Targa Resources (TRGP) 10-Q4 Nov 142014 Q3 Quarterly reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
Document and Entity Information	Sep. 30, 2014	Oct. 24, 2014
Document and Entity Information [Abstract]	'	'
Entity Registrant Name	'Targa Resources Corp.	'
Entity Central Index Key	'0001389170	'
Current Fiscal Year End Date	'--12-31	'
Entity Well-known Seasoned Issuer	'Yes	'
Entity Voluntary Filers	'No	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	42,143,463
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q3	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Sep-14	'

CONSOLIDATED_BALANCE_SHEETS_Un

CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Current assets:	'	'
Cash and cash equivalents	$78.80	$66.70
Trade receivables, net of allowances of $1.1 million and $1.1 million	698.1	658.8
Inventories	251.2	150.7
Deferred income taxes	0	0.1
Assets from risk management activities	5	2
Other current assets	20	18.9
Total current assets	1,053.10	897.2
Property, plant and equipment	6,307.70	5,758.40
Accumulated depreciation	-1,614	-1,408.50
Property, plant and equipment, net	4,693.70	4,349.90
Intangible assets, net	607.3	653.4
Long-term assets from risk management activities	1.7	3.1
Investment in unconsolidated affiliate	51.7	55.9
Other long-term assets	84.4	89.1
Total assets	6,491.90	6,048.60
Current liabilities:	'	'
Accounts payable and accrued liabilities	798.6	761.8
Deferred income taxes	0.5	0.6
Liabilities from risk management activities	3.6	8
Total current liabilities	802.7	770.4
Long-term debt	3,137.20	2,989.30
Long-term liabilities from risk management activities	1.2	1.4
Deferred income taxes	135.5	135.5
Other long-term liabilities	65.5	60.7
Commitments and contingencies (see Note 15)	'	'
Targa Resources Corp. stockholders' equity:	'	'
Common stock ($0.001 par value, 300,000,000 shares authorized, 42,532,353 shares issued and 42,143,463 shares outstanding as of September 30, 2014, and 42,529,068 shares issued and 42,162,178 shares outstanding as of December 31, 2013)	0	0
Preferred stock ($0.001 par value, 100,000,000 shares authorized, no shares issued and outstanding as of September 30, 2014 and December 31, 2013)	0	0
Additional paid-in capital	153.8	151.6
Retained earnings	30.8	20.5
Accumulated other comprehensive income (loss)	0.3	-0.5
Treasury stock, at cost (388,890 shares as of September 30, 2014 and 366,890 as of December 31, 2013)	-25.4	-22.8
Total Targa Resources Corp. stockholders' equity	159.5	148.8
Noncontrolling interests in subsidiaries	2,190.30	1,942.50
Total owners' equity	2,349.80	2,091.30
Total liabilities and owners' equity	$6,491.90	$6,048.60

CONSOLIDATED_BALANCE_SHEETS_Un1

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, except Share data, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Current assets:	'	'
Trade receivables, allowances	$1.10	$1.10
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)	42,532,353	42,529,068
Common stock, shares outstanding (in shares)	42,143,463	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)	388,890	366,890

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) [Abstract]	'	'	'	'
Revenues	$2,288.30	$1,466	$6,583.70	$4,210.30
Costs and expenses:	'	'	'	'
Product purchases	1,880.50	1,169	5,412.20	3,387.90
Operating expenses	112.8	97.6	323.7	279.8
Depreciation and amortization expenses	87.6	69	253.1	198.7
General and administrative expenses	43	37.7	122.4	112.5
Other operating (income) expense	-4.3	4.2	-5.3	8.3
Income from operations	168.7	88.5	477.6	223.1
Other income (expense):	'	'	'	'
Interest expense, net	-36.9	-33.4	-106.5	-97.9
Equity earnings	4.7	5.6	13.8	10.1
Gain (loss) on debt redemptions and amendments	0	-7.4	0	-14.7
Other	-0.6	9.1	-0.6	15.3
Income before income taxes	135.9	62.4	384.3	135.9
Income tax (expense) benefit:	'	'	'	'
Current	-17.3	-6.6	-57.8	-23.3
Deferred	1.8	-6.4	4.2	-7
Income tax expense total	-15.5	-13	-53.6	-30.3
Net income	120.4	49.4	330.7	105.6
Less: Net income attributable to noncontrolling interests	89.7	33.1	253.9	61
Net income available to common shareholders	$30.70	$16.30	$76.80	$44.60
Net income available per common share - basic (in dollars per share)	$0.73	$0.39	$1.83	$1.07
Net income available per common share - diluted (in dollars per share)	$0.73	$0.39	$1.82	$1.06
Weighted average shares outstanding - basic (in shares)	42	41.6	42	41.6
Weighted average shares outstanding - diluted (in shares)	42.1	42.1	42.1	42.1

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Targa Resources Corp.	'	'	'	'
Net income attributable to common shareholders	$30.70	$16.30	$76.80	$44.60
Commodity hedging contracts:	'	'	'	'
Change in fair value, pre-tax	1.9	-1.6	-0.6	0.3
Change in fair value, related income tax	-0.7	0.6	0.2	-0.1
Change in fair value, after tax	1.2	-1	-0.4	0.2
Settlement reclassified to revenues, pre-tax	0.1	-0.6	1.5	-2.3
Settlement reclassified to revenues, related income tax	0	0.2	-0.5	0.9
Settlement reclassified to revenues, after tax	0.1	-0.4	1	-1.4
Interest rate swaps:	'	'	'	'
Settlements reclassified to interest expense, net, pre-tax	0	0.2	0.3	0.6
Settlements reclassified to interest expense, net, related income tax	0	-0.1	-0.1	-0.3
Settlements reclassified to interest expense, net, after tax	0	0.1	0.2	0.3
Other comprehensive income (loss) attributable to Targa Resources Corp., pre-tax	2	-2	1.2	-1.4
Other comprehensive income (loss) attributable to Targa Resources Corp., related income tax	-0.7	0.7	-0.4	0.5
Other comprehensive income (loss) attributable to Targa Resources Corp., after tax	1.3	-1.3	0.8	-0.9
Comprehensive income attributable to Targa Resources Corp.	32	15	77.6	43.7
Noncontrolling interests	'	'	'	'
Net income attributable to noncontrolling interests	89.7	33.1	253.9	61
Commodity hedging contracts:	'	'	'	'
Change in fair value, pre-tax	12.3	-9.7	-3.9	2.1
Change in fair value, related income tax	0	0	0	0
Change in fair value, after tax	12.3	-9.7	-3.9	2.1
Settlement reclassified to revenues, pre-tax	0.7	-3.9	10.1	-14.7
Settlement reclassified to revenues, related income tax	0	0	0	0
Settlement reclassified to revenues, after tax	0.7	-3.9	10.1	-14.7
Interest rate swaps:	'	'	'	'
Settlements reclassified to interest expense, net, pre-tax	0	1.3	2.1	4.1
Settlements reclassified to interest expense, net, related income tax	0	0	0	0
Settlements reclassified to interest expense, net, after tax	0	1.3	2.1	4.1
Other comprehensive income (loss) attributable to noncontrolling interests, pre-tax	13	-12.3	8.3	-8.5
Other comprehensive income (loss) attributable to noncontrolling interests, related income tax	0	0	0	0
Other comprehensive income (loss) attributable to noncontrolling interests, after tax	13	-12.3	8.3	-8.5
Comprehensive income attributable to noncontrolling interests	102.7	20.8	262.2	52.5
Total	'	'	'	'
Net income	120.4	49.4	330.7	105.6
Commodity hedging contracts:	'	'	'	'
Change in fair value, pre-tax	14.2	-11.3	-4.5	2.4
Change in fair value, related income tax	-0.7	0.6	0.2	-0.1
Change in fair value, after tax	13.5	-10.7	-4.3	2.3
Settlement reclassified to revenues, pre-tax	0.8	-4.5	11.6	-17
Settlement reclassified to revenues, related income tax	0	0.2	-0.5	0.9
Settlement reclassified to revenues, after tax	0.8	-4.3	11.1	-16.1
Interest rate swap:	'	'	'	'
Settlements reclassified to interest expense, net, pre-tax	0	1.5	2.4	4.7
Settlements reclassified to interest expense, net, related income tax	0	-0.1	-0.1	-0.3
Settlements reclassified to interest expense, net, after tax	0	1.4	2.3	4.4
Other comprehensive income (loss), pre-tax	15	-14.3	9.5	-9.9
Other comprehensive income (loss), related income tax	-0.7	0.7	-0.4	0.5
Other comprehensive income (loss), after tax	14.3	-13.6	9.1	-9.4
Total comprehensive income	$134.70	$35.80	$339.80	$96.20

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 in Thousands	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 beginning of period at Dec. 31, 2012	$0	$184.40	($32)	$1.20	($9.50)	$1,609.30	$1,753.40
Balance at beginning of period (in shares) at Dec. 31, 2012	42,295	'	'	'	198	'	'
Compensation on equity grants	0	5.6	0	0	0	4.4	10
Accrual of distribution equivalent rights	0	0	0	0	0	-1.1	-1.1
Shares issued under compensation program (in shares)	36	'	'	'	'	'	'
Sale of Partnership limited partner interests	0	0	0	0	0	377.4	377.4
Receivables from unit offerings	0	-3.3	0	0	0	0	-3.3
Impact of Partnership equity transactions	0	23.8	0	0	0	-23.8	0
Dividends in excess of retained earnings	0	-62.9	0	0	0	0	-62.9
Distributions	0	0	0	0	0	-195.1	-195.1
Other comprehensive income (loss)	0	0	0	-0.9	0	-8.5	-9.4
Net income	0	0	44.6	0	0	61	105.6
Balance at end of period at Sep. 30, 2013	0	147.6	12.6	0.3	-9.5	1,823.60	1,974.60
Balance end of period (in shares) at Sep. 30, 2013	42,331	'	'	'	198	'	'
Balance at beginning of period at Dec. 31, 2013	0	151.6	20.5	-0.5	-22.8	1,942.50	2,091.30
Balance at beginning of period (in shares) at Dec. 31, 2013	42,162	'	'	'	367	'	'
Compensation on equity grants	0	3.8	0	0	0	7	10.8
Accrual of distribution equivalent rights	0	0	0	0	0	-2	-2
Shares issued under compensation program (in shares)	3	'	'	'	'	'	'
Common stock and Partnership units tendered for tax withholding obligations	0	0	0	0	-2.6	-4.8	-7.4
Common stock and Partnership units tendered for tax withholding obligations (in shares)	-22	'	'	'	22	'	'
Sale of Partnership limited partner interests	0	0	0	0	0	257.2	257.2
Impact of Partnership equity transactions	0	14.1	0	0	0	-14.1	0
Dividends	0	'	-66.5	0	0	0	-66.5
Dividends in excess of retained earnings	0	-15.7	0	0	0	0	-15.7
Distributions	0	0	0	0	0	-257.7	-257.7
Other comprehensive income (loss)	0	0	0	0.8	0	8.3	9.1
Net income	0	0	76.8	0	0	253.9	330.7
Balance at end of period at Sep. 30, 2014	$0	$153.80	$30.80	$0.30	($25.40)	$2,190.30	$2,349.80
Balance end of period (in shares) at Sep. 30, 2014	42,143	'	'	'	389	'	'

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Cash flows from operating activities	'	'
Net income	$330.70	$105.60
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'
Amortization in interest expense	9.2	12.1
Compensation on equity grants	10.8	10
Depreciation and amortization expense	253.1	198.7
Accretion of asset retirement obligations	3.3	3
Deferred income tax expense (benefit)	-4.2	7
Equity earnings of unconsolidated affiliate	-13.8	-10.1
Distributions of unconsolidated affiliate	13.8	10.1
Risk management activities	0.9	0
(Gain) loss on sale or disposition of assets	-5.6	3.1
(Gain) loss on debt redemptions and amendments	0	14.7
Changes in operating assets and liabilities:	'	'
Receivables and other assets	-41.3	19.7
Inventory	-117.8	-110.3
Accounts payable and other liabilities	80	13.4
Net cash provided by operating activities	519.1	277
Cash flows from investing activities	'	'
Outlays for property, plant and equipment	-571.7	-727.1
Return of capital from unconsolidated affiliate	4.2	1.9
Other, net	6.3	-31.3
Net cash used in investing activities	-561.2	-756.5
Partnership loan facility:	'	'
Proceeds	1,295	1,743
Repayments	-1,115	-1,521.20
Partnership accounts receivable securitization facility:	'	'
Borrowings	88.9	261.6
Repayments	-131	-93.6
Non-Partnership loan facility:	'	'
Proceeds	67	36
Repayments	-59	-48
Costs incurred in connection with financing arrangements	-2.7	-13.6
Distributions to owners	-259.3	-195.1
Proceeds from sale of common units of the Partnership	259.9	379.6
Repurchase of common units under Partnership compensation plans	-4.8	0
Dividends to common and common equivalent shareholders	-82.2	-61.8
Repurchase of common stock under TRC compensation plans	-2.6	0
Net cash provided by financing activities	54.2	486.9
Net change in cash and cash equivalents	12.1	7.4
Cash and cash equivalents, beginning of period	66.7	76.3
Cash and cash equivalents, end of period	$78.80	$83.70

Organization

Organization	9 Months Ended
Organization	Sep. 30, 2014
Organization [Abstract]	'
Organization	'
	Note 1 — Organization

	Targa Resources Corp. (“TRC”) is a 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	9 Months Ended
Basis of Presentation	Sep. 30, 2014
Basis of Presentation [Abstract]	'
Basis of Presentation	'
	Note 2 — Basis of Presentation

	We have prepared these unaudited consolidated financial statements in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. While we derived the year-end balance sheet data from audited financial statements, this interim report does not include all disclosures required by GAAP for annual periods. These unaudited consolidated financial statements and other information included in this Quarterly Report should be read in conjunction with our consolidated financial statements and notes thereto included in our Annual Report.

	The unaudited consolidated financial statements for the three and nine months ended September 30, 2014 and 2013 include all adjustments, which we believe are necessary, for a fair presentation of the results for interim periods. All significant intercompany balances and transactions have been eliminated in consolidation. Certain amounts in prior periods may have been reclassified to conform to the current year presentation.

	Our financial results for the three and nine months ended September 30, 2014 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”). 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 results of operations as net income attributable to noncontrolling interests and in our 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 September 30, 2014, 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

		·	12,945,659 common units of the Partnership, representing an 11.2% 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 17 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.

	Reclassifications Affecting Statement of Cash Flows

	In conjunction with the integration of Badlands into its financial reporting environment during 2013, the Partnership obtained further information about the acquisition date balance sheet, including the nature of the items comprising assumed Accounts payable and accrued liabilities. The Partnership determined that certain assumed liabilities related to purchases that, under its accounting policies, are considered capital in nature. Consequently, the Partnership made certain refinements to better reflect Badlands cash flow activity on a basis similar to that used for its other operations. As a result of these refinements, certain cash flow activity was presented in its 2013 Form 10-K on a basis different than that utilized for previous quarterly reporting during 2013. In preparing this quarterly report the Partnership has made certain reclassifications in the comparative Statement of Cash Flows for the nine months ended September 30, 2013 to conform to the presentation of its Form 10-K, reclassifying $18.9 million related to capital expenditures previously included in Accounts payable and other liabilities of operating activities to Outlays for property, plant and equipment in investing activities, as shown below.

			Nine Months Ended September 30, 2013
	Revised line items Consolidated		As Reported				Reclassification				As Revised
	Statement of Cash Flows		As Reported				Reclassification				As Revised

	Cash flows from operating activities
	Changes in operating assets and liabilities:
	Accounts payable and other liabilities		$	(5.5	)		$	18.9			$	13.4
	Net cash provided by operating activities			258.1				18.9				277

	Cash flows from investing activities:
	Changes in investing assets and liabilities:
	Outlays for property, plant and equipment			(708.2	)			(18.9	)			(727.1	)
	Net cash used in investing activities			(737.6	)			(18.9	)			(756.5	)

	Revision of Previously Reported Revenues and Product Purchases

	During the third quarter of 2014, the Partnership concluded that certain prior period buy-sell transactions related to the marketing of NGL products were incorrectly reported on a gross basis as Revenues and Product Purchases in previous Consolidated Statements of Operations. GAAP require that such transactions that involve purchases and sales of inventory with the same counterparty that are legally contingent or in contemplation of one another be reported as a single transaction on a combined net basis.

