Targa Resources (TRGP) 10-Q5 Nov 132013 Q3 Quarterly reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
Document and Entity Information	Sep. 30, 2013	Oct. 28, 2013
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	'	42,331,487
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Sep-13	'

CONSOLIDATED_BALANCE_SHEETS_Un

CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Current assets:	'	'
Cash and cash equivalents	$83.70	$76.30
Trade receivables, net of allowances $0.9 million and $0.9 million	498.5	514.9
Inventories	201.7	99.4
Assets from risk management activities	10.9	29.3
Other current assets	14.2	13.4
Total current assets	809	733.3
Property, plant and equipment	5,454	4,708
Accumulated depreciation	-1,344.60	-1,170
Property, plant and equipment, net	4,109.40	3,538
Other intangible assets, net	660.3	680.8
Long-term assets from risk management activities	3.9	5.1
Investment in unconsolidated affiliate	51.2	53.1
Other long-term assets	91.5	94.7
Total assets	5,725.30	5,105
Current liabilities:	'	'
Accounts payable and accrued liabilities	679.6	679
Deferred income taxes	2	0.2
Liabilities from risk management activities	5.5	7.4
Total current liabilities	687.1	686.6
Long-term debt	2,867.90	2,475.30
Long-term liabilities from risk management activities	1.6	4.8
Deferred income taxes	136.1	131.2
Other long-term liabilities	58	53.7
Commitments and contingencies (see Note 14)	'	'
Targa Resources Corp. stockholders' equity:	'	'
Common stock ($0.001 par value, 300,000,000 shares authorized, 42,529,218 shares issued and 42,331,487 shares outstanding as of September 30, 2013, and 42,492,233 shares issued and 42,294,502 shares outstanding as of December 31, 2012)	0	0
Preferred stock ($0.001 par value, 100,000,000 shares authorized, no shares issued and outstanding as of September 30, 2013 and December 31, 2012)	0	0
Additional paid-in capital	147.6	184.4
Retained earnings (accumulated deficit)	12.6	-32
Accumulated other comprehensive income	0.3	1.2
Treasury stock, at cost (197,731 shares as of September 30, 2013 and as of December 31, 2012)	-9.5	-9.5
Total Targa Resources Corp. stockholders' equity	151	144.1
Noncontrolling interests in subsidiaries	1,823.60	1,609.30
Total owners' equity	1,974.60	1,753.40
Total liabilities and owners' equity	$5,725.30	$5,105

CONSOLIDATED_BALANCE_SHEETS_Un1

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Current assets:	'	'
Trade receivables, allowances	$0.90	$0.90
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)	42,529,218	42,492,233
Common stock, shares outstanding (in shares)	42,331,487	42,294,502
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)	197,731	197,731

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, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) [Abstract]	'	'	'	'
Revenues	$1,556.80	$1,393.50	$4,396.20	$4,358.40
Costs and expenses:	'	'	'	'
Product purchases	1,259.80	1,153	3,573.80	3,611.80
Operating expenses	97.6	78.3	279.8	227.2
Depreciation and amortization expenses	69	48.6	198.7	144.3
General and administrative expenses	37.7	35.7	112.5	106.5
Other operating expense	4.2	18.9	8.3	18.8
Income from operations	88.5	59	223.1	249.8
Other income (expense):	'	'	'	'
Interest expense, net	-33.4	-30	-97.9	-91
Equity earnings (loss)	5.6	-2.2	10.1	-0.3
Loss on debt redemption	-7.4	0	-14.7	0
Other	9.1	-1.8	15.3	-2.1
Income before income taxes	62.4	25	135.9	156.4
Income tax expense:	'	'	'	'
Current	-6.6	-4.3	-23.3	-20.3
Deferred	-6.4	-1.7	-7	-4.4
Income tax expense total	-13	-6	-30.3	-24.7
Net income	49.4	19	105.6	131.7
Less: Net income attributable to noncontrolling interests	33.1	10.3	61	104.8
Net income available to common shareholders	$16.30	$8.70	$44.60	$26.90
Net income available per common share - basic (in dollars per share)	$0.39	$0.21	$1.07	$0.66
Net income available per common share - diluted (in dollars per share)	$0.39	$0.21	$1.06	$0.64
Weighted average shares outstanding - basic (in shares)	41.6	41	41.6	41
Weighted average shares outstanding - diluted (in shares)	42.1	41.9	42.1	41.8

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, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited) [Abstract]	'	'	'	'
Net income attributable to Targa Resources Corp.	$16.30	$8.70	$44.60	$26.90
Commodity hedging contracts:	'	'	'	'
Change in fair value, pre-tax	-1.6	-3.7	0.3	11.5
Change in fair value, related income tax	0.6	2	-0.1	-2.5
Change in fair value, after tax	-1	-1.7	0.2	9
Settlement reclassified to revenues, pre-tax	-0.6	-3	-2.3	-6.6
Settlement reclassified to revenues, related income tax	0.2	1.6	0.9	1.4
Settlement reclassified to revenues, after tax	-0.4	-1.4	-1.4	-5.2
Interest rate swaps:	'	'	'	'
Settlements reclassified to interest expense, net, pre-tax	0.2	0.3	0.6	1
Settlements reclassified to interest expense, net, related income tax	-0.1	-1	-0.3	-1.3
Settlements reclassified to interest expense, net, after tax	0.1	-0.7	0.3	-0.3
Other comprehensive income (loss) attributable to Targa Resources Corp., pre-tax	-2	-6.4	-1.4	5.9
Other comprehensive income (loss) attributable to Targa Resources Corp., related income tax	0.7	2.6	0.5	-2.4
Other comprehensive income (loss) attributable to Targa Resources Corp., after tax	-1.3	-3.8	-0.9	3.5
Comprehensive income attributable to Targa Resources Corp.	15	4.9	43.7	30.4
Net income attributable to noncontrolling interests	33.1	10.3	61	104.8
Commodity hedging contracts:	'	'	'	'
Change in fair value, pre-tax	-9.7	-18.9	2.1	59.4
Change in fair value, related income tax	0	-0.2	0	0
Change in fair value, after tax	-9.7	-19.1	2.1	59.4
Settlement reclassified to revenues, pre-tax	-3.9	-12.4	-14.7	-25.1
Settlement reclassified to revenues, related income tax	0	-0.1	0	0
Settlement reclassified to revenues, after tax	-3.9	-12.5	-14.7	-25.1
Interest rate swaps:	'	'	'	'
Settlements reclassified to interest expense, net, pre-tax	1.3	1.6	4.1	5.1
Settlements reclassified to interest expense, net, related income tax	0	0	0	0
Settlements reclassified to interest expense, net, after tax	1.3	1.6	4.1	5.1
Other comprehensive income (loss) attributable to noncontrolling interests, before tax	-12.3	-29.7	-8.5	39.4
Other comprehensive income (loss) attributable to noncontrolling interests, related income tax	0	-0.3	0	0
Other comprehensive income (loss) attributable to noncontrolling interests, after tax	-12.3	-30	-8.5	39.4
Comprehensive income attributable to noncontrolling interests	20.8	-19.7	52.5	144.2
Total comprehensive income	$35.80	($14.80)	$96.20	$174.60

CONSOLIDATED_STATEMENTS_OF_CHA

CONSOLIDATED STATEMENTS OF CHANGES IN OWNERS' EQUITY (Unaudited) (USD $)	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings (Accumulated Deficit) [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Treasury Shares [Member]	Noncontrolling Interests [Member]	Total
In Millions, except Share data	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings (Accumulated Deficit) [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Treasury Shares [Member]	Noncontrolling Interests [Member]	Total
Balance at beginning of period at Dec. 31, 2011	$0	$229.50	($70.10)	($1.30)	$0	$1,172.60	$1,330.70
Balance at beginning of period (in shares) at Dec. 31, 2011	42,398,000	'	'	'	0	'	'
Compensation on equity grants	0	10.5	0	0	0	2.5	13
Compensation on equity grants (in shares)	94,000	'	'	'	0	'	'
Accrual of distribution equivalent rights	'	'	'	'	'	-0.4	-0.4
Sale of Partnership limited partner interests	0	0	0	0	0	115.2	115.2
Impact of Partnership equity transactions	0	-20.3	0	0	0	20.3	0
Dividends	0	-46.5	0	0	0	0	-46.5
Distributions	0	-1.2	0	0	0	-158.1	-159.3
Other comprehensive income (loss)	0	0	0	3.5	0	39.4	42.9
Net income	0	0	26.9	0	0	104.8	131.7
Balance at end of period at Sep. 30, 2012	0	172	-43.2	2.2	0	1,296.30	1,427.30
Balance end of period (in shares) at Sep. 30, 2012	42,492,000	'	'	'	0	'	'
Balance at beginning of period at Dec. 31, 2012	0	184.4	-32	1.2	-9.5	1,609.30	1,753.40
Balance at beginning of period (in shares) at Dec. 31, 2012	42,295,000	'	'	'	198,000	'	'
Compensation on equity grants	0	5.6	0	0	0	4.4	10
Compensation on equity grants (in shares)	36,000	'	'	'	0	'	'
Accrual of distribution equivalent rights	0	0	0	0	0	-1.1	-1.1
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	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	$147.60	$12.60	$0.30	($9.50)	$1,823.60	$1,974.60
Balance end of period (in shares) at Sep. 30, 2013	42,331,000	'	'	'	198,000	'	'

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Cash flows from operating activities	'	'
Net income	$105.60	$131.70
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Amortization in interest expense	12.1	14.7
Compensation on equity grants	10	13
Depreciation and amortization expense	198.7	144.3
Accretion of asset retirement obligations	3	3
Deferred income tax expense	7	4.4
Equity (earnings) loss, net of distributions	0	0.3
Risk management activities	0	1.7
Loss (gain) on sale or disposition of assets	3.1	15.5
Loss on debt redemption	14.7	0
Changes in operating assets and liabilities:	'	'
Receivables and other assets	19.7	162.9
Commodity Inventories	-110.3	4.9
Accounts payable and other liabilities	-5.5	-206.2
Net cash provided by operating activities	258.1	290.2
Cash flows from investing activities	'	'
Outlays for property, plant and equipment	-708.2	-365.1
Business acquisition, net of cash acquired	0	-25.8
Purchase of material and supplies	-35.3	0
Investment in unconsolidated affiliate	0	-16.8
Return of capital from unconsolidated affiliate	1.9	2.3
Other, net	4	1.6
Net cash used in investing activities	-737.6	-403.8
Partnership loan facilities:	'	'
Proceeds	1,743	1,120
Repayments	-1,521.20	-938
Partnership accounts receivable securitization facility:	'	'
Proceeds	261.6	0
Repayments	-93.6	0
Non-Partnership loan facilities:	'	'
Proceeds	36	0
Repayments	-48	0
Costs incurred in connection with financing arrangements	-13.6	-10
Distributions	-195.1	-159.3
Equity offering of the Partnership units	379.6	120.7
Dividends to common shareholders	-61.8	-44.9
Net cash provided by financing activities	486.9	88.5
Net change in cash and cash equivalents	7.4	-25.1
Cash and cash equivalents, beginning of period	76.3	145.8
Cash and cash equivalents, end of period	$83.70	$120.70

Organization

Organization	9 Months Ended
Organization	Sep. 30, 2013
Organization and Operations [Abstract]	'
Organization	'
	Note 1 — Organization

	Targa Resources Corp. (“TRC”) is a Delaware corporation formed in October 2005. Our common stock is listed on the NYSE 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
	Sep. 30, 2013
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, 2013 and 2012 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, 2013 are not necessarily indicative of the results that may be expected for the full year.

