basis_of_Presentation_Details

Basis of Presentation (Details)	3 Months Ended
Basis of Presentation (Details)	Mar. 31, 2015
Partnership Ownership Disclosure [Abstract]
General partner ownership interest (in hundredths)	2.00%
Parent's percentage ownership in the general partner of the Partnership	100.00%
Number of Partnership common units owned (in units)	16,309,594
Limited Partner [Member]
Partnership Ownership Disclosure [Abstract]
General partner ownership interest (in hundredths)	9.10%

Significant_Accounting_Policie2

Significant Accounting Policies (Details) (USD $)	Mar. 31, 2015
In Millions, unless otherwise specified	Mar. 31, 2015
Significant Accounting Policies [Abstract]
Unamortized debt issuance costs	$63.80

Business_Acquisitions_Details

Business Acquisitions (Details) (USD $)	0 Months Ended		1 Months Ended		3 Months Ended
	Feb. 27, 2015		Mar. 31, 2015		Mar. 31, 2015		Mar. 31, 2014	Feb. 27, 2015	Dec. 31, 2014
	Feb. 27, 2015		Mar. 31, 2015		Mar. 31, 2015		Mar. 31, 2014	Transaction	Dec. 31, 2014
Business Acquisition [Line Items]
Number of separate legal transactions involved in mergers	2							2
Cash payments related to acquisition					$5,047,800,000
Percentage of general partner's interest maintained (in hundredths)					2.00%
Common units par value (in dollars per share)			$0.00		$0.00				$0.00
Acquisition-related expenses					25,800,000
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					18,700,000		83,000,000
Fair Value of Consideration Transferred [Abstract]
Cash paid, net of cash acquired					1,598,000,000		0
Total	5,047,800,000
Cash acquired from acquisition	17,200,000
Preliminary fair value determination [Abstract]
Trade receivables, net	183,900,000							183,900,000
Other current assets	26,500,000							26,500,000
Assets from risk management activities	102,100,000							102,100,000
Property, plant and equipment	4,944,000,000							4,944,000,000
Investments in unconsolidated affiliates	273,700,000							273,700,000
Intangible assets	1,035,000,000		1,035,000,000		1,035,000,000			1,035,000,000
Other long-term assets	6,700,000							6,700,000
Current liabilities, less current portion of long-term debt	-234,000,000							-234,000,000
Long-term debt	-1,573,800,000							-1,573,800,000
Deferred income tax liabilities, net	-30,200,000							-30,200,000
Other long-term liabilities	-10,700,000							-10,700,000
Noncontrolling interest in subsidiaries	-303,900,000							-303,900,000
Total preliminary fair value determination	4,419,300,000							4,419,300,000
Goodwill	628,500,000		628,500,000	[1],[2]	628,500,000	[1],[2]		628,500,000	0
Trade receivables, gross amount	180,900,000							180,900,000
Contractual receivables included in current receivables	3,000,000							3,000,000
Contractual receivables included in other long term assets	4,500,000							4,500,000
Contractual receivables, gross amount	7,500,000							7,500,000
TRC Non-Partnership [Member]
Business Acquisition [Line Items]
Cash payments related to acquisition					0
Fair Value of Consideration Transferred [Abstract]
Cash paid, net of cash acquired	745,700,000	[3]
Targa Resources Partners LP [Member]
Business Acquisition [Line Items]
Cash payments related to acquisition					5,047,800,000
Fair Value of Consideration Transferred [Abstract]
Cash paid, net of cash acquired	852,300,000	[3]
Restricted Stock Units (RSUs) [Member]
Fair Value of Consideration Transferred [Abstract]
Common shares of TRC	5,200,000	[4]
Preliminary fair value determination [Abstract]
Vesting period of original term					4 years
Number of common units called by replacement equity unit (in shares)			1		1
Dividend payment period					60 days
Restricted Stock Units (RSUs) [Member] \| Vesting Term One [Member]
Preliminary fair value determination [Abstract]
Vesting percentage original term (in hundredths)					25.00%
Restricted Stock Units (RSUs) [Member] \| Vesting Term Two [Member]
Preliminary fair value determination [Abstract]
Vesting percentage original term (in hundredths)					25.00%
Restricted Stock Units (RSUs) [Member] \| Vesting Term Three [Member]
Preliminary fair value determination [Abstract]
Vesting percentage original term (in hundredths)					75.00%
Phantom Units Awards [Member]
Fair Value of Consideration Transferred [Abstract]
Common shares of TRC	15,000,000	[4]
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
Common Stock [Member]
Fair Value of Consideration Transferred [Abstract]
Common shares of TRC	1,008,500,000
Common Stock [Member] \| Targa Resources Partners LP [Member]
Fair Value of Consideration Transferred [Abstract]
Common shares of TRC	2,421,100,000
Atlas Pipeline Partners [Member]
Business Acquisition [Line Items]
Purchase consideration	5,300,000,000
Acquired debt and all other assumed liabilities included in 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							2,600,000,000
Closing market price of common unit (in dollars per share)	$43.82							$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							6,400,000
Contribution made by Targa to maintain general partner's interest	52,400,000
Percentage of general partner's interest maintained (in hundredths)	2.00%
Preliminary fair value determination [Abstract]
Contingent consideration additional amount					6,000,000
Contingent liability acquired in business combination	6,000,000							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] \| 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] \| Class E Preferred Units [Member]
Business Acquisition [Line Items]
Percentage of cumulative redeemable perpetual preferred units (in hundredths)	8.25%
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
Atlas Pipeline Partners [Member] \| Common Units [Member]
Business Acquisition [Line Items]
Cash payments related to acquisition	7,300,000
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							5,754,253
Atlas Pipeline Partners [Member] \| Common Units [Member] \| Targa Resources Partners LP [Member]
Business Acquisition [Line Items]
Total distribution of common shares (in shares)	3,363,935
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]
Percentage of interest in common units (in hundredths)	100.00%							100.00%
Purchase consideration	1,600,000,000
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							1,000,000,000
Closing market price of common unit (in dollars per share)	$99.58							$99.58
Common units par value (in dollars per share)	$0.00							$0.00
Acquisition-related expenses	11,000,000
Reduction in purchase price	-154,700,000
Atlas Energy [Member] \| Phantom Units Awards [Member]
Business Acquisition [Line Items]
Total distribution of common shares (in shares)	81,740
Cash payment related to one-time cash payments and cash settlements of equity awards	4,500,000							4,500,000
Atlas Energy [Member] \| Equity Award Settlements [Member]
Business Acquisition [Line Items]
Cash payments related to acquisition	88,000,000
Atlas Energy [Member] \| Common Units [Member]
Business Acquisition [Line Items]
Total distribution of common shares (in shares)	10,126,532
Common units acquired	147,400,000							147,400,000
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%
Change Of Control Payments [Member]
Business Acquisition [Line Items]
Cash payments related to acquisition	$149,200,000