	The Partnership concluded that these misclassifications were not material to any of the periods affected. However, the Partnership has revised previously reported revenues and product purchases to correctly report NGL buy-sell transactions on a net basis. Accordingly, Revenues and Product Purchases reported in its Form 10-K filed on February 14, 2014 and in previous quarterly reports on Form 10-Q for 2014 and 2013 will be reduced by equal amounts as presented in the following tables. There is no impact on previously reported net income, cash flows, financial position or other profitability measures.
			Year Ended December 31,
			2013				2012				2011
	As Reported:
	Revenues		$	6,556.00			$	5,885.70			$	6,994.50
	Product Purchases			5,378.50				4,879.00				6,039.00

	Effect of Revisions:
	Revenues			(241.3	)			(206.7	)			(151.3	)
	Product Purchases			(241.3	)			(206.7	)			(151.3	)

	As Revised:
	Revenues			6,314.70				5,679.00				6,843.20
	Product Purchases			5,137.20				4,672.30				5,887.70

			Three Months Ended																		Nine Months Ended			Six Months Ended
			September 30,				June 30,								March 31,						September 30,			June 30,
		2013				2014				2013				2014			2013			2013			2014			2013
As Reported:
Revenues		$	1,556.80			$	2,061.90			$	1,441.60			$	2,352.90		$	1,397.80		$	4,396.20		$	4,414.80		$	2,839.40
Product Purchases			1,259.80				1,677.90				1,176.40				1,973.30			1,137.50			3,573.80			3,651.20			2,313.90

Effect of Revisions:
Revenues			(90.8	)			(61.3	)			(71.1	)			(58.2	)		(24.0	)		(185.9	)		(119.5	)		(95.1	)
Product Purchases			(90.8	)			(61.3	)			(71.1	)			(58.2	)		(24.0	)		(185.9	)		(119.5	)		(95.1	)

As Revised:
Revenues			1,466.00				2,000.60				1,370.50				2,294.70			1,373.80			4,210.30			4,295.30			2,744.30
Product Purchases			1,169.00				1,616.60				1,105.30				1,915.10			1,113.50			3,387.90			3,531.70			2,218.80

Significant_Accounting_Policie

Significant Accounting Policies	9 Months Ended
Significant Accounting Policies	Sep. 30, 2014
Significant Accounting Policies [Abstract]	'
Significant Accounting Policies	'
	Note 3 — Significant Accounting Policies

	Accounting Policy Updates/Revisions

	The accounting policies that we follow are set forth in Note 3 of the Notes to Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 2013. There were no significant updates or revisions to these policies during the nine months ended September 30, 2014.

	Recent Accounting Pronouncements

	In April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant and Equipment (Topic 360), Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. The amendment, required to be applied prospectively for reporting periods beginning after December 15, 2014, limits discontinued operations reporting to disposals of components of an entity that represent strategic shifts that have, or will have, a major effect on operations and financial results. The amendment requires expanded disclosures for discontinued operations and also requires additional disclosures regarding disposals of individually significant components that do not qualify as discontinued operations. Early adoption is permitted, but only for disposals (or classifications as held for sale) that have not been reported in financial statements previously issued or available for issuance. This amendment has no impact on our current disclosures, but will in the future if we dispose of any individually significant components.

	In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), which supersedes the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance. The update also creates a new Subtopic 340-40, Other Assets and Deferred Costs – Contracts with Customers, which provides guidance for the incremental costs of obtaining a contract with a customer and those costs incurred in fulfilling a contract with a customer that are not in the scope of another topic. The new revenue standard requires that entities should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entities expect to be entitled in exchange for those goods or services. To achieve that core principle, the standard requires a five-step process of identifying the contracts with customers, identifying the performance obligations in the contracts, determining the transaction price, allocating the transaction price to the performance obligations and recognizing revenue when, or as, the performance obligations are satisfied. The amendment also requires enhanced disclosures regarding the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers.

	The revenue recognition standard will be effective for us starting in the first quarter of 2017. Early adoption is not permitted. We must retroactively apply the new revenue recognition standard to transactions in all prior periods presented, but will have a choice between either (1) restating each prior period presented or (2) presenting a cumulative effect adjustment in our first quarter report in 2017. We have commenced our analysis of the new standard and its impact on our revenue recognition practices.

	In August 2014, the FASB issued ASU No. 2014-15, Presentation of Financial Statements—Going Concern (Subtopic 205-40), Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. The amendment is effective for the annual period beginning after December 15, 2016, and for annual and interim periods thereafter, with early adoption permitted. The amendment requires an entity’s management to evaluate for each annual and interim reporting period whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date that the financial statements are issued or available to be issued. If substantial doubt is raised, further analysis and disclosures are required, including management’s plans to mitigate the adverse conditions or events. This amendment has no impact on our current disclosures, but would if our management identified future conditions or events that, in the aggregate, raise substantial doubt about our ability to continue as a going concern.

Inventories

Inventories	9 Months Ended
Inventories	Sep. 30, 2014
Inventories [Abstract]	'
Inventories	'
	Note 4 — Inventories

	The components of inventories consisted of the following:

		30-Sep-14		31-Dec-13
	Commodities	$	236.6	$	136.4
	Materials and supplies		14.6		14.3
		$	251.2	$	150.7

Property_Plant_and_Equipment_a

Property, Plant and Equipment and Intangible Assets	9 Months Ended
Property, Plant and Equipment and Intangible Assets	Sep. 30, 2014
Property, Plant and Equipment and Intangible Assets [Abstract]	'
Property, Plant and Equipment and Intangible Assets	'
	Note 5 — Property, Plant and Equipment and Intangible Assets

		30-Sep-14									31-Dec-13
		Targa			TRC Non-			Targa			Targa			TRC Non-			Targa			Estimated
		Resources			Partnership			Resources			Resources			Partnership			Resources			Useful Lives
		Partners LP						Corp.			Partners LP						Corp.			(In Years)
								Consolidated									Consolidated
	Gathering systems	$	2,438.60		$	-		$	2,438.60		$	2,230.10		$	-		$	2,230.10		5 to 20
	Processing and fractionation facilities		1,866.90			6.6			1,873.50			1,598.00			6.6			1,604.60		5 to 25
	Terminaling and storage facilities		1,004.10			-			1,004.10			715.2			-			715.2		5 to 25
	Transportation assets		358.3			-			358.3			294.7			-			294.7		10 to 25
	Other property, plant and equipment		138.1			0.2			138.3			121.3			0.2			121.5		3 to 25
	Land		90.9			-			90.9			89.5			-			89.5			-
	Construction in progress		404			-			404			702.8			-			702.8			-
	Property, plant and equipment		6,300.90			6.8			6,307.70			5,751.60			6.8			5,758.40
	Accumulated depreciation		(1,611.5	)		(2.5	)		(1,614.0	)		(1,406.2	)		(2.3	)		(1,408.5	)
	Property, plant and equipment, net	$	4,689.40		$	4.3		$	4,693.70		$	4,345.40		$	4.5		$	4,349.90

	Intangible assets	$	681.8		$	-		$	681.8		$	681.8		$	-		$	681.8			20
	Accumulated amortization		(74.5	)		-			(74.5	)		(28.4	)		-			(28.4	)
	Intangible assets, net	$	607.3		$	-		$	607.3		$	653.4		$	-		$	653.4

	Intangible assets consist of customer contracts and customer relationships acquired in the Partnership’s Badlands business acquisitions. The fair value of these acquired intangible assets was determined at the date of acquisition based on the present value 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.

	Amortization expense attributable to these intangible assets is recorded using a method that closely reflects the cash flow pattern underlying the intangible asset valuation. The estimated annual amortization expense for these intangible assets is approximately $61.4 million, $80.1 million, $88.3 million, $81.5 million and $67.8 million for each of years 2014 through 2018.

Asset_Retirement_Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2014
Asset Retirement Obligations [Abstract]	'
Asset Retirement Obligations	'
	Note 6 — Asset Retirement Obligations

	Our asset retirement obligations (“ARO”) primarily relate to certain gas gathering pipelines and processing facilities, and are included in our Consolidated Balance Sheets as a component of other long-term liabilities. The changes in our aggregate asset retirement obligations are as follows:

		Nine Months Ended
		30-Sep-14
	Beginning of period	$	50.9
	Change in cash flow estimate		2.1
	Accretion expense		3.3
	End of period	$	56.3

Investment_in_Unconsolidated_A

Investment in Unconsolidated Affiliate	9 Months Ended
	Sep. 30, 2014
Investment in Unconsolidated Affiliate [Abstract]	'
Investment in Unconsolidated Affiliate	'
	Note 7 — Investment in Unconsolidated Affiliate

	At September 30, 2014, the Partnership’s unconsolidated investment consisted of a 38.8% ownership interest in Gulf Coast Fractionators LP (“GCF”).

	The following table shows the activity related to the Partnership’s investment in GCF:

			Nine Months Ended
			30-Sep-14
	Beginning of period		$	55.9
	Equity earnings			13.8
	Cash distributions (1)			(18.0	)
	End of period		$	51.7


	-1	Includes $4.2 million distributions received in excess of the Partnership’s share of cumulative earnings that are considered a return of capital and disclosed in cash flows from investing activities in the Consolidated Statements of Cash Flows.

Accounts_Payable_and_Accrued_L

Accounts Payable and Accrued Liabilities	9 Months Ended
Accounts Payable and Accrued Liabilities	Sep. 30, 2014
Accounts Payable and Accrued Liabilities [Abstract]	'
Accounts Payable and Accrued Liabilities	'
	Note 8 — Accounts Payable and Accrued Liabilities

	The components of accounts payable and accrued liabilities consisted of the following:

		30-Sep-14		31-Dec-13
	Commodities	$	573.6	$	520.8
	Other goods and services		104.9		146.8
	Interest		42.8		35.9
	Compensation and benefits		46.4		40.3
	Income and other taxes		25.5		10.2
	Other		5.4		7.8
		$	798.6	$	761.8

Debt_Obligations

Debt Obligations	9 Months Ended
Debt Obligations	Sep. 30, 2014
Debt Obligations [Abstract]	'
Debt Obligations	'
	Note 9 — Debt Obligations

			30-Sep-14			31-Dec-13
	Long-term debt:
	Non-Partnership obligations:
	TRC Senior secured revolving credit facility, variable rate, due October 2017 (1)		$	92		$	84
	Obligations of the Partnership: (2)
	Senior secured revolving credit facility, variable rate, due October 2017 (3)			575			395
	Senior unsecured notes, 7⅞% fixed rate, due October 2018			250			250
	Senior unsecured notes, 6⅞% fixed rate, due February 2021			483.6			483.6
	Unamortized discount			(26.0	)		(28.0	)
	Senior unsecured notes, 6⅜% fixed rate, due August 2022			300			300
	Senior unsecured notes, 5¼% fixed rate, due May 2023			600			600
	Senior unsecured notes, 4¼% fixed rate, due November 2023			625			625
	Accounts receivable securitization facility, due December 2014 (4)			237.6			279.7
	Total long-term debt		$	3,137.20		$	2,989.30
	Irrevocable standby letters of credit:
	Letters of credit outstanding under TRC Senior secured credit facility (1)		$	-		$	-
	Letters of credit outstanding under the Partnership senior secured revolving credit facility (3)			42			86.8
			$	42		$	86.8


		-1	As of September 30, 2014, availability under TRC’s $150 million senior secured revolving credit facility was $58.0 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 September 30, 2014, availability under the Partnership’s $1.2 billion senior secured revolving credit facility (“TRP Revolver”) was $583.0 million.
		-4	All amounts outstanding under the Partnership’s Accounts Receivable Securitization Facility (“Securitization Facility”) are reflected as long-term debt in our Consolidated Balance Sheet because the Partnership has the ability and intent to fund the Securitization Facility’s borrowings on a long-term basis. The Partnership intends to fund the Securitization Facility’s borrowings either by further extending the termination date of the Securitization Facility or by utilizing the availability under its senior secured revolving credit facility.

	The following table shows the range of interest rates and weighted average interest rate incurred on variable-rate debt obligations during the nine months ended September 30, 2014:

			Range of Interest			Weighted Average
			Rates Incurred			Interest Rate Incurred
	TRC senior secured revolving credit facility			2.9	%		2.9	%
	Partnership's senior secured revolving credit facility			1.9% - 4.5	%		2	%
	Partnership's accounts receivable securitization facility			0.9	%		0.9	%

	Compliance with Debt Covenants

	As of September 30, 2014, both the Partnership and we were in compliance with the covenants contained in our various debt agreements.

Partnership_Units_and_Related_

Partnership Units and Related Matters	9 Months Ended
Partnership Units and Related Matters	Sep. 30, 2014
Partnership Units and Related Matters [Abstract]	'
Partnership Units and Related Matters	'
	Note 10 — Partnership Units and Related Matters

	Public Offerings of Common Units

	During the nine months ended September 30, 2014, the Partnership issued 3,119,454 common units under an equity distribution agreement entered into in August 2013 (the “August 2013 EDA”), receiving proceeds of $169.5 million (net of commissions up to 1% of gross proceeds to the Partnership’s sales agent). We contributed $3.5 million to the Partnership to maintain our 2% general partner interest.

	In May 2014, the Partnership entered into an additional equity distribution agreement under its July 2013 Shelf (the “May 2014 EDA”), with Barclays Capital Inc., Citigroup Global Markets Inc., Deutsche Bank Securities Inc., Jefferies LLC, Morgan Stanley & Co. LLC, Raymond James & Associates, Inc., RBC Capital Markets, LLC, UBS Securities LLC and Wells Fargo Securities, LLC, as its sales agents, pursuant to which the Partnership may sell, at its option, up to an aggregate of $400 million of its common units. During the nine months ended September 30, 2014, the Partnership issued 1,243,682 common units under the May 2014 EDA, receiving proceeds of $87.7 million (net of commissions up to 1% of gross proceeds to the Partnership’s sales agent). We contributed $1.8 million to the Partnership to maintain our 2% general partner interest, of which $0.4 million was settled in October. As of October 24, 2014, approximately $311.3 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 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 nine months ended September 30, 2014.

			Distributions
	Three Months	Date Paid or to be	Limited		General Partner						Distributions		Distributions
	Ended	Paid	Partners								to Targa		per limited
											Resources		partner unit
			Common		Incentive			2%	Total		Corp.

	(In millions, except per unit amounts)
	30-Sep-14	14-Nov-14	$	92.3	$	36	$	2.6	$	130.9	$	48.9	$	0.7975
	30-Jun-14	14-Aug-14		89.5		33.7		2.5		125.7		46.3		0.78
	31-Mar-14	15-May-14		87.2		31.7		2.4		121.3		44		0.7625
	31-Dec-13	14-Feb-14		84		29.5		2.3		115.8		41.5		0.7475

Common_Stock_and_Related_Matte

Common Stock and Related Matters

9 Months Ended

Sep. 30, 2014

Common Stock and Related Matters [Abstract]

Common Stock and Related Matters

Note 11 — Common Stock and Related Matters

The following table details the dividends declared and/or paid by us for the nine months ended September 30, 2014:

Three Months

Date Paid or To Be

Total

Amount of

Accrued

Dividend

Ended

Paid

Dividend

Dividends (1)

Declared per

Declared

Paid

Share of

Common Stock

(In millions, except per share amounts)

30-Sep-14

17-Nov-14

30.8

0.2

0.7325

30-Jun-14

15-Aug-14

29.2

0.2

0.69

31-Mar-14

16-May-14

27.4

27.2

0.2

0.6475

31-Dec-13

18-Feb-14

25.6

25.5

0.1

0.6075

-1

Represents accrued dividends on restricted stock and 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	9 Months Ended
Earnings per Common Share	Sep. 30, 2014
Earnings per Common Share [Abstract]	'
Earnings per Common Share	'
	Note 12 — 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 September 30,				Nine Months Ended September 30,
		2014		2013		2014		2013
	Net income	$	120.4	$	49.4	$	330.7	$	105.6
	Less: Net income attributable to noncontrolling interests		89.7		33.1		253.9		61
	Net income attributable to common shareholders	$	30.7	$	16.3	$	76.8	$	44.6

	Weighted average shares outstanding - basic		42		41.6		42		41.6

	Net income available per common share - basic	$	0.73	$	0.39	$	1.83	$	1.07

	Weighted average shares outstanding		42		41.6		42		41.6
	Dilutive effect of unvested stock awards		0.1		0.5		0.1		0.5
	Weighted average shares outstanding - diluted		42.1		42.1		42.1		42.1

	Net income available per common share - diluted	$	0.73	$	0.39	$	1.82	$	1.06

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	9 Months Ended
Derivative Instruments and Hedging Activities	Sep. 30, 2014
Derivative Instruments and Hedging Activities [Abstract]	'
Derivative Instruments and Hedging Activities	'
	Note 13 — 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 its percent-of-proceeds processing arrangements. These hedge positions will move favorably in periods of falling commodity prices and unfavorably in periods of rising commodity prices. 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 and natural gas delivery points to those of the Partnership’s physical equity volumes. The NGL hedges may be transacted as specific NGL hedges or as baskets of ethane, propane, normal butane, isobutane and natural gasoline based upon 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, which closely approximate the Partnership’s actual natural gas and NGL delivery points.