	Except as noted within the context of each footnote disclosure, the dollar amounts presented in the tabular data within these footnote disclosures are stated in millions of dollars.

	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, 2013, 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 a 11.9% 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 16 for an analysis of our and the Partnership’s operations by segment.

Significant_Accounting_Policie

Significant Accounting Policies	9 Months Ended
Significant Accounting Policies	Sep. 30, 2013
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, 2012. Significant updates or revisions to these policies during the nine months ended September 30, 2013 are shown below.

	Accounts Receivable Securitization Facility

	Proceeds from the sale or contribution of certain receivables under our Accounts Receivable Securitization Facility (the “Securitization Facility”) are treated as collateralized borrowings in our financial statements. Such borrowings are reflected as long-term debt on our balance sheets to the extent that the Partnership has the ability and intent to fund the Securitization Facility’s borrowings on a long-term basis. Proceeds and repayments under the Securitization Facility are reflected as cash flows from financing activities on our statements of cash flows.

	Intangible Assets

	Intangible assets arose from producer dedications under long-term contracts and customer relationships associated with businesses 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. Amortization expense attributable to these assets is recorded in a manner that closely resembles the expected pattern in which we benefit from services provided to customers.

	Recent Accounting Pronouncements

	In January 2013, the FASB issued Accounting Standards Update No. 2013-01, Balance Sheet (Topic 210): Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities, which clarifies that ASU 2011-11, Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities, applies to financial instruments or derivative transactions accounted for under ASC 815. We currently present the Partnership’s derivative assets and liabilities on a gross basis on our statement of financial position. The amendments require disclosure of both gross and net amounts of derivative assets and liabilities that are subject to master netting arrangements with counterparties. We have provided these additional disclosures regarding the gross and net amounts of derivative assets and liabilities in Note 12.

Business_Acquisitions

Business Acquisitions	9 Months Ended
Business Acquisitions	Sep. 30, 2013
Business Acquisitions [Abstract]	'
Business Acquisitions	'
	Note 4 –Business Acquisitions

	On December 31, 2012, the Partnership completed the acquisition of Saddle Butte Pipeline, LLC’s ownership of its Williston Basin crude oil pipeline and terminal system and its natural gas gathering and processing operations (collectively “Badlands”).

	Pursuant to the Membership Interest Purchase and Sale Agreement dated November 19, 2012 (the “MIPSA”), the acquisition is subject to a contingent payment of $50 million (“the contingent consideration”) if aggregate crude oil gathering volumes exceed 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 and revalued during the contingency period. 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, resulting in an increase in Other income of $9.1 million for third quarter 2013 and $15.3 million year-to-date 2013. The elimination of the contingent liability reflects management’s updated assessment, with only nine months remaining on the contingency period, that we will not meet the stipulated volumetric thresholds.

	Our Annual Report on Form 10-K included pro-forma information for the year ended 2012 regarding the Badlands acquisition. The following table presents updated 2012 pro forma information to reflect the effects of our 2013 policy decisions regarding depreciation and amortization of acquired properties and intangible assets, as described below. The following table also presents quarterly unaudited pro forma information for the three and nine months ended September 30, 2012 for comparative purposes in this quarterly report.

							Three Months Ended		Nine Months Ended
			Year Ended December 31, 2012				30-Sep-12		30-Sep-12
			As reported in		Pro forma		Pro forma		Pro forma
			10-K		Pro forma		Pro forma		Pro forma
			(In millions, except per share amounts)
	Revenues		$	5,885.70	$	5,909.90	$	1,401.30	$	4,374.00
	Net income			159.3		129.5		12.1		105.9
	Less: Net income attributable to noncontrolling interests			121.2		83.5		1.4		72.4
	Net income attributable to Targa Resources Corp.		$	38.1	$	46	$	10.7	$	33.5

	Net income per common share - Basic		$	0.93	$	1.12	$	0.26	$	0.82
	Net income per common share - Diluted		$	0.91	$	1.1	$	0.26	$	0.8

	The Partnership applied the same assumptions used in preparing the year-end pro forma schedules reported in its Annual Report on Form 10-K except for the following adjustments to conform to its current accounting policies:

		·	depreciation expense associated with the fair value adjustments to property, plant and equipment using the straight-line method over a useful life of 15-20 years. The pro forma information included in our 2012 Form 10-K utilized a 30 year useful life;

		·	amortization expense associated with the fair value adjustments to definite-lived intangibles in a manner that follows the expected pattern of services provided to customers, over a useful life of 20 years. The pro forma information included in our 2012 Form 10-K utilized a straight-line method over a 30 year life; and

		·	adjustment to pro forma revenues to report purchases and sales on a net, rather than gross, basis for certain Badlands natural gas processing agreements in which we are in substance an agent rather than a principal.

Inventories

Inventories	9 Months Ended
Inventories	Sep. 30, 2013
Inventories [Abstract]	'
Inventories	'
	Note 5 — Inventories

	The components of inventories consisted of the following:

		30-Sep-13		31-Dec-12
	Commodities	$	163.3	$	82.3
	Materials and supplies		38.4		17.1
		$	201.7	$	99.4

Property_Plant_and_Equipment_a

Property, Plant and Equipment and Intangible Assets	9 Months Ended
Property, Plant and Equipment and Intangible Assets	Sep. 30, 2013
Property, Plant and Equipment and Intangible Assets [Abstract]	'
Property, Plant and Equipment and Intangible Assets	'
	Note 6 — Property, Plant and Equipment and Intangible Assets

		30-Sep-13									31-Dec-12
		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	$	2,119.70		$	-		$	2,119.70		$	1,975.30		$	-		$	1,975.30		5 to 20
	Processing and fractionation facilities		1,528.40			6.6			1,535.00			1,251.60			6.6			1,258.20		5 to 25
	Terminaling and storage facilities		691.5			-			691.5			462			-			462		5 to 25
	Transportation assets		292.6			-			292.6			292.5			-			292.5		10 to 25
	Other property, plant and equipment		109.2			0.2			109.4			84.6			0.2			84.8		3 to 25
	Land		88.7			-			88.7			87.1			-			87.1		-
	Construction in progress		617.1			-			617.1			548.1			-			548.1		-
	Property, plant and equipment	$	5,447.20		$	6.8		$	5,454.00		$	4,701.20		$	6.8		$	4,708.00
	Accumulated depreciation		(1,342.4	)		(2.2	)		(1,344.6	)		(1,168.0	)		(2.0	)		(1,170.0	)
	Property, plant and equipment, net	$	4,104.80		$	4.6		$	4,109.40		$	3,533.20		$	4.8		$	3,538.00

	Intangible assets	$	681.8		$	-		$	681.8		$	681.9		$	-		$	681.9		20
	Accumulated amortization		(21.5	)		-			(21.5	)		(1.1	)		-			(1.1	)
	Intangible assets, net	$	660.3		$	-		$	660.3		$	680.8		$	-		$	680.8

	Intangible assets consist of customer contracts and customer relationships acquired in 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.

	Customer contracts and customer relationships related to the Badlands system have an estimated economic useful life of 20 years. Amortization expense attributable to these assets is recorded using a method that closely reflects the cash flow pattern underlying the intangible asset valuation. The estimated amortization expense for these intangible assets is approximately $27.1 million, $61.4 million, $80.1 million, $88.3 million and $81.5 million for each of years 2013 through 2017.

	Note 7 — Accounts Payable and Accrued Liabilities

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

		30-Sep-13			31-Dec-12
	Commodities	$	451		$	416.8
	Other goods and services		135			154.4
	Interest		42.3			39.5
	Compensation and benefits		32.5			40.7
	Other		18.8			27.6
		$	679.6		$	679

Accounts_Payable_and_Accrued_L

Accounts Payable and Accrued Liabilities	9 Months Ended
Accounts Payable and Accrued Liabilities	Sep. 30, 2013
Accounts Payable and Accrued Liabilities [Abstract]	'
Accounts Payable and Accrued Liabilities	'
	Note 7 — Accounts Payable and Accrued Liabilities

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

		30-Sep-13		31-Dec-12
	Commodities	$	451	$	416.8
	Other goods and services		135		154.4
	Interest		42.3		39.5
	Compensation and benefits		32.5		40.7
	Other		18.8		27.6
		$	679.6	$	679

Debt_Obligations

Debt Obligations	9 Months Ended
Debt Obligations	Sep. 30, 2013
Debt Obligations [Abstract]	'
Debt Obligations	'
	Note 8 — Debt Obligations

			30-Sep-13			31-Dec-12
	Long-term debt:
	Non-Partnership obligations:
	TRC Senior secured revolving credit facility, variable rate, due October 2017 (1)		$	70		$	82
	Obligations of the Partnership: (2)
	Senior secured revolving credit facility, variable rate, due October 2017 (3)			400			620
	Senior unsecured notes, 11¼% fixed rate, due July 2017 (4)			-			72.7
	Unamortized discount			-			(2.5	)
	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			(28.7	)		(30.5	)
	Senior unsecured notes, 6⅜% fixed rate, due August 2022			300			400
	Senior unsecured notes, 5¼% fixed rate, due May 2023			600			600
	Senior unsecured notes, 4¼% fixed rate, due November 2023			625			-
	Accounts receivable securitization facility, due January 2014 (5)			168			-
	Total long-term debt		$	2,867.90		$	2,475.30
	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)			50			45.3
			$	50		$	45.3
	___________
	-1	As of September 30, 2013, availability under TRC’s $150 million senior secured revolving credit facility was $80.0 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, 2013, availability under the Partnership’s $1.2 billion senior secured revolving credit facility was $750.0 million.
	-4	The outstanding balance of the 11¼% Notes was redeemed on July 15, 2013. See “Senior Notes Repayments and Redemptions” below.
	-5	All amounts outstanding under the Partnership’s Securitization Facility are reflected as long-term debt in our balance sheet because the Partnership has the ability and intent to fund the Securitization Facility’s borrowing with availability under the Partnership’s Revolver (“the TRP Revolver”).

	The following table shows the range of interest rates and weighted average interest rate incurred on our and the Partnership’s variable-rate debt obligations during the nine months ended September 30, 2013:

		Range of Interest		Weighted Average
		Rates Incurred		Interest Rate Incurred
	TRC senior secured revolving credit facility	2.9% - 3.0%		2.90%
	Partnership's senior secured revolving credit facility	1.9% - 4.5%		2.30%
	Partnership's accounts receivable securitization facility	0.90%		0.90%

	Compliance with Debt Covenants

	As of September 30, 2013, both we and the Partnership were in compliance with the covenants contained in our various debt agreements.