[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 the preliminary acquisition fair value attributable to goodwill and intangible assets associated with the Atlas mergers.
[3]	Net of cash acquired of $17.2 million, including $7.3 million to be received by us as part of the Atlas mergers, representing the one-time cash payment from the Partnership for the APL common units owned by ATLS. The one-time cash payment was paid by the Partnership in February 2015 and received by us from the transfer agent in April 2015. The receivable from the transfer agent is reflected in Other, net cash flows from investing activities on the Consolidated Statements of Cash Flows as of March 31, 2015.
[4]	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.

Inventories_Details

Inventories (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Partnership:
Commodities	$66.90	$157.40
Materials and supplies	11.3	11.5
Inventories, Net	$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	$11,624.60		$6,521.10
Accumulated depreciation	-1,791.60		-1,696.50
Property, plant and equipment, net	9,833		4,824.60
Finite-Lived Intangible Assets [Line Items]
Intangible assets	1,716.60		681.8
Accumulated amortization	-114.2		-89.9
Intangible assets, net	1,602.40		591.9
Estimated useful lives	20 years
Preliminary 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
Gathering Systems [Member] \| Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Gathering Systems [Member] \| Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	40 years
Processing and Fractionation Facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,931.20		1,890.70
Processing and Fractionation Facilities [Member] \| Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Processing and Fractionation Facilities [Member] \| Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	40 years
Terminaling and Storage Facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,043		1,038.90
Terminaling and Storage Facilities [Member] \| Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	5 years
Terminaling and Storage Facilities [Member] \| Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Transportation Assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	432.9		359
Transportation Assets [Member] \| Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	10 years
Transportation Assets [Member] \| Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	25 years
Other Property, Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	220.1		149.3
Other Property, Plant and Equipment [Member] \| Minimum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	3 years
Other Property, Plant and Equipment [Member] \| Maximum [Member]
Property, Plant and Equipment [Line Items]
Estimated useful lives	40 years
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	782.2		399
Targa Resources Partners LP [Member]
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 [Line Items]
Intangible assets	1,716.60		681.8
Accumulated amortization	-114.2		-89.9
Intangible assets, net	1,602.40		591.9
Targa Resources Partners LP [Member] \| Gathering Systems [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	6,113.80		2,588.60
Targa Resources Partners LP [Member] \| Processing and Fractionation Facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,924.60		1,884.10
Targa Resources Partners LP [Member] \| Terminaling and Storage Facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,043		1,038.90
Targa Resources Partners LP [Member] \| Transportation Assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	432.9		359
Targa Resources Partners LP [Member] \| Other Property, Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	219.9		149.1
Targa Resources Partners LP [Member] \| Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	101.4		95.6
Targa Resources Partners LP [Member] \| Construction in Progress [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	782.2		399
TRC Non Partnership [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	6.8		6.8
Accumulated depreciation	-6.7		-6.8
Property, plant and equipment, net	0.1		0
Finite-Lived Intangible Assets [Line Items]
Intangible assets	0		0
Accumulated amortization	0		0
Intangible assets, net	0		0
TRC Non Partnership [Member] \| Gathering Systems [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	0		0
TRC Non Partnership [Member] \| Processing and Fractionation Facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	6.6		6.6
TRC Non Partnership [Member] \| Terminaling and Storage Facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	0		0
TRC Non Partnership [Member] \| Transportation Assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	0		0
TRC Non Partnership [Member] \| Other Property, Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	0.2		0.2
TRC Non Partnership [Member] \| Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	0		0
TRC Non Partnership [Member] \| Construction in Progress [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$0		$0