	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. Hedge ineffectiveness was immaterial for all periods presented.

	At September 30, 2014, the notional volumes of the Partnership’s commodity hedges for equity volumes were:

	Commodity		Instrument		Unit		2014				2015				2016
	Natural Gas		Swaps		MMBtu/d			66,050				50,551				25,500
	NGL		Swaps		Bbl/d			2,683				1,210				-
	Condensate		Swaps		Bbl/d			2,450				-				-

	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. 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 September 30, 2014								Fair Value as of December 31, 2013
		Balance Sheet		Derivative				Derivative				Derivative				Derivative
		Location		Assets				Liabilities				Assets				Liabilities
	Derivatives designated as hedging instruments
	Commodity contracts	Current		$	4.7			$	2			$	2			$	7.7
		Long-term			1.7				1.2				3.1				1.4
	Total derivatives designated as hedging instruments			$	6.4			$	3.2			$	5.1			$	9.1

	Derivatives not designated as hedging instruments
	Commodity contracts	Current		$	0.3			$	1.6			$	-			$	0.3
	Total derivatives not designated as hedging instruments			$	0.3			$	1.6			$	-			$	0.3

	Total current position			$	5			$	3.6			$	2			$	8
	Total long-term position				1.7				1.2				3.1				1.4
	Total derivatives			$	6.7			$	4.8			$	5.1			$	9.4

	The pro forma impact of reporting derivatives in the Consolidated Balance Sheets on a net basis is as follows:

			Gross Presentation								Pro forma Net Presentation
			Asset				Liability				Asset				Liability
	30-Sep-14		Position				Position				Position				Position
	Current position
	Counterparties with offsetting position		$	4.5			$	3			$	1.5			$	-
	Counterparties without offsetting position - assets			0.5				-				0.5				-
	Counterparties without offsetting position - liabilities			-				0.6				-				0.6
				5				3.6				2				0.6
	Long-term position
	Counterparties with offsetting position			1.2				0.6				0.6				-
	Counterparties without offsetting position - assets			0.5				-				0.5				-
	Counterparties without offsetting position - liabilities			-				0.6				-				0.6
				1.7				1.2				1.1				0.6
	Total derivatives
	Counterparties with offsetting position			5.7				3.6				2.1				-
	Counterparties without offsetting position - assets			1				-				1				-
	Counterparties without offsetting position - liabilities			-				1.2				-				1.2
			$	6.7			$	4.8			$	3.1			$	1.2

	31-Dec-13
	Current position
	Counterparties with offsetting position		$	1.9			$	4.4			$	-			$	2.5
	Counterparties without offsetting position - assets			0.1				-				0.1				-
	Counterparties without offsetting position - liabilities			-				3.6				-				3.6
			2				8				0.1				6.1
Long-term position
Counterparties with offsetting position			0.7				1.2				-				0.5
Counterparties without offsetting position - assets			2.4				-				2.4				-
Counterparties without offsetting position - liabilities			-				0.2				-				0.2
			3.1				1.4				2.4				0.7
Total derivatives
Counterparties with offsetting position			2.6				5.6				-				3
Counterparties without offsetting position - assets			2.5				-				2.5				-
Counterparties without offsetting position - liabilities			-				3.8				-				3.8
		$	5.1			$	9.4			$	2.5			$	6.8

The fair value of 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 $1.9 million as of September 30, 2014. The estimated fair value is net of an adjustment for credit risk based on the default probabilities by year as indicated by market quotes for the counterparties’ credit default swap rates. The credit risk adjustment was immaterial for all periods presented.

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 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			Three Months Ended September 30,						Nine Months Ended September 30,
Flow Hedging			Three Months Ended September 30,						Nine Months Ended September 30,
Relationships			2014		2013				2014				2013
Commodity contracts		$	14.2			$	(11.3	)		$	(4.5	)		$	2.4

			Gain (Loss) Reclassified from OCI into Income
			(Effective Portion)
Location of Gain			Three Months Ended September 30,						Nine Months Ended September 30,
(Loss)			Three Months Ended September 30,						Nine Months Ended September 30,
			2014		2013				2014				2013
Interest expense, net		$	-			$	(1.5	)		$	(2.4	)		$	(4.7	)
Revenues			(0.8	)			4.5				(11.6	)			17
		$	(0.8	)		$	3			$	(14.0	)		$	12.3

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 (i.e., using the “mark-to-market” method) rather than being deferred until the anticipated transaction settles. The use of mark-to-market accounting for financial instruments can cause non-cash earnings volatility due to changes in the underlying commodity price indices. Gain (loss) recognized on commodity derivatives not designated as hedging instruments was immaterial for all periods presented.

The following table shows the deferred gains (losses) that are related to our consolidated accumulated OCI that will be reclassified into earnings through the end of 2016:

		30-Sep-14				31-Dec-13
Commodity hedges, before tax (1)		$	0.4			$	(0.5	)
Commodity hedges, after tax (1)			0.3				(0.3	)
Interest rate hedges, before tax			-				(0.3	)
Interest rate hedges, after tax			-				(0.2	)


-1	Includes net losses of $2.8 million related to contracts that will be settled and reclassified to revenue over the next 12 months.

See Note 14 for additional disclosures related to derivative instruments and hedging activities.

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
Fair Value Measurements	Sep. 30, 2014
Fair Value Measurements [Abstract]	'
Fair Value Measurements	'
	Note 14 — Fair Value Measurements

	Under GAAP, our Consolidated Balance Sheets reflect a mixture of measurement methods for financial assets and liabilities (“financial instruments”). Derivative financial instruments are reported at fair value in our Consolidated Balance Sheets. Other financial instruments are reported at historical cost or amortized cost in our Consolidated Balance Sheets, with fair value measurements for these instruments provided as supplemental information.
	The following are additional qualitative and quantitative disclosures regarding fair value measurements of financial instruments.

	Fair Value of Derivative Financial Instruments

	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 a discounted cash flow model for swaps and a standard option pricing-model for options, based on inputs that are readily available in public markets. 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 reflects the present value 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 liability of $13.7 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 $17.5 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:

		•	Senior secured revolving credit facilities and the Partnership’s 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:

			30-Sep-14
			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)		$	6.7		$	6.7	$	-	$	6.3	$	0.4
	Liabilities from commodity derivative contracts (1)			4.8			4.8		-		4.5		0.3
	Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
	Cash and cash equivalents			78.8			78.8		-		-		-
	TRC Senior secured revolving credit facility			92			92		-		92		-
	Partnership's Senior secured revolving credit facility			575			575		-		575		-
	Partnership's Senior unsecured notes			2,232.60			2,310.20		-		2,310.20		-
	Partnership's accounts receivable securitization facility			237.6			237.6		-		237.6		-


	-1	The fair value of the derivative contracts in this table is presented on a different basis than the consolidated balance sheet presentation as disclosed in Note 13. The above fair values reflect the total value of each derivative contract taken as a whole, whereas the consolidated balance sheet presentation is based on the individual maturity dates of estimated future settlements. As such, an individual contract could have both an asset and liability position when segregated into its current and long-term portions for consolidated balance sheet classification purposes.

	Additional Information Regarding Level 3 Fair Value Measurements Included in Our Consolidated Balance Sheets

	As of September 30, 2014, we reported certain of the Partnership’s natural gas swaps at fair value using Level 3 inputs due to such derivatives not having observable market prices for substantially the full term of the derivative asset or liability. For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is categorized in Level 3. This includes derivatives valued using indicative price quotations whose contract length extends into unobservable periods.

	The fair value of these natural gas 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 September 30, 2014, the Partnership had five natural gas swaps 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, 2013		$	0.7
	Settlements included in Revenue			0.2
	Unrealized gain (loss) included in OCI			(0.5	)
	Transfers out of Level 3			(0.3	)
Balance, September 30, 2014		$	0.1

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
Commitments and Contingencies	Sep. 30, 2014
Commitments and Contingencies [Abstract]	'
Commitments and Contingencies	'
	Note 15 — Commitments and Contingencies

	Legal Proceedings

	We are a party to various legal proceedings and/or regulatory proceedings and certain claims, suits and complaints arising in the ordinary course of business that have been filed or are pending against us.

	Litigation Related to the Atlas Mergers

	In October 2014, three public unitholders of APL (the “APL Plaintiffs”) filed class action lawsuits against APL, ATLS, Atlas Pipeline Partners GP, LLC (“APL GP”), its managers, us, the Partnership, the general partner and Trident MLP Merger Sub LLC (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 Alleghany 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; and (c) Greenthal Living Trust U/A 01/26/88 v. Atlas Pipeline Partners, L.P., et al., in the Court of Common Pleas for Alleghany County, Pennsylvania (the “APL Lawsuits”). On October 23, 2014, a public unitholder of ATLS (the “ATLS Plaintiff” and, together with the APL Plaintiffs, “Plaintiffs”) filed a class action lawsuit against ATLS, Atlas Energy Partners GP, LLC (“ATLS GP”), its managers, us, and Trident GP Merger Sub LLC (the “ATLS Lawsuit Defendants” and, together with the APL Lawsuit Defendants, “Defendants”). This lawsuit is styled Rick Kane v. Atlas Energy, L.P., et al., in the Court of Common Pleas for Alleghany County, Pennsylvania (the “ATLS Lawsuit” and, together with the APL Lawsuits, the “Lawsuits”).

	Plaintiffs allege a variety of causes of action challenging the Atlas Mergers. The APL Plaintiffs allege that (a) APL GP’s managers have breached the covenant of good faith and/or their fiduciary duties and (b) we, the Partnership, the general partner, Trident MLP Merger Sub LLC, APL, ATLS and APL GP have aided and abetted in these alleged breaches of the covenant of good faith and/or fiduciary duties. One of the APL Plaintiffs also alleges that (a) APL GP and its managers breached APL’s Limited Partnership Agreement and (b) APL and APL GP’s managers aided and abetted in APL GP’s alleged breaches of the Limited Partnership Agreement. Specifically, the APL Plaintiffs allege 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 ATLS Plaintiff alleges that (a) ATLS GP’s managers have breached the covenant of good faith and/or their fiduciary duties and (b) we, Trident GP Merger Sub LLC, ATLS and ATLS GP have aided and abetted in these alleged breaches of the covenant of good faith and/or fiduciary duties. Specifically, the ATLS Plaintiff alleges that (a) the premium offered to ATLS’s unitholders is inadequate, (b) ATLS agreed to contractual terms that will allegedly dissuade other potential acquirers from seeking to acquire ATLS and (c) ATLS GP’s managers favored their self-interests over the interests of ATLS’s unitholders.

	Based on these allegations, Plaintiffs seeks to enjoin Defendants from proceeding with or consummating the Atlas Mergers unless and until APL and ATLS adopt and implement processes to obtain the best possible terms for their respective unitholders. To the extent that the Atlas Mergers are consummated before injunctive relief is granted, Plaintiffs seek to have the Atlas Mergers rescinded. Plaintiffs also seek damages and attorneys’ fees.

	Plaintiffs have not yet served Defendants, and Defendants’ date to answer, move to dismiss or otherwise respond to the Lawsuits has not yet been set. We cannot predict the outcome of the Lawsuits or any others that might be filed subsequent to the date of this filing; nor can we predict the amount of time and expense that will be required to resolve the Lawsuits. Defendants intend to vigorously defend the Lawsuits.

	Contingent Consideration

	Pursuant to the Membership Interest Purchase and Sale Agreement (“MIPSA”), the Partnership acquisition of Badlands was subject to a contingent payment of $50 million (the “contingent consideration”) if aggregate crude oil gathering volumes exceeded certain stipulated monthly thresholds during the period from January 2013 through June 2014. If the threshold is not attained during the contingency period, no payment is owed. Accounting standards require that the contingent consideration be recorded at fair value at the date of acquisition and revalued at subsequent reporting dates under the acquisition method of accounting. At December 31, 2012, the Partnership recorded a $15.3 million accrued liability representing the fair value of this contingent consideration, determined by a probability-based model measuring the likelihood of meeting certain volumetric measures identified in the MIPSA.

	Changes in the fair value of this accrued liability are included in earnings and reported as Other income (expense) in the Consolidated Statement of Operations. As of September 30, 2013, the contingent consideration was re-estimated to be $0, a decrease of $9.1 million for the third quarter 2013, and $15.3 million year-to-date 2013, reflecting at that time management’s updated assessment. The contingent period expired June 2014, with no payment required.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information	9 Months Ended
Supplemental Cash Flow Information	Sep. 30, 2014
Supplemental Cash Flow Information [Abstract]	'
Supplemental Cash Flow Information	'
	Note 16 - Supplemental Cash Flow Information

			Nine Months Ended September 30,
			2014			2013
	Cash:
	Interest paid, net of capitalized interest (1)		$	90.3		$	83
	Income taxes paid, net of refunds			55.2			23.1
	Non-cash Investing and Financing balance sheet movements:
	Deadstock commodity inventories transferred to property, plant and equipment			15.2			28.3
	Accrued dividends on unvested equity awards			0.5			1.1
	Receivables from equity issuances			-			3.3
	Capital expenditure accruals			(40.6	)		(15.1	)
	Transfers from materials and supplies inventory to property, plant and equipment			2.7			15.1
	Change in ARO liability and property, plant and equipment due to revised future ARO cash flow estimate			2.1			1.4



	-1	Interest capitalized on major projects was $14.3 million and $22.6 million for the nine months ended September 30, 2014 and 2013.

Segment_Information

Segment Information	9 Months Ended
Segment Information	Sep. 30, 2014
Segment Information [Abstract]	'
Segment Information	'
	Note 17 — 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 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 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 exported LPGs; 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.

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

			Three Months Ended September 30, 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		$	49.4		$	83.4		$	23.1		$	1,855.60		$	(2.3	)		$	-			$	-			$	2,009.20
	Fees from midstream services			49.4			8			75.5			146.2			-				-				-				279.1
				98.8			91.4			98.6			2,001.80			(2.3	)			-				-				2,288.30
	Intersegment revenues
	Sales of commodities			386			143.6			1.3			116.1			-				(647.0	)			-				-
	Fees from midstream services			1.7			-			85.9			10.1			-				(97.7	)			-				-
				387.7			143.6			87.2			126.2			-				(744.7	)			-				-
	Revenues		$	486.5		$	235		$	185.8		$	2,128.00		$	(2.3	)		$	(744.7	)		$	-			$	2,288.30
	Operating margin		$	98		$	19.1		$	118.6		$	61.6		$	(2.3	)		$	-			$	-			$	295
	Other financial information:
	Total assets (1)		$	3,359.00		$	368.6		$	1,650.20		$	917.2		$	6.7			$	115.5			$	74.7			$	6,491.90
	Capital expenditures		$	74		$	2.3		$	59.8		$	4.6		$	-			$	2.2			$	-			$	142.9


	-1	Corporate assets primarily include investment in unconsolidated subsidiaries and debt issuance costs associated with our long-term debt.