	The Partnership’s Accounts Receivable Securitization Facility

	In January 2013, the Partnership entered into the Securitization Facility to provide up to $200 million of borrowing capacity at commercial paper or LIBOR market index rates plus a margin through January 2014. Under this Securitization Facility, one of the Partnership’s consolidated subsidiaries (Targa Liquids Marketing and Trade LLC or “TLMT”) sells or contributes receivables, without recourse, to another of the Partnership’s consolidated subsidiaries (Targa Receivables LLC or “TRLLC”), a special purpose consolidated subsidiary created for the sole purpose of this Securitization Facility. TRLLC, in turn, sells an undivided percentage ownership in the eligible receivables to a third-party financial institution. Eligible TRLLC receivables up to the amount of the outstanding debt under the Securitization Facility are not available to satisfy the claims of the creditors of TLMT or us. Any excess receivables are eligible to satisfy the claims of creditors of TLMT or us.

	The Partnership’s April 2013 Shelf

	In April 2013, the Partnership filed with the SEC a universal shelf registration statement (the “April 2013 Shelf”), which provides the Partnership with the ability to offer and sell an unlimited amount of debt and equity securities, subject to market conditions and the Partnership’s capital needs. The April 2013 Shelf expires in April 2016. There was no activity under the April 2013 Shelf during the nine months ended September 30, 2013.

	The Partnership’s July 2013 Shelf

	In July 2013, the Partnership filed with the SEC a universal shelf registration statement that allows it to issue up to an aggregate of $800 million of debt or equity securities (the “July 2013 Shelf”). The July 2013 Shelf expires in August 2016. See Note 9 for equity issuances under the July 2013 Shelf.

	The Partnership’s 4¼% Senior Notes due 2023 (“4¼% Notes”)

	In May 2013, the Partnership privately placed $625.0 million in aggregate principal amount of 4¼% Senior Notes. The 4¼% Notes resulted in approximately $618.1 million of net proceeds, which were used to reduce borrowings under the Partnership’s senior secured revolving credit facility and for general partnership purposes.

	The 4¼% Notes are unsecured senior obligations that rank pari passu in right of payment with existing and future senior indebtedness. They are senior in right of payment to any of the Partnership’s future subordinated indebtedness and are unconditionally guaranteed by certain of the Partnership’s subsidiaries. The 4¼% Notes are effectively subordinated to all secured indebtedness under the Partnership’s credit agreement, which is secured by substantially all of the Partnership’s assets, to the extent of the value of the collateral securing that indebtedness.

	Interest on the 4¼% Notes accrues at the rate of 4¼% per annum and is payable semi-annually in arrears on May 15 and November 15, commencing on November 15, 2013.

	The Partnership may redeem 35% of the aggregate principal amount of the 4¼% Notes at any time prior to May 15, 2016, with the net cash proceeds of one or more equity offerings. The Partnership must pay a redemption price of 104.25% of the principal amount, plus accrued and unpaid interest and liquidated damages, if any, to the redemption date provided that:

	1)	at least 65% of the aggregate principal amount of the 4¼% Notes (excluding the 4¼% Notes held by the Partnership) remains outstanding immediately after the occurrence of such redemption; and

	2)	the redemption occurs within 180 days of the date of the closing of such equity offering.

The Partnership may also redeem all or part of the 4¼% Notes on or after May 15, 2018 at the prices set forth below plus accrued and unpaid interest and liquidated damages, if any, on the notes redeemed, if redeemed during the twelve month period beginning on May 15 of each year indicated below.

Year	Redemption Price
2018	102.13%
2019	101.42%
2020	100.71%
2021 and thereafter	100.00%

Senior Notes Repayments and Redemptions
In June 2013, the Partnership paid $106.4 million plus accrued interest, which included a premium of $6.4 million, to redeem $100 million of the outstanding 6⅜% Senior Notes due 2022 (the “6⅜% Notes”). The redemption resulted in a $7.4 million loss on debt redemption, including the write-off of $1.0 million of unamortized debt issue costs.

In July 2013, the Partnership paid $76.8 million plus accrued interest, which included a premium of $4.1 million, per the terms of the note agreement to redeem the outstanding balance of the 11¼% Senior Notes due 2017 (the “11¼% Notes”). The redemption resulted in a $7.4 million loss on debt redemption in the third quarter 2013, including the write-off of $1.0 million of unamortized debt issue costs.

Partnership_Units_and_Related_

Partnership Units and Related Matters	9 Months Ended
Partnership Units and Related Matters	Sep. 30, 2013
Partnership Units and Related Matters [Abstract]	'
Partnership Units and Related Matters	'
	Note 9 — Partnership Units and Related Matters

	Public Offerings of Common Units

	In 2012, the Partnership filed with the SEC a universal shelf registration statement that, subject to effectiveness at the time of use, allows the Partnership to issue up to an aggregate of $300 million of debt or equity securities (the “2012 Shelf”). The 2012 Shelf expires in August 2015.

	In August 2012, the Partnership entered into an Equity Distribution Agreement (“2012 EDA”) with Citigroup Global Markets Inc. (“Citigroup”) pursuant to which the Partnership may sell, at its option, up to an aggregate of $100 million of its common units through Citibank, as sales agent, under the 2012 Shelf. Settlement for sales of common units occurs on the third business day following the date on which any sales were made. During the nine months ended September 30, 2013, the Partnership issued 2,420,046 common units under the 2012 EDA, receiving net proceeds of $94.8 million. We contributed $2.0 million to maintain our 2% general partner interest.

	In March 2013, the Partnership entered into a second Equity Distribution Agreement under the 2012 Shelf (“March 2013 EDA”) with Citigroup, Deutsche Bank Securities Inc.(“Deutsche Bank”), Raymond James & Associates, Inc. (“Raymond James”) and UBS Securities LLC (“UBS”), as sales agents, pursuant to which the Partnership may sell, at its option, up to an aggregate of $200 million of the Partnership common units. During the nine months ended September 30, 2013, the Partnership issued 4,204,751 common units, receiving net proceeds of $197.5 million. During the nine months ended September 30, 2013, we contributed $4.1 million to maintain our 2% general partner interest.

	In August 2013, the Partnership entered into an Equity Distribution Agreement under the July 2013 Shelf (“August 2013 EDA”) with Citigroup, Deutsche Bank, Morgan Stanley & Co. LLC, Raymond James, RBC Capital Markets, LLC, UBS 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 the Partnership’s common units. During the third quarter of 2013, the Partnership issued 1,724,930 common units under the August 2013 EDA, receiving net proceeds of $85.1 million, of which $3.3 million was received in October 2013 and reported as a receivable in Owner’s Equity. We contributed $1.8 million to the Partnership to maintain our 2% general partner interest, which we settled in October.

	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, 2013.

			Distributions
	Three Months Ended	Date Paid or to be	Limited Partners		General Partner							Distributions to		Distributions per
		Paid	Limited Partners		General Partner							Targa Resources		limited partner
			Common		Incentive			2	%	Total		Corp.		unit
	(In millions, except per unit amounts)
	30-Sep-13	14-Nov-13	$	79.4	$	26.9	$	2.2		$	108.5	$	38.6	$	0.7325
	30-Jun-13	14-Aug-13		75.8		24.6		2			102.4		35.9		0.715
	31-Mar-13	15-May-13		71.7		22.1		1.9			95.7		33		0.6975
	31-Dec-12	14-Feb-13		69		20.1		1.8			90.9		30.7		0.68

Common_Stock_and_Related_Matte

Common Stock and Related Matters

9 Months Ended

Sep. 30, 2013

Common Stock and Related Matters [Abstract]

Common Stock and Related Matters

Note 10 — Common Stock and Related Matters

The following table details the dividends declared and/or paid by us for the nine months ended September 30, 2013:

Three Months Ended

Date Paid or to be Paid

Total

Amount of

Accrued

Dividend Declared

Dividend

Dividend Paid

Dividends (1)

per Share of

Declared

Common Stock

(In millions, except per share amounts)

30-Sep-13

15-Nov-13

24.1

23.7

0.4

0.57

30-Jun-13

15-Aug-13

22.5

22.1

0.4

0.5325

31-Mar-13

16-May-13

20.6

0.4

0.495

31-Dec-12

15-Feb-13

19.4

0.4

0.4575

________

-1

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

Earnings_per_Common_Share

Earnings per Common Share	9 Months Ended
Earnings per Common Share	Sep. 30, 2013
Earnings per Common Share [Abstract]	'
Earnings per Common Share	'
	Note 11 — 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,
		2013		2012		2013		2012
	Net income	$	49.4	$	19	$	105.6	$	131.7
	Less: Net income attributable to noncontrolling interests		33.1		10.3		61		104.8
	Net income attributable to common shareholders	$	16.3	$	8.7	$	44.6	$	26.9

	Weighted average shares outstanding - basic		41.6		41		41.6		41

	Net income available per common share - basic	$	0.39	$	0.21	$	1.07	$	0.66

	Weighted average shares outstanding		41.6		41		41.6		41
	Dilutive effect of unvested stock awards		0.5		0.9		0.5		0.8
	Weighted average shares outstanding - diluted		42.1		41.9		42.1		41.8

	Net income available per common share - diluted	$	0.39	$	0.21	$	1.06	$	0.64

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	9 Months Ended
Derivative Instruments and Hedging Activities	Sep. 30, 2013
Derivative Instruments and Hedging Activities [Abstract]	'
Derivative Instruments and Hedging Activities	'
	Note 12 — Derivative Instruments and Hedging Activities

	Partnership 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 Field Gathering and Processing Operations and (ii) NGL and condensate equity volumes predominately in Field Gathering and Processing segment and the LOU business unit in Coastal Gathering and Processing segment that result from its percent of proceeds processing arrangements. These hedge positions will move favorably in periods of falling prices and unfavorably in periods of rising 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 sales using crude oil hedges that are based on the 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.