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	$57.30
Fair value of ARO acquired with Atlas mergers	4.1
Change in cash flow estimate	3.7	2.1
Accretion expense	1.3	1.2
End of period	$66.40

Investment_in_Unconsolidated_A2

Investment in Unconsolidated Affiliates (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014	Dec. 31, 2014
	JointVenture		Mar. 31, 2014	Dec. 31, 2014
Equity Method Investments [Line Items]
Number of non-operated joint ventures	3
Beginning of period	$50.20
Fair value of T2 Joint Ventures	273.7
Equity earnings	1.7	[1]	4.9
Cash distributions	-2.7	[2]
End of period	322.9
Return of capital from unconsolidated affiliate	0.6		2.2
Basis difference on preliminary fair values	$99.10
Preliminary estimated useful lives of the underlying assets	20 years
Gulf Coast Fractionators LP [Member]
Equity Method Investments [Line Items]
Ownership interest (in hundredths)	38.80%			38.80%
T2 LaSalle [Member]
Equity Method Investments [Line Items]
Percentage of equity interest (in hundredths)	75.00%
T2 Eagle Ford [Member]
Equity Method Investments [Line Items]
Percentage of equity interest (in hundredths)	50.00%
T2 EF Co-Gen [Member]
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 the Partnership's share of cumulative earnings for the three months ended March 31, 2015. Such excess distributions are considered a return of capital and disclosed in cash flows from investing activities in the Consolidated Statements of Cash Flows.

Accounts_Payable_and_Accrued_L2

Accounts Payable and Accrued Liabilities (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Components of accounts payable and accrued liabilities [Abstract]
Commodities	$445.80	$416.70
Other goods and services	172.7	111.1
Interest	58.3	37.3
Compensation and benefits	21.6	46.1
Income and other taxes	19	11.7
Other	19.4	15.6
Accounts payable and accrued liabilities	736.8	638.5
Targa Resources Partners LP [Member]
Components of accounts payable and accrued liabilities [Abstract]
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
Accounts payable and accrued liabilities	710.8	592.7
TRC Non Partnership [Member]
Components of accounts payable and accrued liabilities [Abstract]
Commodities	0	0
Other goods and services	2.9	2.2
Interest	1.3	0
Compensation and benefits	18.4	44.8
Income and other taxes	-1	-1.9
Other	4.4	0.7
Accounts payable and accrued liabilities	$26	$45.80