			Three Months Ended September 30, 2013
			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		$	56.5		$	71.1		$	38.8		$	1,157.40		$	4.8			$	-			$	(0.1	)		$	1,328.50
	Fees from midstream services			27.4			7.4			53			49.7			-				-				-				137.5
				83.9			78.5			91.8			1,207.10			4.8				-				(0.1	)			1,466.00
	Intersegment revenues
	Sales of commodities			318.9			163.1			1.8			118.5			-				(602.3	)			-				-
	Fees from midstream services			0.8			-			42.1			8.4			-				(51.3	)			-				-
				319.7			163.1			43.9			126.9			-				(653.6	)			-				-
	Revenues		$	403.6		$	241.6		$	135.7		$	1,334.00		$	4.8			$	(653.6	)		$	(0.1	)		$	1,466.00
	Operating margin		$	70.6		$	21.1		$	70.5		$	32.5		$	4.8			$	-			$	(0.1	)		$	199.4
	Other financial information:
	Total assets		$	3,095.90		$	385.8		$	1,407.50		$	638.8		$	14.8			$	105.2			$	77.3			$	5,725.30
	Capital expenditures		$	177.5		$	4.3		$	99.9		$	1.7		$	-			$	1.1			$	-			$	284.5

			Nine Months Ended September 30, 2014
			Partnership
			Field			Coastal			Logistics			Marketing			Other				Corporate								Total
			Gathering			Gathering			Assets			and							and				TRC Non-
	and		and						Distribution			Eliminations							Partnership
	Processing		Processing
Revenues
Sales of commodities			$	158		$	273.7		$	73		$	5,361.00		$	(12.4	)		$	-			$	-			$	5,853.30
Fees from midstream services			133.5			26.1			216.3			354.5			-				-				-				730.4
			291.5			299.8			289.3			5,715.50			(12.4	)			-				-				6,583.70
Intersegment revenues
Sales of commodities			1,168.20			484			2.7			383.6			-				(2,038.5	)			-				-
Fees from midstream services			3.9			0.1			224.5			25.5			-				(254.0	)			-				-
			1,172.10			484.1			227.2			409.1			-				(2,292.5	)			-				-
Revenues		$	1,463.60		$	783.9		$	516.5		$	6,124.60		$	(12.4	)		$	(2,292.5	)		$	-			$	6,583.70
Operating margin		$	289.8		$	67		$	324		$	179.5		$	(12.4	)		$	-			$	(0.1	)		$	847.8
Other financial information:
Total assets		$	3,359.00		$	368.6		$	1,650.20		$	917.2		$	6.7			$	115.5			$	74.7			$	6,491.90
Capital expenditures		$	301.4		$	9.7		$	195.9		$	23.2		$	-			$	3.6			$	-			$	533.8

		Nine Months Ended September 30, 2013
		Partnership
		Field			Coastal			Logistics			Marketing			Other				Corporate				TRC Non-				Total
		Gathering			Gathering			Assets			and							and				Partnership
		and			and						Distribution							Eliminations
		Processing			Processing
Revenues
Sales of commodities		$	145.7		$	223.8		$	117		$	3,338.70		$	17			$	-			$	(0.1	)		$	3,842.10
Fees from midstream services			70.3			25.9			147.6			124.4			-				-				-				368.2
			216			249.7			264.6			3,463.10			17				-				(0.1	)			4,210.30
Intersegment revenues
Sales of commodities			882.9			450.9			3.6			354.7			-				(1,692.1	)			-				-
Fees from midstream services			2.4			-			111.8			20.8			-				(135.0	)			-				-
			885.3			450.9			115.4			375.5			-				(1,827.1	)			-				-
Revenues		$	1,101.30		$	700.6		$	380		$	3,838.60		$	17			$	(1,827.1	)		$	(0.1	)		$	4,210.30
Operating margin		$	191.8		$	61.2		$	178.9		$	94		$	17			$	-			$	(0.3	)		$	542.6
Other financial information:
Total assets		$	3,095.90		$	385.8		$	1,407.50		$	638.8		$	14.8			$	105.2			$	77.3			$	5,725.30
Capital expenditures		$	388.8		$	15.1		$	317.7		$	2.4		$	-			$	3.1			$	-			$	727.1

The following table shows our consolidated revenues by product and service for the periods presented:

		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
Sales of commodities:
Natural gas		$	333.9		$	317.7		$	1,084.80		$	920.5
NGL			1,614.80			933.1			4,601.20			2,696.00
Condensate			38.6			35.3			108.7			95.3
Petroleum products			22.4			37.9			70.7			113.4
Derivative activities			(0.5	)		4.5			(12.1	)		16.9
			2,009.20			1,328.50			5,853.30			3,842.10
Fees from midstream services:
Fractionating and treating			55.3			36			153.5			91.1
Storage, terminaling, transportation and export			158.8			64.2			385.8			173.7
Gathering and processing			51.9			30			142.6			75.5
Other			13.1			7.3			48.5			27.9
			279.1			137.5			730.4			368.2
Total revenues		$	2,288.30		$	1,466.00		$	6,583.70		$	4,210.30

The following table shows a reconciliation of operating margin to net income for the periods presented:

		Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
Reconciliation of operating margin to net income:
Operating margin		$	295		$	199.4		$	847.8		$	542.6
Depreciation and amortization expense			(87.6	)		(69.0	)		(253.1	)		(198.7	)
General and administrative expense			(43.0	)		(37.7	)		(122.4	)		(112.5	)
Interest expense, net			(36.9	)		(33.4	)		(106.5	)		(97.9	)
Other, net			8.4			3.1			18.5			2.4
Income tax expense			(15.5	)		(13.0	)		(53.6	)		(30.3	)
Net income		$	120.4		$	49.4		$	330.7		$	105.6

Subsequent_Events

Subsequent Events	9 Months Ended
Subsequent Events	Sep. 30, 2014
Subsequent Events [Abstract]	'
Subsequent Events	'
	Note 18 — Subsequent Events

	Atlas Merger

	On October 13, 2014, we, the general partner, the Partnership and Trident MLP Merger Sub LLC, a wholly-owned subsidiary of the Partnership (“MLP Merger Sub”), entered into an Agreement and Plan of Merger (the “APL Merger Agreement”) with APL, ATLS and APL GP, the general partner of APL. Also on October 13, 2014, we and Trident GP Merger Sub LLC, a wholly-owned subsidiary of Targa (“GP Merger Sub”), entered into an Agreement and Plan of Merger (the “ATLS Merger Agreement,” and together with the APL Merger Agreement, the “Merger Agreements”) with ATLS and ATLS GP, the general partner of ATLS. Pursuant to the APL Merger Agreement, MLP Merger Sub will be merged with and into APL, with APL continuing as the surviving entity and as a wholly owned subsidiary of the Partnership. Pursuant to the ATLS Merger Agreement, GP Merger Sub will be merged with and into ATLS, with ATLS continuing as the surviving entity and as a wholly owned subsidiary of Targa. In addition, pursuant to the ATLS Merger Agreement, ATLS has agreed that it will, pursuant to a Separation and Distribution Agreement, (1) transfer its assets and liabilities other than those related to its “Atlas Pipeline Partners” segment to a limited partnership or limited liability company (“New Atlas”) and (2) immediately prior to the ATLS Merger, effect a pro rata distribution to the ATLS unitholders of New Atlas common units representing a 100% interest in New Atlas (the “Spin-Off,” and, collectively with the ATLS Merger and the APL Merger, the “Transactions”).

	The total estimated consideration for the APL Merger is $5.8 billion, including outstanding long-term debt, which as of September 30, 2014 totaled $1.8 billion. Each APL common unitholder will be entitled to receive 0.5846 of the Partnership’s common units and a one-time cash payment of $1.26 per APL common unit. This amounts to total consideration of $38.66 per APL common unit, based on the closing price of the Partnership’s common units on October 10, 2014. The exchange ratio was negotiated as a 15% premium for APL common unitholders based on the volume weighted average prices of APL and the Partnership’s common units during the 15 trading days ending October 3, 2014. The Partnership will also redeem APL’s Class E Preferred Units for an aggregate amount of $126.5 million in cash.

	The Partnership expects to finance the cash portion of APL Merger with borrowings under the TRP Revolver. In connection with the APL Merger, we have agreed to reduce our incentive distribution rights for the four years following closing by fixed amounts of $37.5 million, $25.0 million, $10.0 million and $5.0 million, respectively. These annual amounts will be applied in equal quarterly installments for each successive four quarter period following closing. Based on the Partnership’s common units outstanding and APL’s common units outstanding as of September 30, 2014, the Partnership’s current unitholders will own approximately 66% of the pro forma combined partnership and current APL common unitholders will own approximately 34%.

	The total estimated consideration for the ATLS Merger is $1.869 billion, including 10.35 million of our common stock valued at $1.259 billion based on the closing price of our common stock on October 10, 2014 and $610 million in cash. We have arranged committed financing of $1.1 billion to replace our existing revolving credit facility and to fund the cash components of the ATLS Merger, including cash merger consideration and $190 million related to change of control payments payable by ATLS and transaction fees and expenses. Based on our shares outstanding and the outstanding units of ATLS as of September 30, 2014, our current shareholders will own approximately 80% of the pro forma shares outstanding and current ATLS unitholders will own approximately 20%.

	Each of the Transactions is contingent on one another, and the Transactions are expected to close concurrently during the first quarter of 2015, subject to the approval of our stock issuance in connection with the ATLS Merger by our stockholders and the approval of the Atlas Mergers by unitholders of ATLS and APL, as applicable, regulatory approvals and other customary closing conditions.

	Debt Issuance

	In October 2014, the Partnership privately placed $800.0 million in aggregate principal amount of 4⅛% Senior Notes due 2019 (the 4⅛% Notes”). The 4⅛% Notes resulted in approximately $791.5 million of net proceeds, which were used to reduce borrowings under the TRP Revolver and the Partnership’s Securitization Facility and for general partnership purposes.

	The Partnership’s Senior Notes Redemption

	In October 2014, the Partnership announced the redemption of our 7⅞% Senior Notes due 2018 (the “7⅞% Notes”). On November 28, 2014, the Partnership will pay $259.8 million plus accrued interest per the terms of the note agreement to redeem the outstanding balance of the 7⅞% Notes. The redemption will result in a $12.4 million loss on debt redemption for the year ended 2014, consisting of premiums paid of $9.9 million and a non-cash loss to write-off $2.5 million of unamortized debt issue costs.

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	9 Months Ended
Significant Accounting Policies (Policies)	Sep. 30, 2014
Significant Accounting Policies [Abstract]	'
Accounting Policy Updates/Revisions	'
	Accounting Policy Updates/Revisions

	The accounting policies that we follow are set forth in Note 3 of the Notes to Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 2013. There were no significant updates or revisions to these policies during the nine months ended September 30, 2014.
Recent Accounting Pronouncements	'
	Recent Accounting Pronouncements

	In April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant and Equipment (Topic 360), Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. The amendment, required to be applied prospectively for reporting periods beginning after December 15, 2014, limits discontinued operations reporting to disposals of components of an entity that represent strategic shifts that have, or will have, a major effect on operations and financial results. The amendment requires expanded disclosures for discontinued operations and also requires additional disclosures regarding disposals of individually significant components that do not qualify as discontinued operations. Early adoption is permitted, but only for disposals (or classifications as held for sale) that have not been reported in financial statements previously issued or available for issuance. This amendment has no impact on our current disclosures, but will in the future if we dispose of any individually significant components.

	In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), which supersedes the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance. The update also creates a new Subtopic 340-40, Other Assets and Deferred Costs – Contracts with Customers, which provides guidance for the incremental costs of obtaining a contract with a customer and those costs incurred in fulfilling a contract with a customer that are not in the scope of another topic. The new revenue standard requires that entities should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entities expect to be entitled in exchange for those goods or services. To achieve that core principle, the standard requires a five-step process of identifying the contracts with customers, identifying the performance obligations in the contracts, determining the transaction price, allocating the transaction price to the performance obligations and recognizing revenue when, or as, the performance obligations are satisfied. The amendment also requires enhanced disclosures regarding the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers.

	The revenue recognition standard will be effective for us starting in the first quarter of 2017. Early adoption is not permitted. We must retroactively apply the new revenue recognition standard to transactions in all prior periods presented, but will have a choice between either (1) restating each prior period presented or (2) presenting a cumulative effect adjustment in our first quarter report in 2017. We have commenced our analysis of the new standard and its impact on our revenue recognition practices.

	In August 2014, the FASB issued ASU No. 2014-15, Presentation of Financial Statements—Going Concern (Subtopic 205-40), Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. The amendment is effective for the annual period beginning after December 15, 2016, and for annual and interim periods thereafter, with early adoption permitted. The amendment requires an entity’s management to evaluate for each annual and interim reporting period whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date that the financial statements are issued or available to be issued. If substantial doubt is raised, further analysis and disclosures are required, including management’s plans to mitigate the adverse conditions or events. This amendment has no impact on our current disclosures, but would if our management identified future conditions or events that, in the aggregate, raise substantial doubt about our ability to continue as a going concern.

Basis_of_Presentation_Tables

Basis of Presentation (Tables)	9 Months Ended
Basis of Presentation (Tables)	Sep. 30, 2014
Basis of Presentation [Abstract]	'
Certain Measurement Period Reclassifications Made to Comparative Statement of Cash Flows	'
	In preparing this quarterly report the Partnership has made certain reclassifications in the comparative Statement of Cash Flows for the nine months ended September 30, 2013 to conform to the presentation of its Form 10-K, reclassifying $18.9 million related to capital expenditures previously included in Accounts payable and other liabilities of operating activities to Outlays for property, plant and equipment in investing activities, as shown below.