	At September 30, 2013, the notional volumes of the Partnership’s commodity hedges for equity volumes were:

	Commodity		Instrument		Unit		2013		2014		2015		2016
	Natural Gas		Swaps		MMBtu/d		41,090		33,050		19,551		10,000
	NGL		Swaps		Bbl/d		5,650		1,000		-		-
	Condensate		Swaps		Bbl/d		2,045		1,450		-		-

	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, 2013								Fair Value as of December 31, 2012
		Balance Sheet		Derivative				Derivative				Derivative				Derivative
		Location		Assets				Liabilities				Assets				Liabilities
	Derivatives designated as hedging instruments
	Commodity contracts	Current		$	10.8			$	5.4			$	29.2			$	7.2
		Long-term			3.9				1.6				5.1				4.8
	Total derivatives designated as hedging instruments			$	14.7			$	7			$	34.3			$	12

	Derivatives not designated as hedging instruments
	Commodity contracts	Current		$	0.1			$	0.1			$	0.1			$	0.2
	Total derivatives not designated as hedging instruments			$	0.1			$	0.1			$	0.1			$	0.2

	Total current position			$	10.9			$	5.5			$	29.3			$	7.4
	Total long-term position				3.9				1.6				5.1				4.8
	Total derivatives			$	14.8			$	7.1			$	34.4			$	12.2

	The pro forma impact of reporting derivatives in the Consolidated Balance Sheet is as follows:

			Gross Presentation								Pro forma Net Presentation
			Asset				Liability				Asset				Liability
	30-Sep-13		Position				Position				Position				Position
	Current position
	Counterparties with offsetting position		$	10.3			$	3.8			$	6.5			$	-
	Counterparties without offsetting position - assets			0.6				-				0.6				-
	Counterparties without offsetting position - liabilities			-				1.7				-				1.7
				10.9				5.5				7.1				1.7
	Long-term position
	Counterparties with offsetting position			2.8				1.1				1.7				-
	Counterparties without offsetting position - assets			1.1				-				1.1				-
	Counterparties without offsetting position - liabilities			-				0.5				-				0.5
				3.9				1.6				2.8				0.5
	Total derivatives
	Counterparties with offsetting position			13.1				4.9				8.2				-
	Counterparties without offsetting position - assets			1.7				-				1.7				-
	Counterparties without offsetting position - liabilities			-				2.2				-				2.2
			$	14.8			$	7.1			$	9.9			$	2.2

	31-Dec-12
	Current position
	Counterparties with offsetting position		$	23.8			$	7.4			$	16.4			$	-
	Counterparties without offsetting position - assets			5.5				-				5.5				-
	Counterparties without offsetting position - liabilities			-				-				-				-
				29.3				7.4				21.9				-
Long-term position
Counterparties with offsetting position			4.4				2.8				1.6				-
Counterparties without offsetting position - assets			0.7				-				0.7				-
Counterparties without offsetting position - liabilities			-				2				-				2
			5.1				4.8				2.3				2
Total derivatives
Counterparties with offsetting position			28.2				10.2				18				-
Counterparties without offsetting position - assets			6.2				-				6.2				-
Counterparties without offsetting position - liabilities			-				2				-				2
		$	34.4			$	12.2			$	24.2			$	2

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 $7.7 million as of September 30, 2013. 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 Flow		Three Months Ended September 30,								Nine Months Ended September 30,
Hedging Relationships		2013				2012				2013				2012
Commodity contracts		$	(11.3	)		$	(22.6	)		$	2.4			$	70.9
		$	(11.3	)		$	(22.6	)		$	2.4			$	70.9

		Gain (Loss) Reclassified from OCI into Income (Effective Portion)
		Three Months Ended September 30,								Nine Months Ended September 30,
Location of Gain (Loss)		2013				2012				2013				2012
Interest expense, net		$	(1.5	)		$	(1.9	)		$	(4.7	)		$	(6.1	)
Revenues			4.5				15.4				17				31.7
		$	3			$	13.5			$	12.3			$	25.6

Hedge ineffectiveness was immaterial for all periods presented.

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 derivatives not designated as hedging instruments was immaterial for all periods presented.

The following table shows the deferred gains (losses) included in accumulated OCI that will be reclassified into earnings through the end of 2016:

		30-Sep-13				31-Dec-12
Commodity hedges, before tax		$	1.1			$	3.2
Commodity hedges, after tax			0.6				1.9
Interest rate hedges, before tax			(0.5	)			(1.2	)
Interest rate hedges, after tax			(0.3	)			(0.7	)

As of September 30, 2013, net gains of $6.0 million on commodity hedges and net losses of $3.8 million on terminated interest rate swaps recorded in OCI are expected to be reclassified to revenue and interest expense during the next twelve months.

See Note 13 for additional disclosures related to derivative instruments and hedging activities.

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
Fair Value Measurements	Sep. 30, 2013
Fair Value Measurements [Abstract]	'
Fair Value Measurements	'
	Note 13 — Fair Value Measurements

	Under generally accepted accounting principles, our consolidated balance sheet reflects a mixture of measurement methods for financial assets and liabilities (“financial instruments”). Derivative financial instruments are reported at fair value in our consolidated balance sheet. Other financial instruments are reported at historical cost or amortized cost in our consolidated balance sheet, 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 swap 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, which aggregate to a net asset position of $7.7 million as of September 30, 2013, are sensitive to changes in forward pricing on natural gas, NGLs and crude oil. This asset position reflects the present value, adjusted for counterparty credit risk, of the amount the Partnership expects to receive 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 $12.4 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 $27.8 million, ignoring an adjustment for counterparty credit risk.

	Fair Value of Other Financial Instruments

	The contingent consideration obligation related to the Partnership’s Badlands acquisition is reported at fair value. Due to their cash or near-cash nature, the carrying value of other financial instruments included in working capital (i.e., cash and cash equivalents, accounts receivable, accounts payable) approximates their fair value. As such, long-term debt is primarily the other financial instrument for which our carrying value could vary significantly from fair value. We determined the supplemental fair value disclosures for our long-term debt as follows:

		•	senior secured revolving credit facilities and the Partnership’s Securitization Facility are based on carrying value which approximates fair value as its interest rate is based on prevailing market rates;

		•	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 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 sheet at fair value and (2) supplemental fair value disclosures for other financial instruments:

			30-Sep-13
			Carrying			Fair Value
			Value			Total		Level 1		Level 2		Level 3
	Financial Instruments Recorded on Our Consolidated Balance Sheet at Fair Value:
	Assets from commodity derivative contracts		$	14.8		$	14.8	$	-	$	13.6	$	1.2
	Liabilities from commodity derivative contracts			7.1			7.1		-		6.7		0.4
	Badlands contingent consideration liability			-			-		-		-		-
	Financial Instruments Recorded on Our Consolidated Balance Sheet at Carrying Value:
	Cash and cash equivalents			83.7			83.7		-		-		-
	TRC Senior secured revolving credit facility			70			70		-		70		-
	Partnership's Senior secured revolving credit facility			400			400		-		400		-
	Partnership's Senior unsecured notes			2,229.90			2,261.00		-		2,261.00		-
	Partnership's accounts receivable securitization facility			168			168		-		168		-

			31-Dec-12
			Carrying			Fair Value
			Value			Total		Level 1		Level 2		Level 3
	Financial Instruments Recorded on Our Consolidated Balance Sheet at Fair Value:
	Assets from commodity derivative contracts		$	34.3		$	34.3	$	-	$	34.3	$	-
	Liabilities from commodity derivative contracts			12.1			12.1		-		11.5		0.6
	Badlands contingent consideration liability			15.3			15.3		-		-		15.3
	Financial Instruments Recorded on Our Consolidated Balance Sheet at Carrying Value:
	Cash and cash equivalents			76.3			76.3		-		-		-
	TRC Senior secured revolving credit facility			82			82		-		82		-
	Partnership's Senior secured revolving credit facility			620			620		-		620		-
	Partnership's Senior unsecured notes			1,773.30			1,945.20		-		1,945.20		-

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

	As of September 30, 2013, we reported certain of the Partnership’s natural gas basis swaps at fair value using Level 3 inputs due to such derivatives not having observable market prices for substantially the full term of the derivative asset or liability. For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is categorized in Level 3. This includes derivatives valued using indicative price quotations whose contract length extends into unobservable periods.

	The fair value of these natural gas basis swaps is determined using a discounted cash flow valuation technique based on a forward commodity basis curve. For these derivatives, the primary input to the valuation model is the forward commodity basis curve, which is based on observable or public data sources and extrapolated when observable prices are not available.

As of September 30, 2013, the Partnership had nine natural gas basis 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 basis curves, for which a significant portion of the derivative’s term is beyond available forward pricing. The change in the fair value of Level 3 derivatives associated with a 10% change in the forward basis curve where prices are not observable is immaterial.

In 2012, the Partnership recorded a contingent consideration liability as part of the purchase consideration for the Badlands acquisition (see Note 4). The fair value of this contingent liability was determined using a probability-based model measuring the likelihood of meeting certain volumetric measures identified in the MIPSA. At September 30, 2013, with only nine months remaining in the contingency period, management re-estimated the contingent liability, reflecting its updated assessments of the likelihood of meeting the stipulated volumetric thresholds, net of accretion of the discount factor due to the passage of time. Consequently, as these probability-based inputs are not observable, the entire valuation of the contingent consideration is categorized in 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			Contingent
		Derivative			Liability
		Contracts
Balance, December 31, 2012		$	(0.6	)	$	(15.3	)
Settlements included in Revenue			1.4			-
Change in valuation of contingent liability included in Other Income			-			15.3
Balance, September 30, 2013		$	0.8		$	-

There has been no material transfer of assets or liabilities between the three levels of the fair value hierarchy during the nine months ended September 30, 2013.

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
Commitments and Contingencies	Sep. 30, 2013
Commitments and Contingencies [Abstract]	'
Commitments and Contingencies	'
	Note 14 — Commitments and Contingencies

	Environmental

	On August 15, 2013, the Partnership received a notice of violation with a proposed penalty in the amount of $130,600 from the New Mexico Environment Department (“NMED”) for alleged violations of certain air quality permit conditions at the Monument gas processing plant in Lea County, New Mexico, which is operated by the Partnership and owned by Versado Gas Processors, L.L.C. (“Versado”), a joint venture in which the Partnership owns a 63% interest. The Partnership is in discussions with the NMED to resolve this matter.

	Legal Proceedings

	We are a party to various legal proceedings and/or regulatory proceedings and certain claims, suits and complaints arising in the ordinary course of business that have been filed or are pending against us. We believe all such matters are without merit or involve amounts which, if resolved unfavorably, would not have a material effect on our financial position, results of operations, or cash flows.

Supplemental_Cash_Flow_Informa

Supplemental Cash Flow Information	9 Months Ended
Supplemental Cash Flow Information	Sep. 30, 2013
Supplemental Cash Flow Information [Abstract]	'
Supplemental Cash Flow Information	'
	Note 15 - Supplemental Cash Flow Information

		Nine Months Ended September 30,
		2013		2012
	Cash:
	Interest paid, net of capitalized interest	$	83	$	82.9
	Income taxes paid, net of refunds		23.1		24.4
	Non-cash:
	Deadstock inventory transferred to property, plant and equipment		28.3		2.9
	Accrued dividends on unvested equity awards		1.1		1.6
	Receivables from unit offerings		3.3		-
	Change in capital accruals		3.8		9.3
	Transfers from materials and supplies to property, plant and equipment		15.1		-
	Change in ARO estimate		1.4		-

Segment_Information

Segment Information	9 Months Ended
Segment Information	Sep. 30, 2013
Segment Information [Abstract]	'
Segment Information	'
	Note 16 — 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. The Field Gathering and Processing segment's assets are located in North Texas and the Permian Basin of West Texas and New Mexico. With the Badlands acquisition on December 31, 2012, this segment's assets now includes the Badlands crude oil and natural gas gathering, terminaling and processing assets in North Dakota. Because the acquisition closed on December 31, 2012, Badlands had no operational impact for 2012. 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, 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 and crude oil. 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, Texas and Southwestern 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 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; providing propane, butane and services to LPG exporters; and (4) 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. Partnership activities have been presented on a common control accounting basis, which reflects the drop-down transactions between us and the Partnership as if they occurred in prior periods similar to a pooling of interests. The non-Partnership results include activities related to certain assets and liabilities contractually excluded from the drop-down transactions and certain historical hedge activities that could not be reflected under GAAP in the Partnership common control results.