Debt_Obligations_Details

Debt Obligations (Details) (USD $)	3 Months Ended			0 Months Ended		1 Months Ended	0 Months Ended
Debt Obligations (Details) (USD $)	Mar. 31, 2015		Mar. 31, 2014	Feb. 27, 2015	Apr. 27, 2015	Jan. 31, 2015	Jan. 31, 2015	Dec. 31, 2014		Apr. 13, 2015	Apr. 30, 2015
Current Partnership [Abstract]
Long-term debt	$5,838,200,000							$2,885,400,000
Total debt	6,036,100,000							3,068,200,000
Letters of credit outstanding	25,000,000							44,100,000
Range of interest rates and weighted average interest rate [Abstract]
Net proceeds from issuance of senior notes	1,100,000,000		0
Cash payments related to acquisition	5,047,800,000
Atlas Energy [Member]
Range of interest rates and weighted average interest rate [Abstract]
Cash payments related to acquisition				514,700,000
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
Results of tender offers [Abstract]
Amount Tendered and Paid	1,200,000,000
TRC Senior Secured Term Loan due February 2022 [Member]
Current Partnership [Abstract]
Long-term debt	242,000,000							0
Unamortized discount	-4,200,000							0
Maturity date	28-Feb-22
TRC Senior Secured Revolving Credit Facility due 2017 [Member]
Current Partnership [Abstract]
Long-term debt	0							102,000,000
Maturity date	31-Oct-17
Senior Unsecured 6 5/8% Notes due October 2020 [Member] \| Atlas Pipeline Partners [Member] \| Subsequent Event [Member]
Results of tender offers [Abstract]
Outstanding Note Balance										355,100,000
Amount Tendered and Paid					341,900,000
Tendered percentage (in hundredths)					96.30%
Note Balance after Tender Offers										355,100,000
Senior Secured Credit Facility [Member]
Range of interest rates and weighted average interest rate [Abstract]
Range of Interest Rates Incurred (in hundredths)	2.90%
Weighted Average Interest Rate Incurred (in hundredths)	2.90%
Senior Secured Term Loan [Member]
Range of interest rates and weighted average interest rate [Abstract]
Range of Interest Rates Incurred (in hundredths)	5.75%
Weighted Average Interest Rate Incurred (in hundredths)	5.75%
Senior Secured Term Loan [Member] \| TRC Credit Agreement [Member]
Range of interest rates and weighted average interest rate [Abstract]
Expiration period for credit facility	7 years
Aggregate principal amount	430,000,000
Cash payment related to change of control payments	160,000,000
Repayment of term loan	188,000,000
Write off of debt discount	3,300,000
Write off of debt issuance cost	5,700,000
Shelf Offering April 2015 Shelf [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] \| TRC Credit Agreement [Member]
Range of interest rates and weighted average interest rate [Abstract]
Expiration period for credit facility	5 years
Aggregate principal amount	670,000,000
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] \| TRC Senior Secured Revolving Credit Facility due February 2020 [Member]
Current Partnership [Abstract]
Long-term debt	460,000,000	[1]						0	[1]
Maturity date	29-Feb-20
Revolving Credit Facility [Member] \| TRC Senior Secured Revolving Credit Facility due 2017 [Member]
Current Partnership [Abstract]
Letters of credit outstanding	0	[1]						0	[1]
Maximum borrowing capacity	670,000,000
Remaining borrowing capacity	210,000,000
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] \| Atlas Pipeline Partners [Member]
Results of tender offers [Abstract]
Amount Tendered and Paid						1,168,800,000
APL Senior Notes Tender Offers [Member] \| Senior Unsecured 6 5/8% 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 4 3/4% 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 5 7/8% 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 6 5/8% 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
Targa Resources Partners LP [Member]
Range of interest rates and weighted average interest rate [Abstract]
Cash payments related to acquisition	5,047,800,000
Targa Resources Partners LP [Member] \| Senior Secured Credit Facility [Member]
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%
Targa Resources Partners LP [Member] \| Revolving Credit Facility [Member] \| TRP Senior Secured Revolving Credit Facility due 2017 [Member]
Current Partnership [Abstract]
Long-term debt	840,000,000	[2],[3]						0	[2],[3]
Maturity date	31-Oct-17
Letters of credit outstanding	25,000,000	[3]						44,100,000	[3]
Maximum borrowing capacity	1,600,000,000
Remaining borrowing capacity	735,000,000
Targa Resources Partners LP [Member] \| Revolving Credit Facility [Member] \| First Amendment [Member]
Current Partnership [Abstract]
Maximum borrowing capacity				1,600,000,000		1,200,000,000	1,200,000,000
Range of interest rates and weighted average interest rate [Abstract]
Additional commitment increase available upon request				300,000,000		300,000,000	300,000,000
Targa Resources Partners LP [Member] \| Senior Unsecured Notes [Member] \| Senior Unsecured 5% Notes due January 2018 [Member]
Current Partnership [Abstract]
Long-term debt	1,100,000,000	[2]						0	[2]
Interest rate on fixed rate debt (in hundredths)	5.00%
Maturity date	31-Jan-18
Range of interest rates and weighted average interest rate [Abstract]
Aggregate principal amount						1,100,000,000	1,100,000,000
Net proceeds from issuance of senior notes							1,089,800,000
Targa Resources Partners LP [Member] \| Senior Unsecured Notes [Member] \| Senior Unsecured 6 7/8% Notes due February 2021 [Member]
Current Partnership [Abstract]
Long-term debt	483,600,000	[2]						483,600,000	[2]
Unamortized discount	-24,500,000	[2]						-25,200,000	[2]
Interest rate on fixed rate debt (in hundredths)	6.88%
Maturity date	28-Feb-21
Targa Resources Partners LP [Member] \| Senior Unsecured Notes [Member] \| Senior Unsecured 6 3/8% Notes due August 2022 [Member]
Current Partnership [Abstract]
Long-term debt	300,000,000	[2]						300,000,000	[2]
Interest rate on fixed rate debt (in hundredths)	6.38%
Maturity date	31-Aug-22
Targa Resources Partners LP [Member] \| Senior Unsecured Notes [Member] \| Senior Unsecured 5 1/4% Notes due May 2023 [Member]
Current Partnership [Abstract]
Long-term debt	600,000,000	[2]						600,000,000	[2]
Interest rate on fixed rate debt (in hundredths)	5.25%
Maturity date	31-May-23
Targa Resources Partners LP [Member] \| Senior Unsecured Notes [Member] \| Senior Unsecured 4 1/4% Notes due November 2023 [Member]
Current Partnership [Abstract]
Long-term debt	625,000,000	[2]						625,000,000	[2]
Interest rate on fixed rate debt (in hundredths)	4.25%
Maturity date	30-Nov-23
Targa Resources Partners LP [Member] \| Senior Unsecured Notes [Member] \| Senior Unsecured 4 1/8% notes due November 2019 [Member]
Current Partnership [Abstract]
Long-term debt	800,000,000	[2]						800,000,000	[2]
Interest rate on fixed rate debt (in hundredths)	4.13%
Maturity date	30-Nov-19
Targa Resources Partners LP [Member] \| Senior Unsecured Notes [Member] \| Senior Unsecured 6 5/8% Notes due October 2020 [Member]
Current Partnership [Abstract]
Long-term debt	355,100,000	[2],[4]						0	[2],[4]
Unamortized premium	6,000,000	[2]						0	[2]
Interest rate on fixed rate debt (in hundredths)	6.63%
Maturity date	31-Oct-20
Targa Resources Partners LP [Member] \| Senior Unsecured Notes [Member] \| Senior Unsecured 4 3/4% Notes due November 2021 [Member]
Current Partnership [Abstract]
Long-term debt	6,500,000	[2],[4]						0	[2],[4]
Interest rate on fixed rate debt (in hundredths)	4.75%
Maturity date	30-Nov-21
Targa Resources Partners LP [Member] \| Senior Unsecured Notes [Member] \| Senior Unsecured 5 7/8% Notes due August 2023 [Member]
Current Partnership [Abstract]
Long-term debt	48,100,000	[2],[4]						0	[2],[4]
Unamortized premium	600,000	[2],[4]						0	[2],[4]
Interest rate on fixed rate debt (in hundredths)	5.88%
Maturity date	31-Aug-23
Targa Resources Partners LP [Member] \| APL Senior Notes Tender Offers [Member] \| Senior Unsecured 6 5/8% 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	1,010
Targa Resources Partners LP [Member] \| Accounts Receivable Securitization Facility [Member]
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%
Targa Resources Partners LP [Member] \| Accounts Receivable Securitization Facility [Member] \| Accounts Receivable Securitization Facility due December 2015 [Member]
Current Partnership [Abstract]
Current debt	$197,900,000	[2]						$182,800,000	[2]
Maturity date	31-Dec-15