		Nine Months Ended September 30, 2013
	Revised line items Consolidated	As Reported			Reclassification			As Revised
	Statement of Cash Flows	As Reported			Reclassification			As Revised

	Cash flows from operating activities
	Changes in operating assets and liabilities:
	Accounts payable and other liabilities	$	(5.5	)	$	18.9		$	13.4
	Net cash provided by operating activities		258.1			18.9			277

	Cash flows from investing activities:
	Changes in investing assets and liabilities:
	Outlays for property, plant and equipment		(708.2	)		(18.9	)		(727.1	)
	Net cash used in investing activities		(737.6	)		(18.9	)		(756.5	)
Revision of Previously Reported Revenues and Product Purchases	'
	The Partnership concluded that these misclassifications were not material to any of the periods affected. However, the Partnership has revised previously reported revenues and product purchases to correctly report NGL buy-sell transactions on a net basis. Accordingly, Revenues and Product Purchases reported in its Form 10-K filed on February 14, 2014 and in previous quarterly reports on Form 10-Q for 2014 and 2013 will be reduced by equal amounts as presented in the following tables. There is no impact on previously reported net income, cash flows, financial position or other profitability measures.
		Year Ended December 31,
		2013			2012			2011
	As Reported:
	Revenues	$	6,556.00		$	5,885.70		$	6,994.50
	Product Purchases		5,378.50			4,879.00			6,039.00

	Effect of Revisions:
	Revenues		(241.3	)		(206.7	)		(151.3	)
	Product Purchases		(241.3	)		(206.7	)		(151.3	)

	As Revised:
	Revenues		6,314.70			5,679.00			6,843.20
	Product Purchases		5,137.20			4,672.30			5,887.70

		Three Months Ended															Nine Months Ended			Six Months Ended
		September 30,			June 30,						March 31,						September 30,			June 30,
		2013			2014			2013			2014			2013			2013			2014			2013
	As Reported:
	Revenues	$	1,556.80		$	2,061.90		$	1,441.60		$	2,352.90		$	1,397.80		$	4,396.20		$	4,414.80		$	2,839.40
	Product Purchases		1,259.80			1,677.90			1,176.40			1,973.30			1,137.50			3,573.80			3,651.20			2,313.90

	Effect of Revisions:
	Revenues		(90.8	)		(61.3	)		(71.1	)		(58.2	)		(24.0	)		(185.9	)		(119.5	)		(95.1	)
	Product Purchases		(90.8	)		(61.3	)		(71.1	)		(58.2	)		(24.0	)		(185.9	)		(119.5	)		(95.1	)

	As Revised:
	Revenues		1,466.00			2,000.60			1,370.50			2,294.70			1,373.80			4,210.30			4,295.30			2,744.30
	Product Purchases		1,169.00			1,616.60			1,105.30			1,915.10			1,113.50			3,387.90			3,531.70			2,218.80

Inventories_Tables

Inventories (Tables)	9 Months Ended
Inventories (Tables)	Sep. 30, 2014
Inventories [Abstract]	'
Components of Inventories	'
	The components of inventories consisted of the following:

		30-Sep-14		31-Dec-13
	Commodities	$	236.6	$	136.4
	Materials and supplies		14.6		14.3
		$	251.2	$	150.7

Property_Plant_and_Equipment_a1

Property, Plant and Equipment and Intangible Assets (Tables)	9 Months Ended
	Sep. 30, 2014
Property, Plant and Equipment and Intangible Assets [Abstract]	'
Property, Plant and Equipment and Intangible Assets	'
	Property, Plant and Equipment and Intangible Assets

		30-Sep-14									31-Dec-13
		Targa			TRC Non-			Targa			Targa			TRC Non-			Targa			Estimated
		Resources			Partnership			Resources			Resources			Partnership			Resources			Useful Lives
		Partners LP						Corp.			Partners LP						Corp.			(In Years)
								Consolidated									Consolidated
	Gathering systems	$	2,438.60		$	-		$	2,438.60		$	2,230.10		$	-		$	2,230.10		5 to 20
	Processing and fractionation facilities		1,866.90			6.6			1,873.50			1,598.00			6.6			1,604.60		5 to 25
	Terminaling and storage facilities		1,004.10			-			1,004.10			715.2			-			715.2		5 to 25
	Transportation assets		358.3			-			358.3			294.7			-			294.7		10 to 25
	Other property, plant and equipment		138.1			0.2			138.3			121.3			0.2			121.5		3 to 25
	Land		90.9			-			90.9			89.5			-			89.5			-
	Construction in progress		404			-			404			702.8			-			702.8			-
	Property, plant and equipment		6,300.90			6.8			6,307.70			5,751.60			6.8			5,758.40
	Accumulated depreciation		(1,611.5	)		(2.5	)		(1,614.0	)		(1,406.2	)		(2.3	)		(1,408.5	)
	Property, plant and equipment, net	$	4,689.40		$	4.3		$	4,693.70		$	4,345.40		$	4.5		$	4,349.90

	Intangible assets	$	681.8		$	-		$	681.8		$	681.8		$	-		$	681.8			20
	Accumulated amortization		(74.5	)		-			(74.5	)		(28.4	)		-			(28.4	)
	Intangible assets, net	$	607.3		$	-		$	607.3		$	653.4		$	-		$	653.4

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2014
Asset Retirement Obligations [Abstract]	'
Changes in Aggregate Asset Retirement Obligations	'
	The changes in our aggregate asset retirement obligations are as follows:

		Nine Months Ended
		30-Sep-14
	Beginning of period	$	50.9
	Change in cash flow estimate		2.1
	Accretion expense		3.3
	End of period	$	56.3

Investment_in_Unconsolidated_A1

Investment in Unconsolidated Affiliate (Tables)	9 Months Ended
	Sep. 30, 2014
Investment in Unconsolidated Affiliate [Abstract]	'
Activity Related to Investment in Unconsolidated Affiliate	'
	The following table shows the activity related to the Partnership’s investment in GCF:

			Nine Months Ended
			30-Sep-14
	Beginning of period		$	55.9
	Equity earnings			13.8
	Cash distributions (1)			(18.0	)
	End of period		$	51.7


	-1	Includes $4.2 million distributions received in excess of the Partnership’s share of cumulative earnings that are considered a return of capital and disclosed in cash flows from investing activities in the Consolidated Statements of Cash Flows.

Accounts_Payable_and_Accrued_L1

Accounts Payable and Accrued Liabilities (Tables)	9 Months Ended
Accounts Payable and Accrued Liabilities (Tables)	Sep. 30, 2014
Accounts Payable and Accrued Liabilities [Abstract]	'
Schedule of Accounts Payable and Accrued Liabilities	'
	The components of accounts payable and accrued liabilities consisted of the following:

		30-Sep-14		31-Dec-13
	Commodities	$	573.6	$	520.8
	Other goods and services		104.9		146.8
	Interest		42.8		35.9
	Compensation and benefits		46.4		40.3
	Income and other taxes		25.5		10.2
	Other		5.4		7.8
		$	798.6	$	761.8

Debt_Obligations_Tables

Debt Obligations (Tables)	9 Months Ended
Debt Obligations (Tables)	Sep. 30, 2014
Debt Obligations [Abstract]	'
Schedule of Outstanding Debt	'
			30-Sep-14			31-Dec-13
	Long-term debt:
	Non-Partnership obligations:
	TRC Senior secured revolving credit facility, variable rate, due October 2017 (1)		$	92		$	84
	Obligations of the Partnership: (2)
	Senior secured revolving credit facility, variable rate, due October 2017 (3)			575			395
	Senior unsecured notes, 7⅞% fixed rate, due October 2018			250			250
	Senior unsecured notes, 6⅞% fixed rate, due February 2021			483.6			483.6
	Unamortized discount			(26.0	)		(28.0	)
	Senior unsecured notes, 6⅜% fixed rate, due August 2022			300			300
	Senior unsecured notes, 5¼% fixed rate, due May 2023			600			600
	Senior unsecured notes, 4¼% fixed rate, due November 2023			625			625
	Accounts receivable securitization facility, due December 2014 (4)			237.6			279.7
	Total long-term debt		$	3,137.20		$	2,989.30
	Irrevocable standby letters of credit:
	Letters of credit outstanding under TRC Senior secured credit facility (1)		$	-		$	-
	Letters of credit outstanding under the Partnership senior secured revolving credit facility (3)			42			86.8
			$	42		$	86.8


		-1	As of September 30, 2014, availability under TRC’s $150 million senior secured revolving credit facility was $58.0 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 September 30, 2014, availability under the Partnership’s $1.2 billion senior secured revolving credit facility (“TRP Revolver”) was $583.0 million.
		-4	All amounts outstanding under the Partnership’s Accounts Receivable Securitization Facility (“Securitization Facility”) are reflected as long-term debt in our Consolidated Balance Sheet because the Partnership has the ability and intent to fund the Securitization Facility’s borrowings on a long-term basis. The Partnership intends to fund the Securitization Facility’s borrowings either by further extending the termination date of the Securitization Facility or by utilizing the availability under its senior secured revolving credit facility.
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 nine months ended September 30, 2014:

			Range of Interest			Weighted Average
			Rates Incurred			Interest Rate Incurred
	TRC senior secured revolving credit facility			2.9	%		2.9	%
	Partnership's senior secured revolving credit facility			1.9% - 4.5	%		2	%
	Partnership's accounts receivable securitization facility			0.9	%		0.9	%

Partnership_Units_and_Related_1

Partnership Units and Related Matters (Tables)	9 Months Ended
Partnership Units and Related Matters (Tables)	Sep. 30, 2014
Partnership Units and Related Matters [Abstract]	'
Schedule of Distributions	'
	The following table details the distributions declared and/or paid by the Partnership for the nine months ended September 30, 2014.

			Distributions
	Three Months	Date Paid or to be	Limited		General Partner						Distributions		Distributions
	Ended	Paid	Partners								to Targa		per limited
											Resources		partner unit
			Common		Incentive			2%	Total		Corp.

	(In millions, except per unit amounts)
	30-Sep-14	14-Nov-14	$	92.3	$	36	$	2.6	$	130.9	$	48.9	$	0.7975
	30-Jun-14	14-Aug-14		89.5		33.7		2.5		125.7		46.3		0.78
	31-Mar-14	15-May-14		87.2		31.7		2.4		121.3		44		0.7625
	31-Dec-13	14-Feb-14		84		29.5		2.3		115.8		41.5		0.7475

Common_Stock_and_Related_Matte1

Common Stock and Related Matters (Tables)

9 Months Ended

Sep. 30, 2014

Common Stock and Related Matters [Abstract]

Distributions Declared and/or Paid by Partnership

The following table details the dividends declared and/or paid by us for the nine months ended September 30, 2014:

Three Months

Date Paid or To Be

Total

Amount of

Accrued

Dividend

Ended

Paid

Dividend

Dividends (1)

Declared per

Declared

Paid

Share of

Common Stock

(In millions, except per share amounts)

30-Sep-14

17-Nov-14

30.8

0.2

0.7325

30-Jun-14

15-Aug-14

29.2

0.2

0.69

31-Mar-14

16-May-14

27.4

27.2

0.2

0.6475

31-Dec-13

18-Feb-14

25.6

25.5

0.1

0.6075

-1

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

Earnings_per_Common_Share_Tabl

Earnings per Common Share (Tables)	9 Months Ended
Earnings per Common Share (Tables)	Sep. 30, 2014
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 September 30,				Nine Months Ended September 30,
		2014		2013		2014		2013
	Net income	$	120.4	$	49.4	$	330.7	$	105.6
	Less: Net income attributable to noncontrolling interests		89.7		33.1		253.9		61
	Net income attributable to common shareholders	$	30.7	$	16.3	$	76.8	$	44.6

	Weighted average shares outstanding - basic		42		41.6		42		41.6

	Net income available per common share - basic	$	0.73	$	0.39	$	1.83	$	1.07

	Weighted average shares outstanding		42		41.6		42		41.6
	Dilutive effect of unvested stock awards		0.1		0.5		0.1		0.5
	Weighted average shares outstanding - diluted		42.1		42.1		42.1		42.1

	Net income available per common share - diluted	$	0.73	$	0.39	$	1.82	$	1.06

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
Derivative Instruments and Hedging Activities (Tables)	Sep. 30, 2014
Derivative Instruments and Hedging Activities [Abstract]	'
Notional Volume of Commodity Hedges	'
	At September 30, 2014, the notional volumes of the Partnership’s commodity hedges for equity volumes were:

	Commodity		Instrument		Unit		2014				2015				2016
	Natural Gas		Swaps		MMBtu/d			66,050				50,551				25,500
	NGL		Swaps		Bbl/d			2,683				1,210				-
	Condensate		Swaps		Bbl/d			2,450				-				-
Fair Values of Derivative Instruments	'
	The following schedules reflect the fair values of our derivative instruments and their location in our Consolidated Balance Sheets as well as pro forma reporting assuming that we reported derivatives subject to master netting agreements on a net basis:

				Fair Value as of September 30, 2014								Fair Value as of December 31, 2013
		Balance Sheet		Derivative				Derivative				Derivative				Derivative
		Location		Assets				Liabilities				Assets				Liabilities
	Derivatives designated as hedging instruments
	Commodity contracts	Current		$	4.7			$	2			$	2			$	7.7
		Long-term			1.7				1.2				3.1				1.4
	Total derivatives designated as hedging instruments			$	6.4			$	3.2			$	5.1			$	9.1

	Derivatives not designated as hedging instruments
	Commodity contracts	Current		$	0.3			$	1.6			$	-			$	0.3
	Total derivatives not designated as hedging instruments			$	0.3			$	1.6			$	-			$	0.3

	Total current position			$	5			$	3.6			$	2			$	8
	Total long-term position				1.7				1.2				3.1				1.4
	Total derivatives			$	6.7			$	4.8			$	5.1			$	9.4
Pro Forma Impact of Derivatives Net In Consolidated Balance Sheet	'
	The pro forma impact of reporting derivatives in the Consolidated Balance Sheets on a net basis is as follows:

			Gross Presentation								Pro forma Net Presentation
			Asset				Liability				Asset				Liability
	30-Sep-14		Position				Position				Position				Position
	Current position
	Counterparties with offsetting position		$	4.5			$	3			$	1.5			$	-
	Counterparties without offsetting position - assets			0.5				-				0.5				-
	Counterparties without offsetting position - liabilities			-				0.6				-				0.6
				5				3.6				2				0.6
	Long-term position
	Counterparties with offsetting position			1.2				0.6				0.6				-
	Counterparties without offsetting position - assets			0.5				-				0.5				-
	Counterparties without offsetting position - liabilities			-				0.6				-				0.6
				1.7				1.2				1.1				0.6
	Total derivatives
	Counterparties with offsetting position			5.7				3.6				2.1				-
	Counterparties without offsetting position - assets			1				-				1				-
	Counterparties without offsetting position - liabilities			-				1.2				-				1.2
			$	6.7			$	4.8			$	3.1			$	1.2

	31-Dec-13
	Current position
	Counterparties with offsetting position		$	1.9			$	4.4			$	-			$	2.5
	Counterparties without offsetting position - assets			0.1				-				0.1				-
	Counterparties without offsetting position - liabilities			-				3.6				-				3.6
				2				8				0.1				6.1
	Long-term position
	Counterparties with offsetting position			0.7				1.2				-				0.5
	Counterparties without offsetting position - assets			2.4				-				2.4				-
	Counterparties without offsetting position - liabilities			-				0.2				-				0.2
				3.1				1.4				2.4				0.7
	Total derivatives
	Counterparties with offsetting position			2.6				5.6				-				3
	Counterparties without offsetting position - assets			2.5				-				2.5				-
	Counterparties without offsetting position - liabilities			-				3.8				-				3.8
			$	5.1			$	9.4			$	2.5			$	6.8
Cash Flow Hedges Included In Other Comprehensive Income	'
	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			Three Months Ended September 30,						Nine Months Ended September 30,
	Flow Hedging			Three Months Ended September 30,						Nine Months Ended September 30,
	Relationships			2014		2013				2014				2013
	Commodity contracts		$	14.2			$	(11.3	)		$	(4.5	)		$	2.4

				Gain (Loss) Reclassified from OCI into Income
				(Effective Portion)
	Location of Gain			Three Months Ended September 30,						Nine Months Ended September 30,
	(Loss)			Three Months Ended September 30,						Nine Months Ended September 30,
				2014		2013				2014				2013
	Interest expense, net		$	-			$	(1.5	)		$	(2.4	)		$	(4.7	)
	Revenues			(0.8	)			4.5				(11.6	)			17
			$	(0.8	)		$	3			$	(14.0	)		$	12.3
Schedule of Gain (Loss) On Financial Instruments	'
	The following table shows the deferred gains (losses) that are related to our consolidated accumulated OCI that will be reclassified into earnings through the end of 2016:

			30-Sep-14				31-Dec-13
	Commodity hedges, before tax (1)		$	0.4			$	(0.5	)
	Commodity hedges, after tax (1)			0.3				(0.3	)
	Interest rate hedges, before tax			-				(0.3	)
	Interest rate hedges, after tax			-				(0.2	)


	-1	Includes net losses of $2.8 million related to contracts that will be settled and reclassified to revenue over the next 12 months.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
Fair Value Measurements (Tables)	Sep. 30, 2014
Fair Value Measurements [Abstract]	'
Schedule of Fair Value of Assets and Liabilities Measured on a Recurring Basis	'
	The following table shows a breakdown by fair value hierarchy category for (1) financial instruments measurements included in our Consolidated Balance Sheets at fair value and (2) supplemental fair value disclosures for other financial instruments:

			30-Sep-14
			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)		$	6.7		$	6.7	$	-	$	6.3	$	0.4
	Liabilities from commodity derivative contracts (1)			4.8			4.8		-		4.5		0.3
	Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value:
	Cash and cash equivalents			78.8			78.8		-		-		-
	TRC Senior secured revolving credit facility			92			92		-		92		-
	Partnership's Senior secured revolving credit facility			575			575		-		575		-
	Partnership's Senior unsecured notes			2,232.60			2,310.20		-		2,310.20		-
	Partnership's accounts receivable securitization facility			237.6			237.6		-		237.6		-


	-1	The fair value of the derivative contracts in this table is presented on a different basis than the consolidated balance sheet presentation as disclosed in Note 13. The above fair values reflect the total value of each derivative contract taken as a whole, whereas the consolidated balance sheet presentation is based on the individual maturity dates of estimated future settlements. As such, an individual contract could have both an asset and liability position when segregated into its current and long-term portions for consolidated balance sheet classification purposes.
Reconciliation of the Changes in Fair Value of Financial Instruments Classified As Level 3	'
	The following table summarizes the changes in fair value of our financial instruments classified as Level 3 in the fair value hierarchy:

			Commodity Derivative
			Contracts Asset/
			(Liability)
	Balance, December 31, 2013		$	0.7
	Settlements included in Revenue			0.2
	Unrealized gain (loss) included in OCI			(0.5	)
	Transfers out of Level 3			(0.3	)
	Balance, September 30, 2014		$	0.1

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	9 Months Ended
Supplemental Cash Flow Information (Tables)	Sep. 30, 2014
Supplemental Cash Flow Information [Abstract]	'
Supplemental Cash Flow Information	'
			Nine Months Ended September 30,
			2014			2013
	Cash:
	Interest paid, net of capitalized interest (1)		$	90.3		$	83
	Income taxes paid, net of refunds			55.2			23.1
	Non-cash Investing and Financing balance sheet movements:
	Deadstock commodity inventories transferred to property, plant and equipment			15.2			28.3
	Accrued dividends on unvested equity awards			0.5			1.1
	Receivables from equity issuances			-			3.3
	Capital expenditure accruals			(40.6	)		(15.1	)
	Transfers from materials and supplies inventory to property, plant and equipment			2.7			15.1
	Change in ARO liability and property, plant and equipment due to revised future ARO cash flow estimate			2.1			1.4



	-1	Interest capitalized on major projects was $14.3 million and $22.6 million for the nine months ended September 30, 2014 and 2013.