			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		$	1,249.50		$	4.8		$	-			$	(0.1	)		$	1,420.60
	Fees from midstream services			27.4			7.4			53			48.4			-			-				-				136.2
				83.9			78.5			91.8			1,297.90			4.8			-				(0.1	)			1,556.80
	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		$	1,424.80		$	4.8		$	(653.6	)		$	(0.1	)		$	1,556.80
	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

			Three Months Ended September 30, 2012
			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		$	42.2		$	60.5		$	52.9		$	1,136.40		$	14		$	-			$	0.6			$	1,306.60
	Fees from midstream services			8.5			7.4			43.6			27.4			-			-				-				86.9
				50.7			67.9			96.5			1,163.80			14			-				0.6				1,393.50
	Intersegment revenues
	Sales of commodities			274.8			150.5			0.5			151.5			-			(577.3	)			-				-
	Fees from midstream services			0.3			-			27.6			7.2			-			(35.1	)			-				-
				275.1			150.5			28.1			158.7			-			(612.4	)			-				-
	Revenues		$	325.8		$	218.4		$	124.6		$	1,322.50		$	14		$	(612.4	)		$	0.6			$	1,393.50
	Operating margin		$	53.8		$	18		$	50.4		$	25.4		$	14		$	-			$	0.6			$	162.2
	Other financial information:
	Total assets		$	1,717.30		$	421.8		$	977.5		$	491.7		$	44.8		$	117.8			$	110.6			$	3,881.50
	Capital expenditures		$	66.7		$	28.2		$	64		$	0.9		$	-		$	1.7			$	-			$	161.5


			Nine 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		$	145.7		$	223.8		$	117		$	3,528.40		$	17		$	-			$	(0.2	)		$	4,031.70
Fees from midstream services			70.3			25.9			147.6			120.7			-			-				-				364.5
			216			249.7			264.6			3,649.10			17			-				(0.2	)			4,396.20
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		$	4,024.60		$	17		$	(1,827.1	)		$	(0.2	)		$	4,396.20
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

		Nine Months Ended September 30, 2012
		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		$	134.2		$	172		$	152.9		$	3,622.20		$	28.1		$	-			$	1.6			$	4,111.00
Fees from midstream services			27.3			15.9			125.6			78.5			-			0.1				-				247.4
			161.5			187.9			278.5			3,700.70			28.1			0.1				1.6				4,358.40
Intersegment revenues
Sales of commodities			851.9			532.7			0.6			398.3			-			(1,783.5	)			-				-
Fees from midstream services			0.9			0.1			76.2			23.5			-			(100.7	)			-				-
			852.8			532.8			76.8			421.8			-			(1,884.2	)			-				-
Revenues		$	1,014.30		$	720.7		$	355.3		$	4,122.50		$	28.1		$	(1,884.1	)		$	1.6			$	4,358.40
Operating margin		$	180.6		$	92.3		$	139.2		$	77.8		$	28.1		$	-			$	1.4			$	519.4
Other financial information:
Total assets		$	1,717.30		$	421.8		$	977.5		$	491.7		$	44.8		$	117.8			$	110.6			$	3,881.50
Capital expenditures		$	139.6		$	32.8		$	213.8		$	10.4		$	-		$	3.2			$	0.4			$	400.2

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

		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
Sales of commodities
Natural gas sales		$	317.7		$	252.1		$	920.5		$	642.7
NGL sales			1,025.20			957.4			2,885.60			3,198.40
Condensate sales			35.3			29			95.3			87
Petroleum products			37.9			52.7			113.4			152.5
Derivative activities			4.5			15.4			16.9			30.4
			1,420.60			1,306.60			4,031.70			4,111.00
Fees from midstream services
Fractionating and treating fees			38.2			28.6			98.9			84
Storage, terminaling, transportation and export fees			63			41.6			170.3			107.4
Gathering and processing fees			30			11.8			75.5			30.1
Other			5			4.9			19.8			25.9
			136.2			86.9			364.5			247.4

Total revenues		$	1,556.80		$	1,393.50		$	4,396.20		$	4,358.40

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

		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012

Operating margin		$	199.4		$	162.2		$	542.6		$	519.4
Depreciation and amortization expense			(69.0	)		(48.6	)		(198.7	)		(144.3	)
General and administrative expense			(37.7	)		(35.7	)		(112.5	)		(106.5	)
Interest expense, net			(33.4	)		(30.0	)		(97.9	)		(91.0	)
Income tax expense			(13.0	)		(6.0	)		(30.3	)		(24.7	)
Other, net			3.1			(22.9	)		2.4			(21.2	)
Net income		$	49.4		$	19		$	105.6		$	131.7

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	9 Months Ended
Significant Accounting Policies (Policies)	Sep. 30, 2013
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, 2012. Significant updates or revisions to these policies during the nine months ended September 30, 2013 are shown below.
Accounts Receivable Securitization Facility	'
	Accounts Receivable Securitization Facility

	Proceeds from the sale or contribution of certain receivables under our Accounts Receivable Securitization Facility (the “Securitization Facility”) are treated as collateralized borrowings in our financial statements. Such borrowings are reflected as long-term debt on our balance sheets to the extent that the Partnership has the ability and intent to fund the Securitization Facility’s borrowings on a long-term basis. Proceeds and repayments under the Securitization Facility are reflected as cash flows from financing activities on our statements of cash flows.
Intangible Assets	'
	Intangible Assets

	Intangible assets arose from producer dedications under long-term contracts and customer relationships associated with businesses 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. Amortization expense attributable to these assets is recorded in a manner that closely resembles the expected pattern in which we benefit from services provided to customers.
Recent Accounting Pronouncements	'
	Recent Accounting Pronouncements

	In January 2013, the FASB issued Accounting Standards Update No. 2013-01, Balance Sheet (Topic 210): Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities, which clarifies that ASU 2011-11, Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities, applies to financial instruments or derivative transactions accounted for under ASC 815. We currently present the Partnership’s derivative assets and liabilities on a gross basis on our statement of financial position. The amendments require disclosure of both gross and net amounts of derivative assets and liabilities that are subject to master netting arrangements with counterparties. We have provided these additional disclosures regarding the gross and net amounts of derivative assets and liabilities in Note 12.

Business_Acquisitions_Tables

Business Acquisitions (Tables)	9 Months Ended
Business Acquisitions (Tables)	Sep. 30, 2013
Business Acquisitions [Abstract]	'
Pro forma consolidated results of operations	'
	Our Annual Report on Form 10-K included pro-forma information for the year ended 2012 regarding the Badlands acquisition. The following table presents updated 2012 pro forma information to reflect the effects of our 2013 policy decisions regarding depreciation and amortization of acquired properties and intangible assets, as described below. The following table also presents quarterly unaudited pro forma information for the three and nine months ended September 30, 2012 for comparative purposes in this quarterly report.

						Three Months Ended		Nine Months Ended
		Year Ended December 31, 2012				30-Sep-12		30-Sep-12
		As reported in		Pro forma		Pro forma		Pro forma
		10-K		Pro forma		Pro forma		Pro forma
		(In millions, except per share amounts)
	Revenues	$	5,885.70	$	5,909.90	$	1,401.30	$	4,374.00
	Net income		159.3		129.5		12.1		105.9
	Less: Net income attributable to noncontrolling interests		121.2		83.5		1.4		72.4
	Net income attributable to Targa Resources Corp.	$	38.1	$	46	$	10.7	$	33.5

	Net income per common share - Basic	$	0.93	$	1.12	$	0.26	$	0.82
	Net income per common share - Diluted	$	0.91	$	1.1	$	0.26	$	0.8

Inventories_Tables

Inventories (Tables)	9 Months Ended
Inventories (Tables)	Sep. 30, 2013
Inventories [Abstract]	'
Components of inventory	'
	The components of inventories consisted of the following:

		30-Sep-13		31-Dec-12
	Commodities	$	163.3	$	82.3
	Materials and supplies		38.4		17.1
		$	201.7	$	99.4

Property_Plant_and_Equipment_a1

Property, Plant and Equipment and Intangible Assets (Tables)	9 Months Ended
	Sep. 30, 2013
Property, Plant and Equipment and Intangible Assets [Abstract]	'
Component of property plant and equipment and intangible assets	'

		30-Sep-13									31-Dec-12
		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	$	2,119.70		$	-		$	2,119.70		$	1,975.30		$	-		$	1,975.30		5 to 20
	Processing and fractionation facilities		1,528.40			6.6			1,535.00			1,251.60			6.6			1,258.20		5 to 25
	Terminaling and storage facilities		691.5			-			691.5			462			-			462		5 to 25
	Transportation assets		292.6			-			292.6			292.5			-			292.5		10 to 25
	Other property, plant and equipment		109.2			0.2			109.4			84.6			0.2			84.8		3 to 25
	Land		88.7			-			88.7			87.1			-			87.1		-
	Construction in progress		617.1			-			617.1			548.1			-			548.1		-
	Property, plant and equipment	$	5,447.20		$	6.8		$	5,454.00		$	4,701.20		$	6.8		$	4,708.00
	Accumulated depreciation		(1,342.4	)		(2.2	)		(1,344.6	)		(1,168.0	)		(2.0	)		(1,170.0	)
	Property, plant and equipment, net	$	4,104.80		$	4.6		$	4,109.40		$	3,533.20		$	4.8		$	3,538.00

	Intangible assets	$	681.8		$	-		$	681.8		$	681.9		$	-		$	681.9		20
	Accumulated amortization		(21.5	)		-			(21.5	)		(1.1	)		-			(1.1	)
	Intangible assets, net	$	660.3		$	-		$	660.3		$	680.8		$	-		$	680.8

Accounts_Payable_and_Accrued_L1

Accounts Payable and Accrued Liabilities (Tables)	9 Months Ended
Accounts Payable and Accrued Liabilities (Tables)	Sep. 30, 2013
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-13		31-Dec-12
	Commodities	$	451	$	416.8
	Other goods and services		135		154.4
	Interest		42.3		39.5
	Compensation and benefits		32.5		40.7
	Other		18.8		27.6
		$	679.6	$	679

Debt_Obligations_Tables

Debt Obligations (Tables)	9 Months Ended
Debt Obligations (Tables)	Sep. 30, 2013
Debt Obligations [Abstract]	'
Schedule of outstanding debt	'

			30-Sep-13			31-Dec-12
	Long-term debt:
	Non-Partnership obligations:
	TRC Senior secured revolving credit facility, variable rate, due October 2017 (1)		$	70		$	82
	Obligations of the Partnership: (2)
	Senior secured revolving credit facility, variable rate, due October 2017 (3)			400			620
	Senior unsecured notes, 11¼% fixed rate, due July 2017 (4)			-			72.7
	Unamortized discount			-			(2.5	)
	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			(28.7	)		(30.5	)
	Senior unsecured notes, 6⅜% fixed rate, due August 2022			300			400
	Senior unsecured notes, 5¼% fixed rate, due May 2023			600			600
	Senior unsecured notes, 4¼% fixed rate, due November 2023			625			-
	Accounts receivable securitization facility, due January 2014 (5)			168			-
	Total long-term debt		$	2,867.90		$	2,475.30
	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)			50			45.3
			$	50		$	45.3
	___________
	-1	As of September 30, 2013, availability under TRC’s $150 million senior secured revolving credit facility was $80.0 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, 2013, availability under the Partnership’s $1.2 billion senior secured revolving credit facility was $750.0 million.
	-4	The outstanding balance of the 11¼% Notes was redeemed on July 15, 2013. See “Senior Notes Repayments and Redemptions” below.
	-5	All amounts outstanding under the Partnership’s Securitization Facility are reflected as long-term debt in our balance sheet because the Partnership has the ability and intent to fund the Securitization Facility’s borrowing with availability under the Partnership’s Revolver (“the TRP Revolver”).
Range of interest rates paid and weighted average interest rate paid on our variable-rate debt obligations	'
	The following table shows the range of interest rates and weighted average interest rate incurred on our and the Partnership’s variable-rate debt obligations during the nine months ended September 30, 2013:

		Range of Interest		Weighted Average
		Rates Incurred		Interest Rate Incurred
	TRC senior secured revolving credit facility	2.9% - 3.0%		2.90%
	Partnership's senior secured revolving credit facility	1.9% - 4.5%		2.30%
	Partnership's accounts receivable securitization facility	0.90%		0.90%
Schedule of redemption prices for issued debt	'
	The Partnership may also redeem all or part of the 4¼% Notes on or after May 15, 2018 at the prices set forth below plus accrued and unpaid interest and liquidated damages, if any, on the notes redeemed, if redeemed during the twelve month period beginning on May 15 of each year indicated below.