[1]	As of March 31, 2015, availability under TRC's $670 million senior secured revolving credit facility was $210.0 million.
[2]	While we consolidate the debt of the Partnership in our financial statements, we do not have the obligation to make interest payments or debt payments with respect to the debt of the Partnership.
[3]	As of March 31, 2015, availability under the Partnership's $1.6 billion senior secured revolving credit facility ("TRP Revolver") was $735.0 million.
[4]	(4) 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
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014	Feb. 27, 2015	Apr. 30, 2015
Partnership Equity [Abstract]
General partner ownership interest (in hundredths)	2.00%
Number of days from end of each quarter by when cash is distributed to unit holders	45 days
Distributions Declared [Member]
Partnership Equity [Abstract]
Date paid or to be paid	15-May-15
Distributions to limited partners common	148.3
Distributions to general partners (Incentive distribution rights)	41.7
Distributions to general partner (2%)	3.9
Total distributions to general and limited partners	193.9
Distributions to Targa Resources Corp.	59
Distributions per limited partner unit (in dollars per unit)	0.82
Distributions Paid [Member]
Partnership Equity [Abstract]
Date paid or to be paid		13-Feb-15
Distributions to limited partners common		96.3
Distributions to general partners (Incentive distribution rights)		38.4
Distributions to general partner (2%)		2.7
Total distributions to general and limited partners		137.4
Distributions to Targa Resources Corp.		51.6
Distributions per limited partner 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 ownership 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
May 2014 EDA [Member]
Partnership Equity [Abstract]
Number of common units included in public offerings (in shares)	1,271,876
Dollar amount of common units able to sell from equity distribution agreement	400
Net proceeds from public offering	53
Commissions to sales agents, maximum (in hundredths)	1.00%
Amount contributed to maintain general partner ownership percentage	1.1
General partner ownership interest (in hundredths)	2.00%
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				100.1
Net proceeds from public offering				24.8
Amount contributed to maintain general partner ownership percentage				2.1
Amount received to maintain general partner ownership percentage				0.8
General partner ownership interest (in hundredths)				2.00%
Amount which remain available under the shelf agreement				$4.20

Common_Stock_and_Related_Matte2

Common Stock and Related Matters (Details) (USD $)	3 Months Ended					1 Months Ended		0 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014	Dec. 31, 2014		Mar. 31, 2015		Feb. 27, 2015
Common Stock, Number of Shares, Par Value and Other Disclosures [Abstract]
Value of shares issued in exchange for ATLS common units	$0.10			$0		$0.10
Common stock closing market price (in dollars per share)								$99.58
Dividends Payable [Line Items]
Amount of dividend paid	32.4		25.5
Dividend Declared, Q1 2015 [Member]
Dividends Payable [Line Items]
Date paid or to be paid	18-May-15
Total dividend declared	46.6
Amount of dividend paid	46.4
Accrued dividends	0.2	[1]				0.2	[1]
Dividend declared per share of common stock (in dollars per share)	$0.83
Dividend Declared, Q4 2014 [Member]
Dividends Payable [Line Items]
Date paid or to be paid				17-Feb-15
Total dividend declared				32.6
Amount of dividend paid				32.4
Accrued dividends				0.2	[1]
Dividend declared per share of common stock (in dollars per share)				$0.78
Common Stock [Member]
Common Stock, Number of Shares, Par Value and Other Disclosures [Abstract]
Number of shares issued in public offering (in shares)	3,738,000					3,250,000
Common stock issued price per share (in dollars per share)	$91					$91
Common stock net proceeds of public offering						292.8
Number of additional shares sold in public offering (in shares)						487,500
Additional net proceeds from public offering pursuant to exercise of underwriters' overallotment option						43.9
Payments to capital contribution in partnership						52.4
General partnership interest (in hundredths)						2.00%
Atlas Energy [Member]
Common Stock, Number of Shares, Par Value and Other Disclosures [Abstract]
Number of shares issued in exchange for ATLS common units (in shares)								10,126,532
Value of shares issued in exchange for ATLS common units								$1,000
Replacement restricted stock units (in shares)								81,740

[1]	Represents accrued dividends on restricted stock units that are payable upon vesting.