Segment_Information_Tables

Segment Information (Tables)	9 Months Ended
Segment Information (Tables)	Sep. 30, 2014
Segment Information [Abstract]	'
Information by Segment	'
	Segment information is shown in the following tables. We have segregated the following segment information between Partnership and non-Partnership activities.

			Three Months Ended September 30, 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		$	49.4			$	83.4			$	23.1			$	1,855.60			$	(2.3	)		$	-			$	-			$	2,009.20
	Fees from midstream services			49.4				8				75.5				146.2				-				-				-				279.1
				98.8				91.4				98.6				2,001.80				(2.3	)			-				-				2,288.30
	Intersegment revenues
	Sales of commodities			386				143.6				1.3				116.1				-				(647.0	)			-				-
	Fees from midstream services			1.7				-				85.9				10.1				-				(97.7	)			-				-
				387.7				143.6				87.2				126.2				-				(744.7	)			-				-
	Revenues		$	486.5			$	235			$	185.8			$	2,128.00			$	(2.3	)		$	(744.7	)		$	-			$	2,288.30
	Operating margin		$	98			$	19.1			$	118.6			$	61.6			$	(2.3	)		$	-			$	-			$	295
	Other financial information:
	Total assets (1)		$	3,359.00			$	368.6			$	1,650.20			$	917.2			$	6.7			$	115.5			$	74.7			$	6,491.90
	Capital expenditures		$	74			$	2.3			$	59.8			$	4.6			$	-			$	2.2			$	-			$	142.9


	-1	Corporate assets primarily include investment in unconsolidated subsidiaries and debt issuance costs associated with our long-term debt.

			Three Months Ended September 30, 2013
			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		$	56.5			$	71.1			$	38.8			$	1,157.40			$	4.8			$	-			$	(0.1	)		$	1,328.50
	Fees from midstream services			27.4				7.4				53				49.7				-				-				-				137.5
				83.9				78.5				91.8				1,207.10				4.8				-				(0.1	)			1,466.00
	Intersegment revenues
	Sales of commodities			318.9				163.1				1.8				118.5				-				(602.3	)			-				-
	Fees from midstream services			0.8				-				42.1				8.4				-				(51.3	)			-				-
				319.7				163.1				43.9				126.9				-				(653.6	)			-				-
	Revenues		$	403.6			$	241.6			$	135.7			$	1,334.00			$	4.8			$	(653.6	)		$	(0.1	)		$	1,466.00
	Operating margin		$	70.6			$	21.1			$	70.5			$	32.5			$	4.8			$	-			$	(0.1	)		$	199.4
	Other financial information:
	Total assets		$	3,095.90			$	385.8			$	1,407.50			$	638.8			$	14.8			$	105.2			$	77.3			$	5,725.30
	Capital expenditures		$	177.5			$	4.3			$	99.9			$	1.7			$	-			$	1.1			$	-			$	284.5

			Nine Months Ended September 30, 2014
			Partnership
			Field				Coastal				Logistics				Marketing				Other				Corporate								Total
			Gathering				Gathering				Assets				and								and				TRC Non-
			and				and								Distribution								Eliminations				Partnership
			Processing				Processing
	Revenues
	Sales of commodities		$	158			$	273.7			$	73			$	5,361.00			$	(12.4	)		$	-			$	-			$	5,853.30
	Fees from midstream services			133.5				26.1				216.3				354.5				-				-				-				730.4
				291.5				299.8				289.3				5,715.50				(12.4	)			-				-				6,583.70
	Intersegment revenues
	Sales of commodities			1,168.20				484				2.7				383.6				-				(2,038.5	)			-				-
	Fees from midstream services			3.9				0.1				224.5				25.5				-				(254.0	)			-				-
				1,172.10				484.1				227.2				409.1				-				(2,292.5	)			-				-
	Revenues		$	1,463.60			$	783.9			$	516.5			$	6,124.60			$	(12.4	)		$	(2,292.5	)		$	-			$	6,583.70
	Operating margin		$	289.8			$	67			$	324			$	179.5			$	(12.4	)		$	-			$	(0.1	)		$	847.8
	Other financial information:
	Total assets		$	3,359.00			$	368.6			$	1,650.20			$	917.2			$	6.7			$	115.5			$	74.7			$	6,491.90
Capital expenditures		$	301.4			$	9.7			$	195.9			$	23.2			$	-			$	3.6			$	-			$	533.8

		Nine Months Ended September 30, 2013
		Partnership
		Field				Coastal				Logistics				Marketing				Other				Corporate				TRC Non-				Total
		Gathering				Gathering				Assets				and								and				Partnership
		and				and								Distribution								Eliminations
		Processing				Processing
Revenues
Sales of commodities		$	145.7			$	223.8			$	117			$	3,338.70			$	17			$	-			$	(0.1	)		$	3,842.10
Fees from midstream services			70.3				25.9				147.6				124.4				-				-				-				368.2
			216				249.7				264.6				3,463.10				17				-				(0.1	)			4,210.30
Intersegment revenues
Sales of commodities			882.9				450.9				3.6				354.7				-				(1,692.1	)			-				-
Fees from midstream services			2.4				-				111.8				20.8				-				(135.0	)			-				-
			885.3				450.9				115.4				375.5				-				(1,827.1	)			-				-
Revenues		$	1,101.30			$	700.6			$	380			$	3,838.60			$	17			$	(1,827.1	)		$	(0.1	)		$	4,210.30
Operating margin		$	191.8			$	61.2			$	178.9			$	94			$	17			$	-			$	(0.3	)		$	542.6
Other financial information:
Total assets		$	3,095.90			$	385.8			$	1,407.50			$	638.8			$	14.8			$	105.2			$	77.3			$	5,725.30
Capital expenditures		$	388.8			$	15.1			$	317.7			$	2.4			$	-			$	3.1			$	-			$	727.1
Revenues by Product and Service	'
	The following table shows our consolidated revenues by product and service for the periods presented:

			Three Months Ended								Nine Months Ended
			September 30,								September 30,
			2014				2013				2014				2013
	Sales of commodities:
	Natural gas		$	333.9			$	317.7			$	1,084.80			$	920.5
	NGL			1,614.80				933.1				4,601.20				2,696.00
	Condensate			38.6				35.3				108.7				95.3
	Petroleum products			22.4				37.9				70.7				113.4
	Derivative activities			(0.5	)			4.5				(12.1	)			16.9
				2,009.20				1,328.50				5,853.30				3,842.10
	Fees from midstream services:
	Fractionating and treating			55.3				36				153.5				91.1
	Storage, terminaling, transportation and export			158.8				64.2				385.8				173.7
	Gathering and processing			51.9				30				142.6				75.5
	Other			13.1				7.3				48.5				27.9
				279.1				137.5				730.4				368.2
	Total revenues		$	2,288.30			$	1,466.00			$	6,583.70			$	4,210.30
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								Nine Months Ended
			September 30,								September 30,
			2014				2013				2014				2013
	Reconciliation of operating margin to net income:
	Operating margin		$	295			$	199.4			$	847.8			$	542.6
	Depreciation and amortization expense			(87.6	)			(69.0	)			(253.1	)			(198.7	)
	General and administrative expense			(43.0	)			(37.7	)			(122.4	)			(112.5	)
	Interest expense, net			(36.9	)			(33.4	)			(106.5	)			(97.9	)
	Other, net			8.4				3.1				18.5				2.4
	Income tax expense			(15.5	)			(13.0	)			(53.6	)			(30.3	)
	Net income		$	120.4			$	49.4			$	330.7			$	105.6

Basis_of_Presentation_Details

Basis of Presentation (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

6 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

6 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

6 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

In Millions, except Share data, unless otherwise specified

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Jun. 30, 2014

Mar. 31, 2014

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 30, 2014

Mar. 31, 2014

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 30, 2014

Mar. 31, 2014

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 30, 2014

As Reported [Member]

Reclassification / Effect of Revisions [Member]

As Revised [Member]

Limited Partner [Member]

Partnership Ownership Disclosure [Abstract]

General partner ownership interest (in hundredths)

2.00%

11.20%

Parent's percentage ownership in the general partner of the Partnership

100.00%

Number of Partnership common units owned (in units)

12,945,659

Changes in operating assets and liabilities [Abstract]

Accounts payable and other liabilities

$80

$13.40

($5.50)

$18.90

$13.40

Net cash provided by operating activities

519.1

277

258.1

18.9

277

Changes in investing assets and liabilities [Abstract]

Outlays for property, plant and equipment

-571.7

-727.1

-708.2

-18.9

-727.1

Net cash used in investing activities

-561.2

-756.5

-737.6

-18.9

-756.5

Revision of Previously Reported Revenues and Product Purchases [Abstract]

Revenues

2,288.30

1,466

6,583.70

4,210.30

2,061.90

2,352.90

1,556.80

1,441.60

1,397.80

4,414.80

2,839.40

4,396.20

6,556

5,885.70

6,994.50

-61.3

-58.2

-90.8

-71.1

-24

-119.5

-95.1

-185.9

-241.3

-206.7

-151.3

2,000.60

2,294.70

1,466

1,370.50

1,373.80

4,295.30

2,744.30

4,210.30

6,314.70

5,679

6,843.20

Product purchases

$1,880.50

$1,169

$5,412.20

$3,387.90

$1,677.90

$1,973.30

$1,259.80

$1,176.40

$1,137.50

$3,651.20

$2,313.90

$3,573.80

$5,378.50

$4,879

$6,039

($61.30)

($58.20)

($90.80)

($71.10)

($24)

($119.50)

($95.10)

($185.90)

($241.30)

($206.70)

($151.30)

$1,616.60

$1,915.10

$1,169

$1,105.30

$1,113.50

$3,531.70

$2,218.80

$3,387.90

$5,137.20

$4,672.30

$5,887.70

Inventories_Details

Inventories (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Inventories [Abstract]	'	'
Commodities	$236.60	$136.40
Materials and supplies	14.6	14.3
Inventories, Net	$251.20	$150.70

Property_Plant_and_Equipment_a2

Property, Plant and Equipment and Intangible Assets (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	$6,307.70	$5,758.40
Accumulated depreciation	-1,614	-1,408.50
Property, plant and equipment, net	4,693.70	4,349.90
Finite-Lived Intangible Assets [Line Items]	'	'
Estimated useful lives	'20 years	'
Estimated annual amortization expense for intangible assets [Abstract]	'	'
2014	61.4	'
2015	80.1	'
2016	88.3	'
2017	81.5	'
2018	67.8	'
Gathering Systems [Member] \| Minimum [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Estimated useful life	'5 years	'
Gathering Systems [Member] \| Maximum [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Estimated useful life	'20 years	'
Processing and Fractionation Facilities [Member] \| Minimum [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Estimated useful life	'5 years	'
Processing and Fractionation Facilities [Member] \| Maximum [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Estimated useful life	'25 years	'
Terminaling and Storage Facilities [Member] \| Minimum [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Estimated useful life	'5 years	'
Terminaling and Storage Facilities [Member] \| Maximum [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Estimated useful life	'25 years	'
Transportation Assets [Member] \| Minimum [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Estimated useful life	'10 years	'
Transportation Assets [Member] \| Maximum [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Estimated useful life	'25 years	'
Other Property, Plant and Equipment [Member] \| Minimum [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Estimated useful life	'3 years	'
Other Property, Plant and Equipment [Member] \| Maximum [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Estimated useful life	'25 years	'
Targa Resources Partners LP [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	6,300.90	5,751.60
Accumulated depreciation	-1,611.50	-1,406.20
Property, plant and equipment, net	4,689.40	4,345.40
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible assets	681.8	681.8
Accumulated amortization	-74.5	-28.4
Intangible assets, net	607.3	653.4
Targa Resources Partners LP [Member] \| Gathering Systems [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	2,438.60	2,230.10
Targa Resources Partners LP [Member] \| Processing and Fractionation Facilities [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	1,866.90	1,598
Targa Resources Partners LP [Member] \| Terminaling and Storage Facilities [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	1,004.10	715.2
Targa Resources Partners LP [Member] \| Transportation Assets [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	358.3	294.7
Targa Resources Partners LP [Member] \| Other Property, Plant and Equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	138.1	121.3
Targa Resources Partners LP [Member] \| Land [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	90.9	89.5
Targa Resources Partners LP [Member] \| Construction in Progress [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	404	702.8
TRC Non Partnership [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	6.8	6.8
Accumulated depreciation	-2.5	-2.3
Property, plant and equipment, net	4.3	4.5
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
Targa Resources Corp. Consolidated [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	6,307.70	5,758.40
Accumulated depreciation	-1,614	-1,408.50
Property, plant and equipment, net	4,693.70	4,349.90
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible assets	681.8	681.8
Accumulated amortization	-74.5	-28.4
Intangible assets, net	607.3	653.4
Targa Resources Corp. Consolidated [Member] \| Gathering Systems [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	2,438.60	2,230.10
Targa Resources Corp. Consolidated [Member] \| Processing and Fractionation Facilities [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	1,873.50	1,604.60
Targa Resources Corp. Consolidated [Member] \| Terminaling and Storage Facilities [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	1,004.10	715.2
Targa Resources Corp. Consolidated [Member] \| Transportation Assets [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	358.3	294.7
Targa Resources Corp. Consolidated [Member] \| Other Property, Plant and Equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	138.3	121.5
Targa Resources Corp. Consolidated [Member] \| Land [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	90.9	89.5
Targa Resources Corp. Consolidated [Member] \| Construction in Progress [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, plant and equipment	$404	$702.80

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Changes in aggregate asset retirement obligations [Roll Forward]	'	'
Beginning of period	$50.90	'
Change in cash flow estimate	2.1	1.4
Accretion expense	3.3	3
End of period	$56.30	'

Investment_in_Unconsolidated_A2

Investment in Unconsolidated Affiliate (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014		Sep. 30, 2013
Equity Method Investments [Line Items]	'	'	'		'
Beginning of period	'	'	$55.90		'
Equity earnings	4.7	5.6	13.8		10.1
End of period	51.7	'	51.7		'
Return of capital from unconsolidated affiliate	'	'	4.2		1.9
Gulf Coast Fractionators LP [Member]	'	'	'		'
Equity Method Investments [Line Items]	'	'	'		'
Ownership interest (in hundredths)	38.80%	'	38.80%		'
Beginning of period	'	'	55.9		'
Equity earnings	'	'	13.8		'
Cash distributions	'	'	-18	[1]	'
End of period	$51.70	'	$51.70		'

[1]	Includes $4.2 million distributions received in excess of the Partnership's share of cumulative earnings that are considered a return of capital and disclosed in cash flows from investing activities in the Consolidated Statements of Cash Flows.