	Year	Redemption Price
	2018	102.13%
	2019	101.42%
	2020	100.71%
	2021 and thereafter	100.00%

Partnership_Units_and_Related_1

Partnership Units and Related Matters (Tables)	9 Months Ended
Partnership Units and Related Matters (Tables)	Sep. 30, 2013
Partnership Units and Related Matters [Abstract]	'
Schedule of 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, 2013.

			Distributions
	Three Months Ended	Date Paid or to be	Limited Partners		General Partner							Distributions to		Distributions per
		Paid	Limited Partners		General Partner							Targa Resources		limited partner
			Common		Incentive			2	%	Total		Corp.		unit
	(In millions, except per unit amounts)
	30-Sep-13	14-Nov-13	$	79.4	$	26.9	$	2.2		$	108.5	$	38.6	$	0.7325
	30-Jun-13	14-Aug-13		75.8		24.6		2			102.4		35.9		0.715
	31-Mar-13	15-May-13		71.7		22.1		1.9			95.7		33		0.6975
	31-Dec-12	14-Feb-13		69		20.1		1.8			90.9		30.7		0.68

Common_Stock_and_Related_Matte1

Common Stock and Related Matters (Tables)

9 Months Ended

Sep. 30, 2013

Common Stock and Related Matters [Abstract]

Common Stock and Related Matters

The following table details the dividends declared and/or paid by us for the nine months ended September 30, 2013:

Three Months Ended

Date Paid or to be Paid

Total

Amount of

Accrued

Dividend Declared

Dividend

Dividend Paid

Dividends (1)

per Share of

Declared

Common Stock

(In millions, except per share amounts)

30-Sep-13

15-Nov-13

24.1

23.7

0.4

0.57

30-Jun-13

15-Aug-13

22.5

22.1

0.4

0.5325

31-Mar-13

16-May-13

20.6

0.4

0.495

31-Dec-12

15-Feb-13

19.4

0.4

0.4575

________

-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, 2013
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,
		2013		2012		2013		2012
	Net income	$	49.4	$	19	$	105.6	$	131.7
	Less: Net income attributable to noncontrolling interests		33.1		10.3		61		104.8
	Net income attributable to common shareholders	$	16.3	$	8.7	$	44.6	$	26.9

	Weighted average shares outstanding - basic		41.6		41		41.6		41

	Net income available per common share - basic	$	0.39	$	0.21	$	1.07	$	0.66

	Weighted average shares outstanding		41.6		41		41.6		41
	Dilutive effect of unvested stock awards		0.5		0.9		0.5		0.8
	Weighted average shares outstanding - diluted		42.1		41.9		42.1		41.8

	Net income available per common share - diluted	$	0.39	$	0.21	$	1.06	$	0.64

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
Derivative Instruments and Hedging Activities (Tables)	Sep. 30, 2013
Derivative Instruments and Hedging Activities [Abstract]	'
Notional volume of commodity hedges	'
	At September 30, 2013, the notional volumes of the Partnership’s commodity hedges for equity volumes were:

	Commodity		Instrument		Unit	2013		2014	2015		2016
	Natural Gas		Swaps		MMBtu/d	41,090		33,050	19,551		10,000
	NGL		Swaps		Bbl/d	5,650		1,000	-		-
	Condensate		Swaps		Bbl/d	2,045		1,450	-		-
Fair values of derivative instruments	'
	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, 2013						Fair Value as of December 31, 2012
		Balance Sheet		Derivative			Derivative			Derivative			Derivative
		Location		Assets			Liabilities			Assets			Liabilities
	Derivatives designated as hedging instruments
	Commodity contracts	Current		$	10.8		$	5.4		$	29.2		$	7.2
		Long-term			3.9			1.6			5.1			4.8
	Total derivatives designated as hedging instruments			$	14.7		$	7		$	34.3		$	12

	Derivatives not designated as hedging instruments
	Commodity contracts	Current		$	0.1		$	0.1		$	0.1		$	0.2
	Total derivatives not designated as hedging instruments			$	0.1		$	0.1		$	0.1		$	0.2

	Total current position			$	10.9		$	5.5		$	29.3		$	7.4
	Total long-term position				3.9			1.6			5.1			4.8
	Total derivatives			$	14.8		$	7.1		$	34.4		$	12.2
Pro forma impact of derivatives net in Consolidated Balance Sheet	'
	The pro forma impact of reporting derivatives in the Consolidated Balance Sheet is as follows:

			Gross Presentation						Pro forma Net Presentation
			Asset			Liability			Asset			Liability
	30-Sep-13		Position			Position			Position			Position
	Current position
	Counterparties with offsetting position		$	10.3		$	3.8		$	6.5		$	-
	Counterparties without offsetting position - assets			0.6			-			0.6			-
	Counterparties without offsetting position - liabilities			-			1.7			-			1.7
				10.9			5.5			7.1			1.7
	Long-term position
	Counterparties with offsetting position			2.8			1.1			1.7			-
	Counterparties without offsetting position - assets			1.1			-			1.1			-
	Counterparties without offsetting position - liabilities			-			0.5			-			0.5
				3.9			1.6			2.8			0.5
	Total derivatives
	Counterparties with offsetting position			13.1			4.9			8.2			-
	Counterparties without offsetting position - assets			1.7			-			1.7			-
	Counterparties without offsetting position - liabilities			-			2.2			-			2.2
			$	14.8		$	7.1		$	9.9		$	2.2

	31-Dec-12
	Current position
	Counterparties with offsetting position		$	23.8		$	7.4		$	16.4		$	-
	Counterparties without offsetting position - assets			5.5			-			5.5			-
	Counterparties without offsetting position - liabilities			-			-			-			-
				29.3			7.4			21.9			-
	Long-term position
	Counterparties with offsetting position			4.4			2.8			1.6			-
	Counterparties without offsetting position - assets			0.7			-			0.7			-
	Counterparties without offsetting position - liabilities			-			2			-			2
				5.1			4.8			2.3			2
	Total derivatives
	Counterparties with offsetting position			28.2			10.2			18			-
	Counterparties without offsetting position - assets			6.2			-			6.2			-
	Counterparties without offsetting position - liabilities			-			2			-			2
			$	34.4		$	12.2		$	24.2		$	2
Cash flow hedges included in accumulated other comprehensive income (loss)	'
	The following tables reflect amounts recorded in other comprehensive income (“OCI”) and amounts reclassified from OCI to revenue and expense for the periods indicated:

			Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)
	Derivatives in Cash Flow		Three Months Ended September 30,						Nine Months Ended September 30,
	Hedging Relationships		2013			2012			2013			2012
	Commodity contracts		$	(11.3	)	$	(22.6	)	$	2.4		$	70.9
			$	(11.3	)	$	(22.6	)	$	2.4		$	70.9

			Gain (Loss) Reclassified from OCI into Income (Effective Portion)
			Three Months Ended September 30,						Nine Months Ended September 30,
	Location of Gain (Loss)		2013			2012			2013			2012
	Interest expense, net		$	(1.5	)	$	(1.9	)	$	(4.7	)	$	(6.1	)
	Revenues			4.5			15.4			17			31.7
			$	3		$	13.5		$	12.3		$	25.6
Schedule of gain (loss) on financial instruments	'
	The following table shows the deferred gains (losses) included in accumulated OCI that will be reclassified into earnings through the end of 2016:

			30-Sep-13			31-Dec-12
	Commodity hedges, before tax		$	1.1		$	3.2
	Commodity hedges, after tax			0.6			1.9
	Interest rate hedges, before tax			(0.5	)		(1.2	)
	Interest rate hedges, after tax			(0.3	)		(0.7	)

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
Fair Value Measurements (Tables)	Sep. 30, 2013
Fair Value Measurements [Abstract]	'
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 sheet at fair value and (2) supplemental fair value disclosures for other financial instruments:

		30-Sep-13
		Carrying			Fair Value
		Value			Total			Level 1		Level 2		Level 3
	Financial Instruments Recorded on Our Consolidated Balance Sheet at Fair Value:
	Assets from commodity derivative contracts	$	14.8		$	14.8		$	-	$	13.6	$	1.2
	Liabilities from commodity derivative contracts		7.1			7.1			-		6.7		0.4
	Badlands contingent consideration liability		-			-			-		-		-
	Financial Instruments Recorded on Our Consolidated Balance Sheet at Carrying Value:
	Cash and cash equivalents		83.7			83.7			-		-		-
	TRC Senior secured revolving credit facility		70			70			-		70		-
	Partnership's Senior secured revolving credit facility		400			400			-		400		-
	Partnership's Senior unsecured notes		2,229.90			2,261.00			-		2,261.00		-
	Partnership's accounts receivable securitization facility		168			168			-		168		-

		31-Dec-12
		Carrying			Fair Value
		Value			Total			Level 1		Level 2		Level 3
	Financial Instruments Recorded on Our Consolidated Balance Sheet at Fair Value:
	Assets from commodity derivative contracts	$	34.3		$	34.3		$	-	$	34.3	$	-
	Liabilities from commodity derivative contracts		12.1			12.1			-		11.5		0.6
	Badlands contingent consideration liability		15.3			15.3			-		-		15.3
	Financial Instruments Recorded on Our Consolidated Balance Sheet at Carrying Value:
	Cash and cash equivalents		76.3			76.3			-		-		-
	TRC Senior secured revolving credit facility		82			82			-		82		-
	Partnership's Senior secured revolving credit facility		620			620			-		620		-
	Partnership's Senior unsecured notes		1,773.30			1,945.20			-		1,945.20		-
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			Contingent
		Derivative			Liability
		Contracts
	Balance, December 31, 2012	$	(0.6	)	$	(15.3	)
	Settlements included in Revenue		1.4			-
	Change in valuation of contingent liability included in Other Income		-			15.3
	Balance, September 30, 2013	$	0.8		$	-

Supplemental_Cash_Flow_Informa1

Supplemental Cash Flow Information (Tables)	9 Months Ended
Supplemental Cash Flow Information (Tables)	Sep. 30, 2013
Supplemental Cash Flow Information [Abstract]	'
Supplemental Cash Flow Information	'
		Nine Months Ended September 30,
		2013		2012
	Cash:
	Interest paid, net of capitalized interest	$	83	$	82.9
	Income taxes paid, net of refunds		23.1		24.4
	Non-cash:
	Deadstock inventory transferred to property, plant and equipment		28.3		2.9
	Accrued dividends on unvested equity awards		1.1		1.6
	Receivables from unit offerings		3.3		-
	Change in capital accruals		3.8		9.3
	Transfers from materials and supplies to property, plant and equipment		15.1		-
	Change in ARO estimate		1.4		-

Segment_Information_Tables

Segment Information (Tables)	9 Months Ended
Segment Information (Tables)	Sep. 30, 2013
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. Partnership activities have been presented on a common control accounting basis, which reflects the drop-down transactions between us and the Partnership as if they occurred in prior periods similar to a pooling of interests. The non-Partnership results include activities related to certain assets and liabilities contractually excluded from the drop-down transactions and certain historical hedge activities that could not be reflected under GAAP in the Partnership common control results.