Earnings_per_Common_Share_Deta

Earnings per Common Share (Details) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Earnings per Common Share [Abstract]
Net income	$34.60	$106.90
Less: Net income attributable to noncontrolling interests	31.4	87.3
Net income attributable to common shareholders	$3.20	$19.60
Weighted average shares outstanding - basic (in shares)	45.8	42
Net income available per common share - basic (in dollars per share)	$0.07	$0.47
Weighted average shares outstanding (in shares)	45.8	42
Dilutive effect of unvested stock awards (in shares)	0.1	0.1
Weighted average shares outstanding - diluted (in shares)	45.9	42.1
Net income available per common share - diluted (in dollars per share)	$0.07	$0.47

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 derivative assets	$174.80
Atlas Pipeline Partners [Member]
Derivative Line [Items]
Fair value of derivative assets		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] \| Year 2015 [Member] \| Natural Gas [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (MMBtu per day)	125,439
Swaps [Member] \| Year 2015 [Member] \| NGL [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (Bbl per day)	5,928
Swaps [Member] \| Year 2015 [Member] \| Condensate [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (Bbl per day)	1,991
Swaps [Member] \| Year 2016 [Member] \| Natural Gas [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (MMBtu per day)	68,205
Swaps [Member] \| Year 2016 [Member] \| NGL [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (Bbl per day)	2,254
Swaps [Member] \| Year 2016 [Member] \| Condensate [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (Bbl per day)	1,082
Swaps [Member] \| Year 2017 [Member] \| Natural Gas [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (MMBtu per day)	23,082
Swaps [Member] \| Year 2017 [Member] \| NGL [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (Bbl per day)	658
Swaps [Member] \| Year 2017 [Member] \| Condensate [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (Bbl per day)	500
Basis Swaps [Member] \| Year 2015 [Member] \| Natural Gas [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (MMBtu per day)	23,782
Basis Swaps [Member] \| Year 2016 [Member] \| Natural Gas [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (MMBtu per day)	0
Basis Swaps [Member] \| Year 2017 [Member] \| Natural Gas [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (MMBtu per day)	0
Options [Member] \| Crude Oil [Member] \| Atlas Pipeline Partners [Member]
Derivative Line [Items]
Fair value of outstanding derivative contracts		$7.70
Options [Member] \| Year 2015 [Member] \| NGL [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (Bbl per day)	899
Options [Member] \| Year 2015 [Member] \| Condensate [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (Bbl per day)	1,198
Options [Member] \| Year 2016 [Member] \| NGL [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (Bbl per day)	790
Options [Member] \| Year 2016 [Member] \| Condensate [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (Bbl per day)	380
Options [Member] \| Year 2017 [Member] \| NGL [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (Bbl per day)	790
Options [Member] \| Year 2017 [Member] \| Condensate [Member]
Derivative Line [Items]
Notional volumes of commodity hedges (Bbl per day)	380

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	Mar. 31, 2015	Dec. 31, 2014
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] \| Current Assets from Risk Management Activities [Member]
Derivatives, Fair Value [Line Items]
Derivative assets	8.2	0
Not Designated as Hedging Instrument [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	Mar. 31, 2015		Dec. 31, 2014
Derivative Asset [Abstract]
Pro forma net presentation, asset	$174.80
Gross asset	177.2		60.2
Pro forma net presentation, asset, total	174.8	[1]	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

[1]	The fair value of the derivative contracts in this table is presented on a different basis than the Consolidated Balance Sheets presentation as disclosed in Note 14. 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.

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	Mar. 31, 2015		Dec. 31, 2014
Derivative Liability [Abstract]
Gross liability	$2.40		$5.20
Pro forma net presentation, liability, total	0	[1]	0.8
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

[1]	The fair value of the derivative contracts in this table is presented on a different basis than the Consolidated Balance Sheets presentation as disclosed in Note 14. 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.

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 losses 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, before tax	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
	Swap		Dec. 31, 2014
Fair Value Measurements [Abstract]
Derivative 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
Number of natural gas basis swaps categorized as Level 3	13
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]
Assets from commodity derivative contracts	174.8	[1]	55.8
Liabilities from commodity derivative contracts	0	[1]	0.8
Commodity Derivative Contracts (Asset) / Liability [Member]
Fair Value, Liabilities/Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance, beginning of period	-1.7
Settlements included in Revenue	0
Unrealized gain included in OCI	-1.1
Transfers into Level 3	-0.6
Transfers out of Level 3	-0.1
Balance, end of period	-3.5
Level 1 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]
Assets from commodity derivative contracts	0	[1]
Liabilities from commodity derivative contracts	0	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Cash and cash equivalents	0
Level 1 [Member] \| TRC Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Level 1 [Member] \| Senior Secured Term Loan [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Level 1 [Member] \| Partnership's Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Level 1 [Member] \| Partnership's Senior Unsecured Notes [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Level 1 [Member] \| Partnership's Accounts Receivable Securitization Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	197.9
Level 2 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]
Assets from commodity derivative contracts	172.9	[1]
Liabilities from commodity derivative contracts	1.6	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Cash and cash equivalents	0
Level 2 [Member] \| TRC Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	460
Level 2 [Member] \| Senior Secured Term Loan [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	243.1
Level 2 [Member] \| Partnership's Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	840
Level 2 [Member] \| Partnership's Senior Unsecured Notes [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	4,384.90
Level 2 [Member] \| Partnership's Accounts Receivable Securitization Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Level 3 [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]
Assets from commodity derivative contracts	4.3	[1]
Liabilities from commodity derivative contracts	0.8	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Cash and cash equivalents	0
Level 3 [Member] \| TRC Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Level 3 [Member] \| Senior Secured Term Loan [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Level 3 [Member] \| Partnership's Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Level 3 [Member] \| Partnership's Senior Unsecured Notes [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Level 3 [Member] \| Partnership's Accounts Receivable Securitization Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	0
Carrying Value [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]
Assets from commodity derivative contracts	177.2	[1]
Liabilities from commodity derivative contracts	2.4	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Cash and cash equivalents	170.7
Carrying Value [Member] \| TRC Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	460
Carrying Value [Member] \| Senior Secured Term Loan [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	237.8
Carrying Value [Member] \| Partnership's 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] \| Partnership's 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] \| Partnership's 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]
Liabilities from commodity derivative contracts	2.4	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Cash and cash equivalents	170.7
Fair Value [Member] \| TRC Senior Secured Revolving Credit Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	460
Fair Value [Member] \| Senior Secured Term Loan [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	243.1
Fair Value [Member] \| Partnership's 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] \| Partnership's 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] \| Partnership's Accounts Receivable Securitization Facility [Member]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]
Long-term debt	$197.90