Accounts_Payable_and_Accrued_L2

Accounts Payable and Accrued Liabilities (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Accounts Payable and Accrued Liabilities [Abstract]	'	'
Commodities	$573.60	$520.80
Other goods and services	104.9	146.8
Interest	42.8	35.9
Compensation and benefits	46.4	40.3
Income and other taxes	25.5	10.2
Other	5.4	7.8
Total accounts payable and accrued liabilities	$798.60	$761.80

Debt_Obligations_Details

Debt Obligations (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Dec. 31, 2013
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	$3,137.20		$2,989.30
Letters of credit outstanding	42		86.8
Revolving Credit Facility [Member] \| TRC Senior Secured Revolving Credit Facility due 2017 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	92	[1]	84	[1]
Maturity date	31-Oct-17		'
Letters of credit outstanding	0	[1]	0	[1]
Maximum borrowing capacity	150		'
Remaining borrowing capacity	58		'
Range of interest rates and weighted average interest rate [Abstract]	'		'
Interest Rates Incurred (in hundredths)	2.90%		'
Weighted Average Interest Rate Incurred (in hundredths)	2.90%		'
Targa Resources Partners LP [Member] \| Revolving Credit Facility [Member] \| TRP Senior Secured Revolving Credit Facility due 2017 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	575	[2],[3]	395	[2],[3]
Maturity date	31-Oct-17		'
Letters of credit outstanding	42	[3]	86.8	[3]
Maximum borrowing capacity	1,200		'
Remaining borrowing capacity	583		'
Range of interest rates and weighted average interest rate [Abstract]	'		'
Range of Interest Rates Incurred, Minimum (in hundredths)	1.90%		'
Range of Interest Rates Incurred, Maximum (in hundredths)	4.50%		'
Weighted Average Interest Rate Incurred (in hundredths)	2.00%		'
Targa Resources Partners LP [Member] \| Senior Unsecured Notes [Member] \| Senior Unsecured 7 7/8% Notes due October 2018 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	250	[2]	250	[2]
Interest rate on fixed rate debt (in hundredths)	7.88%		'
Maturity date	31-Oct-18		'
Targa Resources Partners LP [Member] \| Senior Unsecured Notes [Member] \| Senior Unsecured 6 7/8% Notes due February 2021 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	483.6	[2]	483.6	[2]
Unamortized discount	-26	[2]	-28	[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]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	300	[2]	300	[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]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	600	[2]	600	[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]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	625	[2]	625	[2]
Interest rate on fixed rate debt (in hundredths)	4.25%		'
Maturity date	30-Nov-23		'
Targa Resources Partners LP [Member] \| Accounts receivable securitization facility [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	$237.60	[2],[4]	$279.70	[2],[4]
Maturity date	31-Dec-14		'
Targa Resources Partners LP [Member] \| Accounts receivable securitization facility [Member] \| Partnership's Accounts Receivable Securitization Facility due 2014 [Member]	'		'
Range of interest rates and weighted average interest rate [Abstract]	'		'
Interest Rates Incurred (in hundredths)	0.90%		'
Weighted Average Interest Rate Incurred (in hundredths)	0.90%		'

[1]	As of September 30, 2014, availability under TRC's $150 million senior secured revolving credit facility was $58.0 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 September 30, 2014, availability under the Partnership's $1.2 billion senior secured revolving credit facility ("TRP Revolver") was $583.0 million.
[4]	All amounts outstanding under the Partnership's Securitization Facility are reflected as long-term debt in our Consolidated Balance Sheet because the Partnership has the ability and intent to fund the Securitization Facility's borrowings on a long-term basis. The Partnership intends to fund the Securitization Facility's borrowings either by further extending the termination date of the Securitization Facility or by utilizing the availability under its senior secured revolving credit facility.

Partnership_Units_and_Related_2

Partnership Units and Related Matters (Details) (USD $)	3 Months Ended				9 Months Ended	1 Months Ended	9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2014	Oct. 24, 2014	Sep. 30, 2014	Sep. 30, 2014	Oct. 24, 2014
						Subsequent Event [Member]	August 2013 EDA [Member]	May 2014 EDA [Member]	May 2014 EDA [Member]
									Subsequent Event [Member]
Partnership Equity [Abstract]	'	'	'	'	'	'	'	'	'
Number of common units sold (in shares)	'	'	'	'	'	'	3,119,454	1,243,682	'
Net proceeds from sale of common units	'	'	'	'	'	'	$169.50	$87.70	'
Commissions to sales agents, maximum (in hundredths)	'	'	'	'	'	'	1.00%	1.00%	'
General partner contributed to maintain general partner ownership percentage	'	'	'	'	'	0.4	3.5	1.8	'
General partner ownership interest (in hundredths)	'	'	'	'	2.00%	'	2.00%	2.00%	'
Amount which remain available under the shelf agreement	'	'	'	'	'	'	'	'	311.3
Dollar amount of common units able to sell from equity distribution agreement	'	'	'	'	'	'	'	400	'
Number of days from end of each quarter by when cash is distributed to unit holders	'	'	'	'	'45 days	'	'	'	'
Date paid or to be paid	14-Nov-14	14-Aug-14	15-May-14	14-Feb-14	'	'	'	'	'
Distributions Paid Limited Partners Common	92.3	89.5	87.2	84	'	'	'	'	'
Distributions to General Partners (Incentive)	36	33.7	31.7	29.5	'	'	'	'	'
Distributions to General Partners (2%)	2.6	2.5	2.4	2.3	'	'	'	'	'
Total distributions to general and limited partners	130.9	125.7	121.3	115.8	'	'	'	'	'
Distributions to Targa Resources Corp.	$48.90	$46.30	$44	$41.50	'	'	'	'	'
Distributions per limited partner per unit (in dollars per unit)	$0.80	$0.78	$0.76	$0.75	'	'	'	'	'

Common_Stock_and_Related_Matte2

Common Stock and Related Matters (Details) (USD $)	9 Months Ended		3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2013
	Sep. 30, 2014	Sep. 30, 2013	Dividend Declared, Q3 2014 [Member]		Dividend declared, Q2 2014 [Member]		Dividend declared, Q1 2014 [Member]		Dividend Declared, Q4 2013 [Member]
Dividends Payable [Line Items]	'	'	'		'		'		'
Date paid or to be paid	'	'	17-Nov-14		15-Aug-14		16-May-14		18-Feb-14
Total dividend declared	'	'	$31		$29.20		$27.40		$25.60
Amount of dividend paid	82.2	61.8	30.8		29		27.2		25.5
Accrued dividends	'	'	$0.20	[1]	$0.20	[1]	$0.20	[1]	$0.10	[1]
Dividend declared per share of common stock (in dollars per share)	'	'	$0.73		$0.69		$0.65		$0.61

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

Earnings_per_Common_Share_Deta

Earnings per Common Share (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Earnings per Common Share [Abstract]	'	'	'	'
Net income	$120.40	$49.40	$330.70	$105.60
Less: Net income attributable to noncontrolling interests	89.7	33.1	253.9	61
Net income attributable to common shareholders	$30.70	$16.30	$76.80	$44.60
Weighted average shares outstanding - basic (in shares)	42	41.6	42	41.6
Net income available per common share - basic (in dollars per share)	$0.73	$0.39	$1.83	$1.07
Weighted average shares outstanding (in shares)	42	41.6	42	41.6
Dilutive effect of unvested stock awards (in shares)	0.1	0.5	0.1	0.5
Weighted average shares outstanding - diluted (in shares)	42.1	42.1	42.1	42.1
Net income available per common share - diluted (in dollars per share)	$0.73	$0.39	$1.82	$1.06

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014
	MMBTU
Derivative Line [Items]	'
Derivative financial instruments, fair value, net	1.9
Cash flow interest rate swaps deferred net loss to be reclassified within twelve months	2.8
Instruments - Swaps [Member] \| Year 2014 [Member] \| Natural Gas [Member]	'
Derivative Line [Items]	'
Notional volumes of commodity hedges (MMBtu per day)	66,050
Instruments - Swaps [Member] \| Year 2014 [Member] \| NGL [Member]	'
Derivative Line [Items]	'
Notional volumes of commodity hedges (Bbl per day)	2,683
Instruments - Swaps [Member] \| Year 2014 [Member] \| Condensate [Member]	'
Derivative Line [Items]	'
Notional volumes of commodity hedges (Bbl per day)	2,450
Instruments - Swaps [Member] \| Year 2015 [Member] \| Natural Gas [Member]	'
Derivative Line [Items]	'
Notional volumes of commodity hedges (MMBtu per day)	50,551
Instruments - Swaps [Member] \| Year 2015 [Member] \| NGL [Member]	'
Derivative Line [Items]	'
Notional volumes of commodity hedges (Bbl per day)	1,210
Instruments - Swaps [Member] \| Year 2015 [Member] \| Condensate [Member]	'
Derivative Line [Items]	'
Notional volumes of commodity hedges (Bbl per day)	0
Instruments - Swaps [Member] \| Year 2016 [Member] \| Natural Gas [Member]	'
Derivative Line [Items]	'
Notional volumes of commodity hedges (MMBtu per day)	25,500
Instruments - Swaps [Member] \| Year 2016 [Member] \| NGL [Member]	'
Derivative Line [Items]	'
Notional volumes of commodity hedges (Bbl per day)	0
Instruments - Swaps [Member] \| Year 2016 [Member] \| Condensate [Member]	'
Derivative Line [Items]	'
Notional volumes of commodity hedges (Bbl per day)	0

Derivative_Instruments_and_Hed3

Derivative Instruments and Hedging Activities, Derivative Instruments and Hedging Activities, Fair Values Derivatives, Balance Sheet Location, by Derivative Contract Type (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Derivative Assets [Abstract]	'	'
Current assets	$5	$2
Long-term assets	1.7	3.1
Total derivative assets	6.7	5.1
Derivative Liabilities [Abstract]	'	'
Current liabilities	3.6	8
Long-term liabilities	1.2	1.4
Total derivative liabilities	4.8	9.4
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Fair value, net	1.9	'
Asset Position [Member] \| Gross Presentation [Member]	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Counterparties with offsetting position	5.7	2.6
Counterparties without offsetting position - assets	1	2.5
Counterparties without offsetting position - liabilities	0	0
Fair value, net	6.7	5.1
Asset Position [Member] \| Pro-forma Net Presentation [Member]	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Counterparties with offsetting position	2.1	0
Counterparties without offsetting position - assets	1	2.5
Counterparties without offsetting position - liabilities	0	0
Fair value, net	3.1	2.5
Liability Position [Member] \| Gross Presentation [Member]	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Counterparties with offsetting position	3.6	5.6
Counterparties without offsetting position - assets	0	0
Counterparties without offsetting position - liabilities	1.2	3.8
Fair value, net	4.8	9.4
Liability Position [Member] \| Pro-forma Net Presentation [Member]	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Counterparties with offsetting position	0	3
Counterparties without offsetting position - assets	0	0
Counterparties without offsetting position - liabilities	1.2	3.8
Fair value, net	1.2	6.8
Current Position [Member] \| Asset Position [Member] \| Gross Presentation [Member]	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Counterparties with offsetting position	4.5	1.9
Counterparties without offsetting position - assets	0.5	0.1
Counterparties without offsetting position - liabilities	0	0
Fair value, net	5	2
Current Position [Member] \| Asset Position [Member] \| Pro-forma Net Presentation [Member]	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Counterparties with offsetting position	1.5	0
Counterparties without offsetting position - assets	0.5	0.1
Counterparties without offsetting position - liabilities	0	0
Fair value, net	2	0.1
Current Position [Member] \| Liability Position [Member] \| Gross Presentation [Member]	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Counterparties with offsetting position	3	4.4
Counterparties without offsetting position - assets	0	0
Counterparties without offsetting position - liabilities	0.6	3.6
Fair value, net	3.6	8
Current Position [Member] \| Liability Position [Member] \| Pro-forma Net Presentation [Member]	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Counterparties with offsetting position	0	2.5
Counterparties without offsetting position - assets	0	0
Counterparties without offsetting position - liabilities	0.6	3.6
Fair value, net	0.6	6.1
Long-term Position [Member] \| Asset Position [Member] \| Gross Presentation [Member]	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Counterparties with offsetting position	1.2	0.7
Counterparties without offsetting position - assets	0.5	2.4
Counterparties without offsetting position - liabilities	0	0
Fair value, net	1.7	3.1
Long-term Position [Member] \| Asset Position [Member] \| Pro-forma Net Presentation [Member]	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Counterparties with offsetting position	0.6	0
Counterparties without offsetting position - assets	0.5	2.4
Counterparties without offsetting position - liabilities	0	0
Fair value, net	1.1	2.4
Long-term Position [Member] \| Liability Position [Member] \| Gross Presentation [Member]	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Counterparties with offsetting position	0.6	1.2
Counterparties without offsetting position - assets	0	0
Counterparties without offsetting position - liabilities	0.6	0.2
Fair value, net	1.2	1.4
Long-term Position [Member] \| Liability Position [Member] \| Pro-forma Net Presentation [Member]	'	'
Pro forma impact of reporting derivatives in the Consolidated Balance Sheet [Abstract]	'	'
Counterparties with offsetting position	0	0.5
Counterparties without offsetting position - assets	0	0
Counterparties without offsetting position - liabilities	0.6	0.2
Fair value, net	0.6	0.7
Designated as Hedging Instrument [Member] \| Commodity Contracts [Member]	'	'
Derivative Assets [Abstract]	'	'
Current assets	4.7	2
Long-term assets	1.7	3.1
Total derivative assets	6.4	5.1
Derivative Liabilities [Abstract]	'	'
Current liabilities	2	7.7
Long-term liabilities	1.2	1.4
Total derivative liabilities	3.2	9.1
Not Designated as Hedging Instrument [Member] \| Commodity Contracts [Member]	'	'
Derivative Assets [Abstract]	'	'
Current assets	0.3	0
Total derivative assets	0.3	0
Derivative Liabilities [Abstract]	'	'
Current liabilities	1.6	0.3
Total derivative liabilities	$1.60	$0.30

Derivative_Instruments_and_Hed4

Derivative Instruments and Hedging Activities, Derivative Instruments and Hedging Activities, Derivative Instruments, Gain (Loss) by Hedging Relationship, by Income Statement Location, by Derivative Instrument Risk (Details) (USD $)	3 Months Ended			9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013	Sep. 30, 2014		Sep. 30, 2013	Dec. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]	'		'	'		'	'
Gain (Loss) Reclassified from OCI into Income - Effective Portion	($0.80)		$3	($14)		$12.30	'
Revenue [Member]	'		'	'		'	'
Derivative Instruments, Gain (Loss) [Line Items]	'		'	'		'	'
Gain (Loss) Reclassified from OCI into Income - Effective Portion	-0.8		4.5	-11.6		17	'
Interest Expense, Net [Member]	'		'	'		'	'
Derivative Instruments, Gain (Loss) [Line Items]	'		'	'		'	'
Gain (Loss) Reclassified from OCI into Income - Effective Portion	0		-1.5	-2.4		-4.7	'
Commodity Contracts [Member]	'		'	'		'	'
Derivative Instruments, Gain (Loss) [Line Items]	'		'	'		'	'
Gain (Loss) Recognized in OCI - Effective Portion	14.2		-11.3	-4.5		2.4	'
Unrealized gain (loss) on hedges, before tax	0.4	[1]	'	0.4	[1]	'	-0.5	[1]
Unrealized gain (loss) on hedges, after tax	0.3	[1]	'	0.3	[1]	'	-0.3	[1]
Interest Rate Swap [Member]	'		'	'		'	'
Derivative Instruments, Gain (Loss) [Line Items]	'		'	'		'	'
Unrealized gain (loss) on hedges, before tax	0		'	0		'	-0.3
Unrealized gain (loss) on hedges, after tax	$0		'	$0		'	($0.20)