			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			$	1,249.50			$	4.8		$	-			$	(0.1	)		$	1,420.60
	Fees from midstream services			27.4				7.4				53				48.4				-			-				-				136.2
				83.9				78.5				91.8				1,297.90				4.8			-				(0.1	)			1,556.80
	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			$	1,424.80			$	4.8		$	(653.6	)		$	(0.1	)		$	1,556.80
	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

			Three Months Ended September 30, 2012
			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		$	42.2			$	60.5			$	52.9			$	1,136.40			$	14		$	-			$	0.6			$	1,306.60
	Fees from midstream services			8.5				7.4				43.6				27.4				-			-				-				86.9
				50.7				67.9				96.5				1,163.80				14			-				0.6				1,393.50
	Intersegment revenues
	Sales of commodities			274.8				150.5				0.5				151.5				-			(577.3	)			-				-
	Fees from midstream services			0.3				-				27.6				7.2				-			(35.1	)			-				-
				275.1				150.5				28.1				158.7				-			(612.4	)			-				-
	Revenues		$	325.8			$	218.4			$	124.6			$	1,322.50			$	14		$	(612.4	)		$	0.6			$	1,393.50
	Operating margin		$	53.8			$	18			$	50.4			$	25.4			$	14		$	-			$	0.6			$	162.2
	Other financial information:
	Total assets		$	1,717.30			$	421.8			$	977.5			$	491.7			$	44.8		$	117.8			$	110.6			$	3,881.50
	Capital expenditures		$	66.7			$	28.2			$	64			$	0.9			$	-		$	1.7			$	-			$	161.5

			Nine 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		$	145.7			$	223.8			$	117			$	3,528.40			$	17		$	-			$	(0.2	)		$	4,031.70
	Fees from midstream services			70.3				25.9				147.6				120.7				-			-				-				364.5
				216				249.7				264.6				3,649.10				17			-				(0.2	)			4,396.20
	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			$	4,024.60			$	17		$	(1,827.1	)		$	(0.2	)		$	4,396.20
	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

			Nine Months Ended September 30, 2012
		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		$	134.2			$	172			$	152.9			$	3,622.20			$	28.1		$	-			$	1.6			$	4,111.00
Fees from midstream services			27.3				15.9				125.6				78.5				-			0.1				-				247.4
			161.5				187.9				278.5				3,700.70				28.1			0.1				1.6				4,358.40
Intersegment revenues
Sales of commodities			851.9				532.7				0.6				398.3				-			(1,783.5	)			-				-
Fees from midstream services			0.9				0.1				76.2				23.5				-			(100.7	)			-				-
			852.8				532.8				76.8				421.8				-			(1,884.2	)			-				-
Revenues		$	1,014.30			$	720.7			$	355.3			$	4,122.50			$	28.1		$	(1,884.1	)		$	1.6			$	4,358.40
Operating margin		$	180.6			$	92.3			$	139.2			$	77.8			$	28.1		$	-			$	1.4			$	519.4
Other financial information:
Total assets		$	1,717.30			$	421.8			$	977.5			$	491.7			$	44.8		$	117.8			$	110.6			$	3,881.50
Capital expenditures		$	139.6			$	32.8			$	213.8			$	10.4			$	-		$	3.2			$	0.4			$	400.2
Revenues by product and service	'
	The following table shows our consolidated revenues by product and service for the periods presented:

			Three Months Ended September 30,								Nine Months Ended September 30,
			2013				2012				2013				2012
	Sales of commodities
	Natural gas sales		$	317.7			$	252.1			$	920.5			$	642.7
	NGL sales			1,025.20				957.4				2,885.60				3,198.40
	Condensate sales			35.3				29				95.3				87
	Petroleum products			37.9				52.7				113.4				152.5
	Derivative activities			4.5				15.4				16.9				30.4
				1,420.60				1,306.60				4,031.70				4,111.00
	Fees from midstream services
	Fractionating and treating fees			38.2				28.6				98.9				84
	Storage, terminaling, transportation and export fees			63				41.6				170.3				107.4
	Gathering and processing fees			30				11.8				75.5				30.1
	Other			5				4.9				19.8				25.9
				136.2				86.9				364.5				247.4

	Total revenues		$	1,556.80			$	1,393.50			$	4,396.20			$	4,358.40
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 September 30,								Nine Months Ended September 30,
			2013				2012				2013				2012

	Operating margin		$	199.4			$	162.2			$	542.6			$	519.4
	Depreciation and amortization expense			(69.0	)			(48.6	)			(198.7	)			(144.3	)
	General and administrative expense			(37.7	)			(35.7	)			(112.5	)			(106.5	)
	Interest expense, net			(33.4	)			(30.0	)			(97.9	)			(91.0	)
	Income tax expense			(13.0	)			(6.0	)			(30.3	)			(24.7	)
	Other, net			3.1				(22.9	)			2.4				(21.2	)
	Net income		$	49.4			$	19			$	105.6			$	131.7

Basis_of_Presentation_Details

Basis of Presentation (Details)	9 Months Ended
Basis of Presentation (Details)	Sep. 30, 2013
Partnership Ownership Disclosure [Abstract]	'
General partner ownership interest (in hundredths)	2.00%
Parent's percentage ownership in the general partner of the Partnership (in hundredths)	100.00%
Number of Partnership common units owned (in units)	12,945,659
Limited Partner [Member]	'
Partnership Ownership Disclosure [Abstract]	'
General partner ownership interest (in hundredths)	11.90%

Business_Acquisitions_Details

Business Acquisitions (Details) (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
As reported [Abstract]	'	'	'	'	'
Revenues	$1,556.80	$1,393.50	$4,396.20	$4,358.40	$5,885.70
Net income	49.4	19	105.6	131.7	159.3
Less: Net income attributable to noncontrolling interests	33.1	10.3	61	104.8	121.2
Net income attributable to common shareholders	16.3	8.7	44.6	26.9	38.1
Net income per common share - Basic (in dollars per share)	$0.39	$0.21	$1.07	$0.66	$0.93
Net income per common share - Diluted (in dollars per share)	$0.39	$0.21	$1.06	$0.64	$0.91
Pro Forma Results [Abstract]	'	'	'	'	'
Revenues	'	1,401.30	'	4,374	5,909.90
Net income	'	12.1	'	105.9	129.5
Less: Net income attributable to noncontrolling interests	'	1.4	'	72.4	83.5
Net income attributable to Targa Resources Corp.	'	10.7	'	33.5	46
Net income per common share - Basic	'	$0.26	'	$0.82	$1.12
Net income per common share - Diluted	'	$0.26	'	$0.80	$1.10
Useful life of acquired definite-lived intangibles	'	'	'20 years	'	'
Useful life of acquired property, plant, and equipment - pro-forma as reported in 10-K	'	'	'30 years	'	'
Useful life of acquired definite-lived intangibles - pro-forma as reported in 10-K	'	'	'30 years	'	'
Badlands [Member]	'	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'	'
Contingent consideration	'	'	'	'	50
Fair value of contingent consideration	'	'	0	'	15.3
Decrease in contingent consideration attributable to accretion of the discount factor	$9.10	'	$15.30	'	'
Pro Forma Results [Abstract]	'	'	'	'	'
Number of months remaining in contingency period	'	'	'9 months	'	'
Badlands [Member] \| Minimum [Member]	'	'	'	'	'
Pro Forma Results [Abstract]	'	'	'	'	'
Useful life of acquired property, plant and equipment	'	'	'15 years	'	'
Badlands [Member] \| Maximum [Member]	'	'	'	'	'
Pro Forma Results [Abstract]	'	'	'	'	'
Useful life of acquired property, plant and equipment	'	'	'20 years	'	'

Inventories_Details

Inventories (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Inventories [Abstract]	'	'
Commodities	$163.30	$82.30
Materials and supplies	38.4	17.1
Inventories, Net	$201.70	$99.40

Property_Plant_and_Equipment_a2

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

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

In Millions, unless otherwise specified

Intangible Assets [Member]

Gathering Systems [Member]

Processing and Fractionation Facilities [Member]

Terminaling and Storage Facilities [Member]

Transportation Assets [Member]

Other Property, Plant and Equipment [Member]

Targa Resources Partners LP [Member]

TRC Non Partnership [Member]

Targa Resources Corp. Consolidated [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Gathering Systems [Member]

Processing and Fractionation Facilities [Member]

Terminaling and Storage Facilities [Member]

Transportation Assets [Member]

Other Property, Plant and Equipment [Member]

Land [Member]

Construction in Progress [Member]

Gathering Systems [Member]

Processing and Fractionation Facilities [Member]

Terminaling and Storage Facilities [Member]

Transportation Assets [Member]

Other Property, Plant and Equipment [Member]

Land [Member]

Construction in Progress [Member]

Gathering Systems [Member]

Processing and Fractionation Facilities [Member]

Terminaling and Storage Facilities [Member]

Transportation Assets [Member]

Other Property, Plant and Equipment [Member]

Land [Member]

Construction in Progress [Member]

Property, Plant and Equipment [Line Items]

Property, plant and equipment

$5,454

$4,708

$5,447.20

$4,701.20

$2,119.70

$1,975.30

$1,528.40

$1,251.60

$691.50

$462

$292.60

$292.50

$109.20

$84.60

$88.70

$87.10

$617.10

$548.10

$6.80

$6.60

$0.20

$5,454

$4,708

$2,119.70

$1,975.30

$1,535

$1,258.20

$691.50

$462

$292.60

$292.50

$109.40

$84.80

$88.70

$87.10

$617.10

$548.10

Accumulated depreciation

-1,344.60

-1,170

-1,342.40

-1,168

-2.2

-2

-1,344.60

-1,170

Property, plant and equipment, net

4,109.40

3,538

4,104.80

3,533.20

4.6

4.8

4,109.40

3,538

Intangible assets

681.8

681.9

681.8

681.9

Accumulated amortization

-21.5

-1.1

-21.5

-1.1

Intangible assets, net

660.3

680.8

660.3

680.8

Estimated useful life

'5 years

'20 years

'5 years

'25 years

'5 years

'25 years

'10 years

'25 years

'3 years

'25 years

Finite-Lived Intangible Assets [Line Items]

Estimated useful lives (in years)

'20 years

Estimated amortization expense for intangible assets [Abstract]