[1]	The fair value of the derivative contracts in this table is presented on a different basis than the Consolidated Balance Sheets presentation as disclosed in Note 14. 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.

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	5
Atlas Energy [Member]
Loss Contingencies [Line Items]
Number of public unitholders		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	$31.40	[1]	$23.70	[1]
Income taxes paid, net of refunds	0.8		0.1
Non-cash Investing and Financing balance sheet movements [Abstract]
Deadstock commodity inventories transferred to property, plant and equipment	0		1.1
Accrued dividends on unvested equity awards	0.5		0.2
Receivables from equity issuances	24.8		5.9
Capital expenditure accruals	30.9		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 the 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		Mar. 31, 2014	Feb. 27, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Number of divisions	2
Sale 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		275.3
Special GP interest [Abstract]
Goodwill	628.5	[1],[2]		628.5	0
Intangible assets	1,602.40	[2]			591.9
Total assets	13,625.30	[1]	6,055.20		6,453.50
Capital expenditures	157.3		175.4
Business acquisitions	5,047.80
Special GP Interest [Member]
Special GP interest [Abstract]
Goodwill	628.5	[2]
Intangible assets	979.9	[2]
Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Revenues	1,679.70
Operating margin	0
Special GP interest [Abstract]
Total assets	13,439.60	[1]
Capital expenditures	157.3
Business acquisitions	5,047.80
Targa Resources Partners LP [Member] \| Special GP Interest [Member]
Special GP interest [Abstract]
Goodwill	628.5	[2]
Intangible assets	979.9	[2]
TRC Non-Partnership [Member]
Segment Reporting Information [Line Items]
Revenues	0		0
Operating margin	-0.1		0
Special GP interest [Abstract]
Total assets	185.7		78.9
Capital expenditures	0		0
Business acquisitions	0
TRC Non-Partnership [Member] \| Special GP Interest [Member]
Special GP interest [Abstract]
Goodwill	0	[2]
Intangible assets	0	[2]
Reportable Segments [Member]
Special GP interest [Abstract]
Total assets	12,016.90	[1]
Reportable Segments [Member] \| Targa Resources Partners LP [Member]
Special GP interest [Abstract]
Total assets	11,831.20	[1]
Reportable Segments [Member] \| TRC Non-Partnership [Member]
Special GP interest [Abstract]
Total assets	185.7	[1]
Gathering and Processing [Member]
Segment Reporting Information [Line Items]
Number of reportable segments per division	2
Field Gathering and Processing [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Revenues	448.7		488.1
Operating margin	79.3		94.1
Special GP interest [Abstract]
Total assets	8,870.20
Coastal Gathering and Processing [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [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] \| Targa Resources Partners LP [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] \| Targa Resources Partners LP [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] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Revenues	21.7		-6.1
Operating margin	21.7		-6.1
Special GP interest [Abstract]
Total assets	177.3
Corporate and Eliminations [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Revenues	-436.5		-783.5
Operating margin	0		0
Special GP interest [Abstract]
Total assets	1,787.60
Operating Segments [Member]
Segment Reporting Information [Line Items]
Sale of commodities	1,402.20		2,085.10
Fees from midstream services	277.5		209.6
Revenues	1,679.70		2,294.70
Operating Segments [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale of commodities	1,402.20
Fees from midstream services	277.5
Revenues	1,679.70
Operating Segments [Member] \| TRC Non-Partnership [Member]
Segment Reporting Information [Line Items]
Sale of commodities	0		0
Fees from midstream services	0		0
Revenues	0		0
Operating Segments [Member] \| Field Gathering and Processing [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale of commodities	168		45.8
Fees from midstream services	63.3		40.8
Revenues	231.3		86.6
Special GP interest [Abstract]
Total assets	7,261.80	[1]	3,275.10
Capital expenditures	94.4		98.9
Business acquisitions	5,047.80
Operating Segments [Member] \| Field Gathering and Processing [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member] \| Special GP Interest [Member]
Special GP interest [Abstract]
Goodwill	628.5
Intangible assets	979.9
Operating Segments [Member] \| Coastal Gathering and Processing [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale 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	[1]	385.1
Capital expenditures	1.1		4.3
Business acquisitions	0
Operating Segments [Member] \| Coastal Gathering and Processing [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member] \| Special GP Interest [Member]
Special GP interest [Abstract]
Goodwill	0
Intangible assets	0
Operating Segments [Member] \| Logistics Assets [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale 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	[1]	1,568.70