[1]	Includes net losses of $2.8 million 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 $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014
	Swap
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]	'
Assets from commodity derivative contracts	$6.70	[1]
Liabilities from commodity derivative contracts	4.8	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]	'
Cash and cash equivalents	78.8
TRC Senior secured revolving credit facility	92
Partnership's Senior secured revolving credit facility	575
Partnership's Senior unsecured notes	2,310.20
Partnership's accounts receivable securitization facility	237.6
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Derivative fair value commodity price increases 10 percent, net liability	13.7
Derivative fair value commodity price decreases 10 percent, net asset	17.5
Number of natural gas basis swaps categorized as Level 3	5
Commodity Derivative Contracts Asset/ (Liability) [Member]	'
Fair Value, Liabilities/Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'
Balance, December 31, 2013	0.7
Settlements included in Revenue	0.2
Unrealized gain (loss) included in OCI	-0.5
Transfers out of Level 3	-0.3
Balance, September 30, 2014	0.1
Fair Value, Inputs, 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
TRC Senior secured revolving credit facility	0
Partnership's Senior secured revolving credit facility	0
Partnership's Senior unsecured notes	0
Partnership's accounts receivable securitization facility	0
Fair Value, Inputs, Level 2 [Member]	'
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]	'
Assets from commodity derivative contracts	6.3	[1]
Liabilities from commodity derivative contracts	4.5	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]	'
Cash and cash equivalents	0
TRC Senior secured revolving credit facility	92
Partnership's Senior secured revolving credit facility	575
Partnership's Senior unsecured notes	2,310.20
Partnership's accounts receivable securitization facility	237.6
Fair Value, Inputs, Level 3 [Member]	'
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]	'
Assets from commodity derivative contracts	0.4	[1]
Liabilities from commodity derivative contracts	0.3	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]	'
Cash and cash equivalents	0
TRC Senior secured revolving credit facility	0
Partnership's Senior secured revolving credit facility	0
Partnership's Senior unsecured notes	0
Partnership's accounts receivable securitization facility	0
Carrying (Reported) Amount, Fair Value Disclosure [Member]	'
Financial Instruments Recorded on Our Consolidated Balance Sheets at Fair Value [Abstract]	'
Assets from commodity derivative contracts	6.7	[1]
Liabilities from commodity derivative contracts	4.8	[1]
Financial Instruments Recorded on Our Consolidated Balance Sheets at Carrying Value [Abstract]	'
Cash and cash equivalents	78.8
TRC Senior secured revolving credit facility	92
Partnership's Senior secured revolving credit facility	575
Partnership's Senior unsecured notes	2,232.60
Partnership's accounts receivable securitization facility	$237.60

[1]	The fair value of the derivative contracts in this table is presented on a different basis than the balance sheet presentation as disclosed in Note 13. The above fair values reflect the total value of each derivative contract taken as a whole, whereas the balance sheet presentation is based on the individual maturity dates of estimated future settlements. As such, an individual contract could have both an asset and liability position when segregated into its current and long-term portions for balance sheet classification purposes.

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (Badlands [Member], USD $)	3 Months Ended	9 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2012
Badlands [Member]	'	'	'
Business Acquisition Contingent Consideration [Line Items]	'	'	'
Contingent consideration	'	'	$50
Fair value of contingent consideration	'	0	15.3
Decrease in contingent consideration	$9.10	$15.30	'

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013
Cash [Abstract]	'		'
Interest paid, net of capitalized interest	$90.30	[1]	$83	[1]
Income taxes paid, net of refunds	55.2		23.1
Non-cash Investing and Financing balance sheet movements:	'		'
Deadstock commodity inventories transferred to property, plant and equipment	15.2		28.3
Accrued dividends on unvested equity awards	0.5		1.1
Receivables from equity issuances	0		3.3
Capital expenditure accruals	-40.6		-15.1
Transfers from materials and supplies inventory to property, plant and equipment	2.7		15.1
Change in ARO liability and property, plant and equipment due to revised future ARO cash flow estimate	2.1		1.4
Interest capitalized on major projects	$14.30		$22.60

[1]	Interest capitalized on major projects was $14.3 million and $22.6 million for the nine months ended September 30, 2014 and 2013.

Segment_Information_Details

Segment Information (Details) (USD $)	3 Months Ended			9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014		Sep. 30, 2013	Sep. 30, 2014		Sep. 30, 2013	Dec. 31, 2013
				Division
				Segment
Segment Information [Abstract]	'		'	'		'	'
Number of divisions	'		'	2		'	'
Number of reportable segments for Gathering and Processing Division	'		'	2		'	'
Number of reportable segments for Logistics and Marketing Division	'		'	2		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	$2,009.20		$1,328.50	$5,853.30		$3,842.10	'
Fees from midstream services	279.1		137.5	730.4		368.2	'
Revenues	2,288.30		1,466	6,583.70		4,210.30	'
Operating Margin	295		199.4	847.8		542.6	'
Total assets	6,491.90		5,725.30	6,491.90		5,725.30	6,048.60
Capital Expenditures	142.9		284.5	533.8		727.1	'
Depreciation and amortization expenses	-87.6		-69	-253.1		-198.7	'
General and administrative expenses	-43		-37.7	-122.4		-112.5	'
Interest expense, net	-36.9		-33.4	-106.5		-97.9	'
Other, net	8.4		3.1	18.5		2.4	'
Income tax expense	-15.5		-13	-53.6		-30.3	'
Net income	120.4		49.4	330.7		105.6	'
Other Segment [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Revenues	-2.3		4.8	-12.4		17	'
Operating Margin	-2.3		4.8	-12.4		17	'
Total assets	6.7	[1]	14.8	6.7	[1]	14.8	'
Capital Expenditures	0		0	0		0	'
Corporate and Eliminations [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Revenues	-744.7		-653.6	-2,292.50		-1,827.10	'
Operating Margin	0		0	0		0	'
Total assets	115.5	[1]	105.2	115.5	[1]	105.2	'
Capital Expenditures	2.2		1.1	3.6		3.1	'
TRC Non- Partnership [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Revenues	0		-0.1	0		-0.1	'
Operating Margin	0		-0.1	-0.1		-0.3	'
Total assets	74.7	[1]	77.3	74.7	[1]	77.3	'
Capital Expenditures	0		0	0		0	'
Natural gas sales [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	333.9		317.7	1,084.80		920.5	'
NGL sales [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	1,614.80		933.1	4,601.20		2,696	'
Condensate sales [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	38.6		35.3	108.7		95.3	'
Petroleum products [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	22.4		37.9	70.7		113.4	'
Derivative activities [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	-0.5		4.5	-12.1		16.9	'
Fractionating and treating fees [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Fees from midstream services	55.3		36	153.5		91.1	'
Storage, terminaling, transportation and export fees [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Fees from midstream services	158.8		64.2	385.8		173.7	'
Gathering and processing fees [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Fees from midstream services	51.9		30	142.6		75.5	'
Other [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Fees from midstream services	13.1		7.3	48.5		27.9	'
Reportable Segments [Member] \| Field Gathering and Processing [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Revenues	486.5		403.6	1,463.60		1,101.30	'
Operating Margin	98		70.6	289.8		191.8	'
Total assets	3,359	[1]	3,095.90	3,359	[1]	3,095.90	'
Capital Expenditures	74		177.5	301.4		388.8	'
Reportable Segments [Member] \| Coastal Gathering and Processing [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Revenues	235		241.6	783.9		700.6	'
Operating Margin	19.1		21.1	67		61.2	'
Total assets	368.6	[1]	385.8	368.6	[1]	385.8	'
Capital Expenditures	2.3		4.3	9.7		15.1	'
Reportable Segments [Member] \| Logistics Assets [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Revenues	185.8		135.7	516.5		380	'
Operating Margin	118.6		70.5	324		178.9	'
Total assets	1,650.20	[1]	1,407.50	1,650.20	[1]	1,407.50	'
Capital Expenditures	59.8		99.9	195.9		317.7	'
Reportable Segments [Member] \| Marketing and Distribution [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Revenues	2,128		1,334	6,124.60		3,838.60	'
Operating Margin	61.6		32.5	179.5		94	'
Total assets	917.2	[1]	638.8	917.2	[1]	638.8	'
Capital Expenditures	4.6		1.7	23.2		2.4	'
Total Outside Revenues [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	2,009.20		1,328.50	5,853.30		3,842.10	'
Fees from midstream services	279.1		137.5	730.4		368.2	'
Revenues	2,288.30		1,466	6,583.70		4,210.30	'
Total Outside Revenues [Member] \| Field Gathering and Processing [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	49.4		56.5	158		145.7	'
Fees from midstream services	49.4		27.4	133.5		70.3	'
Revenues	98.8		83.9	291.5		216	'
Total Outside Revenues [Member] \| Coastal Gathering and Processing [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	83.4		71.1	273.7		223.8	'
Fees from midstream services	8		7.4	26.1		25.9	'
Revenues	91.4		78.5	299.8		249.7	'
Total Outside Revenues [Member] \| Logistics Assets [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	23.1		38.8	73		117	'
Fees from midstream services	75.5		53	216.3		147.6	'
Revenues	98.6		91.8	289.3		264.6	'
Total Outside Revenues [Member] \| Marketing and Distribution [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	1,855.60		1,157.40	5,361		3,338.70	'
Fees from midstream services	146.2		49.7	354.5		124.4	'
Revenues	2,001.80		1,207.10	5,715.50		3,463.10	'
Total Outside Revenues [Member] \| Other Segment [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	-2.3		4.8	-12.4		17	'
Fees from midstream services	0		0	0		0	'
Revenues	-2.3		4.8	-12.4		17	'
Total Outside Revenues [Member] \| Corporate and Eliminations [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	0		0	0		0	'
Fees from midstream services	0		0	0		0	'
Revenues	0		0	0		0	'
Total Outside Revenues [Member] \| TRC Non- Partnership [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	0		-0.1	0		-0.1	'
Fees from midstream services	0		0	0		0	'
Revenues	0		-0.1	0		-0.1	'
Total Intersegment Revenues [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	0		0	0		0	'
Fees from midstream services	0		0	0		0	'
Revenues	0		0	0		0	'
Total Intersegment Revenues [Member] \| Field Gathering and Processing [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	386		318.9	1,168.20		882.9	'
Fees from midstream services	1.7		0.8	3.9		2.4	'
Revenues	387.7		319.7	1,172.10		885.3	'
Total Intersegment Revenues [Member] \| Coastal Gathering and Processing [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	143.6		163.1	484		450.9	'
Fees from midstream services	0		0	0.1		0	'
Revenues	143.6		163.1	484.1		450.9	'
Total Intersegment Revenues [Member] \| Logistics Assets [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	1.3		1.8	2.7		3.6	'
Fees from midstream services	85.9		42.1	224.5		111.8	'
Revenues	87.2		43.9	227.2		115.4	'
Total Intersegment Revenues [Member] \| Marketing and Distribution [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	116.1		118.5	383.6		354.7	'
Fees from midstream services	10.1		8.4	25.5		20.8	'
Revenues	126.2		126.9	409.1		375.5	'
Total Intersegment Revenues [Member] \| Other Segment [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	0		0	0		0	'
Fees from midstream services	0		0	0		0	'
Revenues	0		0	0		0	'
Total Intersegment Revenues [Member] \| Corporate and Eliminations [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	-647		-602.3	-2,038.50		-1,692.10	'
Fees from midstream services	-97.7		-51.3	-254		-135	'
Revenues	-744.7		-653.6	-2,292.50		-1,827.10	'
Total Intersegment Revenues [Member] \| TRC Non- Partnership [Member]	'		'	'		'	'
Segment Reporting Information [Line Items]	'		'	'		'	'
Sale of commodities	0		0	0		0	'
Fees from midstream services	0		0	0		0	'
Revenues	$0		$0	$0		$0	'

[1]	Corporate assets primarily include investment in unconsolidated subsidiaries and debt issuance costs associated with our long-term debt.

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	1 Months Ended	9 Months Ended
	Oct. 31, 2014	Sep. 30, 2014	Oct. 10, 2014	Sep. 30, 2013
	Oct. 31, 2014	Quarter	Oct. 10, 2014	Sep. 30, 2013
Subsequent Event [Line Items]	'	'	'	'
Consideration in cash	$610,000,000	'	'	'
Subsequent Event [Member] \| Current Atlas Pipeline Partners Unitholders [Member]	'	'	'	'
Subsequent Event [Line Items]	'	'	'	'
Pro forma percentage of common units outstanding after completion of acquisition (in hundredths)	'	34.00%	'	'
Subsequent Event [Member] \| Current Atlas Energy Unitholders [Member]	'	'	'	'
Subsequent Event [Line Items]	'	'	'	'
Pro forma percentage of common units outstanding after completion of acquisition (in hundredths)	'	20.00%	'	'
Subsequent Event [Member] \| Current Targa Resources LP Unitholders [Member]	'	'	'	'
Subsequent Event [Line Items]	'	'	'	'
Pro forma percentage of common units outstanding after completion of acquisition (in hundredths)	'	66.00%	'	'
Subsequent Event [Member] \| Current Targa Resources Corp Shareholders [Member]	'	'	'	'
Subsequent Event [Line Items]	'	'	'	'
Pro forma percentage of common units outstanding after completion of acquisition (in hundredths)	'	80.00%	'	'
Subsequent Event [Member] \| 4 1/8 % Notes [Member]	'	'	'	'
Debt Instruments [Abstract]	'	'	'	'
Aggregate principal amount	800,000,000	'	'	'
Interest rate on senior notes (in hundredths)	4.13%	'	'	'
Net proceeds from issuance of senior notes	791,500,000	'	'	'
Maturity date	'	31-Dec-19	'	'
Subsequent Event [Member] \| 7 7/8 % Notes [Member]	'	'	'	'
Debt Instruments [Abstract]	'	'	'	'
Interest rate on senior notes (in hundredths)	7.88%	'	'	'
Maturity date	'	31-Dec-18	'	'
Redemption price (in hundredths)	103.94%	'	'	'
Subsequent Event [Member] \| Atlas Merger [Member]	'	'	'	'
Subsequent Event [Line Items]	'	'	'	'
Pro forma distribution percentage of common units prior to merger (in hundredths)	100.00%	'	'	'
Subsequent Event [Member] \| Atlas Pipeline Partners [Member]	'	'	'	'
Subsequent Event [Line Items]	'	'	'	'
Total estimated consideration	5,800,000,000	'	'	'
Outstanding long-term debt included in consideration	'	'	'	1,800,000,000
Distribution of common units (in shares)	0.5846	'	'	'
One-time cash payment (in dollars per share)	$1.26	'	'	'
Business combination share price (in dollars per share)	'	'	$38.66	'
Exchange ratio (in hundredths)	15.00%	'	'	'
Number of trading days ending October 3, 2014	'	'15 days	'	'
Preferred units, cumulative cash distribution	126,500,000	'	'	'
Number of years, incentive distribution rights agreed to reduce	'	'4 years	'	'
Number of successive quarters, annual distribution is paid	'	4	'	'
Subsequent Event [Member] \| Atlas Pipeline Partners [Member] \| Distribution Rights Year 1 [Member]	'	'	'	'
Subsequent Event [Line Items]	'	'	'	'
Reduction in incentive distribution	-37,500,000	'	'	'
Subsequent Event [Member] \| Atlas Pipeline Partners [Member] \| Distribution Rights Year 2 [Member]	'	'	'	'
Subsequent Event [Line Items]	'	'	'	'
Reduction in incentive distribution	-25,000,000	'	'	'
Subsequent Event [Member] \| Atlas Pipeline Partners [Member] \| Distribution Rights Year 3 [Member]	'	'	'	'
Subsequent Event [Line Items]	'	'	'	'
Reduction in incentive distribution	-10,000,000	'	'	'
Subsequent Event [Member] \| Atlas Pipeline Partners [Member] \| Distribution Rights Year 4 [Member]	'	'	'	'
Subsequent Event [Line Items]	'	'	'	'
Reduction in incentive distribution	-5,000,000	'	'	'
Subsequent Event [Member] \| Atlas Energy [Member]	'	'	'	'
Subsequent Event [Line Items]	'	'	'	'
Total estimated consideration	1,869,000,000	'	'	'
Distribution of common units (in shares)	10,350,000	'	'	'
Value of common stock as part of total consideration	'	'	1,259,000,000	'
Committed financing value	1,100,000,000	'	'	'
Control payments, transaction fees and expenses	$190,000,000	'	'	'