Capital expenditures	57.7		68.6
Business acquisitions	0
Operating Segments [Member] \| Logistics Assets [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member] \| Special GP Interest [Member]
Special GP interest [Abstract]
Goodwill	0
Intangible assets	0
Operating Segments [Member] \| Marketing and Distribution [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale 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	[1]	614.1
Capital expenditures	3		3.1
Business acquisitions	0
Operating Segments [Member] \| Marketing and Distribution [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member] \| Special GP Interest [Member]
Special GP interest [Abstract]
Goodwill	0
Intangible assets	0
Operating Segments [Member] \| Other Segment [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale of commodities	21.7		-6.1
Fees from midstream services	0		0
Revenues	21.7		-6.1
Special GP interest [Abstract]
Total assets	177.3	[1]	4.5
Capital expenditures	0		0
Business acquisitions	0
Operating Segments [Member] \| Other Segment [Member] \| Targa Resources Partners LP [Member] \| Special GP Interest [Member]
Special GP interest [Abstract]
Goodwill	0
Intangible assets	0
Operating Segments [Member] \| Corporate and Eliminations [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale of commodities	0.1		-0.1
Fees from midstream services	0		0.2
Revenues	0.1		0.1
Special GP interest [Abstract]
Total assets	1,787.60	[1]	128.8
Capital expenditures	1.1		0.5
Business acquisitions	0
Operating Segments [Member] \| Corporate and Eliminations [Member] \| Targa Resources Partners LP [Member] \| Special GP Interest [Member]
Special GP interest [Abstract]
Goodwill	0
Intangible assets	0
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Sale of commodities	0		0
Fees from midstream services	0		0
Revenues	0		0
Intersegment Eliminations [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale of commodities	0
Fees from midstream services	0
Revenues	0
Intersegment Eliminations [Member] \| TRC Non-Partnership [Member]
Segment Reporting Information [Line Items]
Sale of commodities	0		0
Fees from midstream services	0		0
Revenues	0		0
Intersegment Eliminations [Member] \| Field Gathering and Processing [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale of commodities	215.4		400.4
Fees from midstream services	2		1.1
Revenues	217.4		401.5
Intersegment Eliminations [Member] \| Coastal Gathering and Processing [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale of commodities	62.8		177
Fees from midstream services	0		0
Revenues	62.8		177
Intersegment Eliminations [Member] \| Logistics Assets [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale of commodities	1.1		0.6
Fees from midstream services	72.4		66.2
Revenues	73.5		66.8
Intersegment Eliminations [Member] \| Marketing and Distribution [Member] \| Reportable Segments [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale of commodities	78.5		130.4
Fees from midstream services	4.4		7.9
Revenues	82.9		138.3
Intersegment Eliminations [Member] \| Other Segment [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale of commodities	0		0
Fees from midstream services	0		0
Revenues	0		0
Intersegment Eliminations [Member] \| Corporate and Eliminations [Member] \| Targa Resources Partners LP [Member]
Segment Reporting Information [Line Items]
Sale of commodities	-357.8		-708.4
Fees from midstream services	-78.8		-75.2
Revenues	($436.60)		($783.60)

[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 the preliminary acquisition fair value attributable to goodwill and intangible assets associated with the Atlas mergers.

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]
Sale of commodities	$1,402.20	$2,085.10
Fees from midstream services	277.5	209.6
Total revenues	1,679.70	2,294.70
Reconciliation of operating margin to net income [Abstract]
Operating margin	300	275.3
Depreciation and amortization expense	-119.6	-79.6
General and administrative expense	-42.6	-38
Interest expense, net	-55	-33.9
Other, net	-33	5.6
Income tax expense	-15.2	-22.5
Net income	34.6	106.9
Natural Gas Sales [Member]
Revenue from External Customer [Line Items]
Sale of commodities	302.1	391.8
NGL Sales [Member]
Revenue from External Customer [Line Items]
Sale of commodities	1,030.70	1,650.90
Condensate Sales [Member]
Revenue from External Customer [Line Items]
Sale of commodities	21.3	28.4
Petroleum Products [Member]
Revenue from External Customer [Line Items]
Sale of commodities	26.4	20.1
Derivative Settlements [Member]
Revenue from External Customer [Line Items]
Sale of commodities	21.7	-6.1
Fractionating and Treating Fees [Member]
Revenue from External Customer [Line Items]
Fees from midstream services	49.8	46.5
Storage, Terminaling, Transportation and Export Fees [Member]
Revenue from External Customer [Line Items]
Fees from midstream services	136.2	101.2
Gathering and Processing Fees [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