2013

27.1

2014

61.4

2015

80.1

2016

88.3

2017

$81.50

Accounts_Payable_and_Accrued_L2

Accounts Payable and Accrued Liabilities (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Accounts Payable and Accrued Liabilities [Abstract]	'	'
Commodities	$451	$416.80
Other goods and services	135	154.4
Interest	42.3	39.5
Compensation and benefits	32.5	40.7
Other	18.8	27.6
Accounts payable and accrued liabilities	$679.60	$679

Debt_Obligations_Details

Debt Obligations (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	$2,867.90		$2,475.30
Irrevocable Standby Letters of Credit [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Letters of credit outstanding	50		45.3
TRC Senior Secured Credit Facility [Member] \| Secured Debt [Member] \| Irrevocable Standby Letters of Credit [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Letters of credit outstanding	0	[1]	0	[1]
Partnership's Senior Secured Credit Facility [Member] \| Secured Debt [Member] \| Irrevocable Standby Letters of Credit [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Letters of credit outstanding	50	[2]	45.3	[2]
Partnership's Accounts Receivable Securitization Facility [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Range of Interest Rates Incurred, Maximum (in hundredths)	0.90%		'
Weighted Average Interest Rate Incurred (in hundredths)	0.90%		'
Parent Company excluding Partnership [Member] \| TRC Senior Secured Revolving Credit Facility due 2017 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	70	[1]	82	[1]
Maturity date	1-Oct-17		'
Range of Interest Rates Incurred, Minimum (in hundredths)	2.90%		'
Range of Interest Rates Incurred, Maximum (in hundredths)	3.00%		'
Weighted Average Interest Rate Incurred (in hundredths)	2.90%		'
Parent Company excluding Partnership [Member] \| Senior Unsecured Notes due 2017 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Revolving credit facility	150		'
Available capacity under revolving credit facility	80		'
Targa Resources Partners LP [Member] \| Accounts receivable securitization facility [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	168	[3],[4]	0	[3],[4]
Maturity date	1-Jan-14		'
Maximum borrowing capacity under Securitization Facility	200		'
Targa Resources Partners LP [Member] \| TRC Senior Secured Revolving Credit Facility due 2017 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	400	[2],[3]	620	[2],[3]
Maturity date	1-Oct-17		'
Revolving credit facility	1,200		'
Available capacity under revolving credit facility	750		'
Targa Resources Partners LP [Member] \| Senior Unsecured Notes due 2017 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	0	[3],[5]	72.7	[3],[5]
Unamortized discount	0	[3]	-2.5	[3]
Maturity date	1-Jul-17		'
Per Annum Interest Rate (in hundredths)	11.25%		'
Targa Resources Partners LP [Member] \| Senior Unsecured Notes due 2018 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	250	[3]	250	[3]
Maturity date	1-Oct-18		'
Per Annum Interest Rate (in hundredths)	7.88%		'
Targa Resources Partners LP [Member] \| Senior Unsecured Notes due 2021 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	483.6	[3]	483.6	[3]
Unamortized discount	-28.7	[3]	-30.5	[3]
Maturity date	1-Feb-21		'
Per Annum Interest Rate (in hundredths)	6.88%		'
Targa Resources Partners LP [Member] \| Senior Unsecured Notes due 2022 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	300	[3]	400	[3]
Maturity date	1-Aug-22		'
Per Annum Interest Rate (in hundredths)	6.38%		'
Targa Resources Partners LP [Member] \| Senior Unsecured Notes due 2023 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	600	[3]	600	[3]
Maturity date	1-May-23		'
Per Annum Interest Rate (in hundredths)	5.25%		'
Targa Resources Partners LP [Member] \| Partnership's Senior Secured Credit Facility [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
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)	2.30%		'
Targa Resources Partners LP [Member] \| Senior Unsecured Notes due November 2023 [Member]	'		'
Schedule of Debt Instruments [Line Items]	'		'
Long-term debt	625	[3]	0	[3]
Maturity date	1-Nov-23		'
Per Annum Interest Rate (in hundredths)	4.25%		'
Net Proceeds	$618.10		'
Percentage of principal amount can be redeemed prior to May 15, 2016 (in hundredths)	35.00%		'
Percentage of aggregate principal amount remains outstanding (in hundredths)	65.00%		'
Redemption Period	'180 days		'
Redemption Price [Abstract]	'		'
Redemption price (in hundredths)	104.25%		'
Targa Resources Partners LP [Member] \| Senior Unsecured Notes due November 2023 [Member] \| 2018 [Member]	'		'
Redemption Price [Abstract]	'		'
Redemption price (in hundredths)	102.13%		'
Targa Resources Partners LP [Member] \| Senior Unsecured Notes due November 2023 [Member] \| 2019 [Member]	'		'
Redemption Price [Abstract]	'		'
Redemption price (in hundredths)	101.42%		'
Targa Resources Partners LP [Member] \| Senior Unsecured Notes due November 2023 [Member] \| 2020 [Member]	'		'
Redemption Price [Abstract]	'		'
Redemption price (in hundredths)	100.71%		'
Targa Resources Partners LP [Member] \| Senior Unsecured Notes due November 2023 [Member] \| 2021 and thereafter [Member]	'		'
Redemption Price [Abstract]	'		'
Redemption price (in hundredths)	100.00%		'

[1]	As of September 30, 2013, availability under TRCbs $150 million senior secured revolving credit facility was $80.0 million.
[2]	As of September 30, 2013, availability under the Partnershipbs $1.2 billion senior secured revolving credit facility was $750.0 million.
[3]	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.
[4]	All amounts outstanding under the Partnershipbs Securitization Facility are reflected as long-term debt in our balance sheet because the Partnership has the ability and intent to fund the Securitization Facilitybs borrowing with availability under the Partnershipbs Revolver (bthe TRP Revolverb).
[5]	The outstanding balance of the 11B

Debt_Obligations_Senior_Notes_

Debt Obligations, Senior Notes Repayments and Redemptions (Details) (USD $)	9 Months Ended			0 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Jul. 29, 2013	Jul. 15, 2013	Jun. 30, 2013
				Targa Resources Partners LP [Member]	Targa Resources Partners LP [Member]
				Senior unsecured notes due 2017 [Member]	Senior unsecured notes due 2017 [Member]
Schedule of Debt Instruments [Line Items]	'	'	'	'	'
Debt redeemed	'	'	'	$76.80	$106.40
Debt principal amount redeemed	'	'	'	72.7	100
Loss on redemption of debt	14.7	0	'	7.4	7.4
Loss on redemption of debt, premium paid	'	'	'	4.1	6.4
Loss on redemption of debt, write-off of unamortized debt issue costs	'	'	'	1	1
Aggregate amount of debt or equity securities allowed under shelf agreement	'	$300	$800	'	'

Partnership_Units_and_Related_2

Partnership Units and Related Matters (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2013	Jul. 29, 2013	Sep. 30, 2012
Partnership Equity [Abstract]	'	'	'	'	'	'	'
General partner ownership interest (in hundredths)	'	'	'	'	2.00%	'	'
Aggregate amount of debt or equity securities allowed to be issued under the shelf agreement	'	'	'	'	'	$800	$300
Number of days from end of each quarter by when cash is distributed to unitholders	'	'	'	'	'45 days	'	'
Date paid or to be paid	14-Nov-13	14-Aug-13	15-May-13	14-Feb-13	'	'	'
Distributions Paid Limited Partners Common	79.4	75.8	71.7	69	'	'	'
Distributions to General Partners (Incentive)	26.9	24.6	22.1	20.1	'	'	'
Distributions to General Partners (2%)	2.2	2	1.9	1.8	'	'	'
Total distributions to general and limited partners	108.5	102.4	95.7	90.9	'	'	'
Distributions to Targa Resources Corp.	38.6	35.9	33	30.7	'	'	'
Distributions per limited partner per unit (in dollars per unit)	$0.73	$0.72	$0.70	$0.68	'	'	'
2012 EDA [Member]	'	'	'	'	'	'	'
Partnership Equity [Abstract]	'	'	'	'	'	'	'
Number of common units sold (in shares)	'	'	'	'	2,420,046	'	'
Net proceeds from sale of common units	'	'	'	'	94.8	'	'
Dollar amount of Common Units able to sell from Equity Distribution Agreement	'	'	'	'	100	'	'
General partner contributed to maintain general partner ownership percentage	'	'	'	'	2	'	'
General partner ownership interest (in hundredths)	'	'	'	'	2.00%	'	'
2013 EDA [Member]	'	'	'	'	'	'	'
Partnership Equity [Abstract]	'	'	'	'	'	'	'
Number of common units sold (in shares)	'	'	'	'	4,204,751	'	'
Net proceeds from sale of common units	'	'	'	'	197.5	'	'
Dollar amount of Common Units able to sell from Equity Distribution Agreement	'	'	'	'	200	'	'
General partner contributed to maintain general partner ownership percentage	'	'	'	'	4.1	'	'
General partner ownership interest (in hundredths)	'	'	'	'	2.00%	'	'
August 2013 EDA [Member]	'	'	'	'	'	'	'
Partnership Equity [Abstract]	'	'	'	'	'	'	'
Number of common units sold (in shares)	1,724,930	'	'	'	'	'	'
Net proceeds from sale of common units including receivables	85.1	'	'	'	'	'	'
Dollar amount of Common Units able to sell from Equity Distribution Agreement	400	'	'	'	'	'	'
General partner contributed to maintain general partner ownership percentage	1.8	'	'	'	'	'	'
General partner ownership interest (in hundredths)	2.00%	'	'	'	'	'	'
Receivables from issuance of common units	$3.30	'	'	'	3.3	'	'

Common_Stock_and_Related_Matte2

Common Stock and Related Matters (Details) (USD $)	3 Months Ended								9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2012		Sep. 30, 2013	Sep. 30, 2012
Common Stock and Related Matters [Abstract]	'		'		'		'		'	'
Date paid or to be paid	15-Nov-13		15-Aug-13		16-May-13		15-Feb-13		'	'
Total dividend declared	$24.10		$22.50		$21		$19.40		'	'
Amount of dividend paid	23.7		22.1		20.6		19		61.8	44.9
Accrued dividends	$0.40	[1]	$0.40	[1]	$0.40	[1]	$0.40	[1]	'	'
Dividend declared per share of common stock (in dollars per share)	$0.57		$0.53		$0.50		$0.46		'	'

[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		12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Earnings per Common Share [Abstract]	'	'	'	'	'
Net income	$49.40	$19	$105.60	$131.70	$159.30
Less: Net income attributable to noncontrolling interests	33.1	10.3	61	104.8	121.2
Net income attributable to common shareholders	$16.30	$8.70	$44.60	$26.90	$38.10
Weighted average shares outstanding - basic (in shares)	41.6	41	41.6	41	'
Net income available per common share - basic (in dollars per share)	$0.39	$0.21	$1.07	$0.66	$0.93
Weighted average shares outstanding (in shares)	41.6	41	41.6	41	'
Dilutive effect of unvested stock awards (in shares)	0.5	0.9	0.5	0.8	'
Weighted average shares outstanding - diluted (in shares)	42.1	41.9	42.1	41.8	'
Net income available per common share - diluted (in dollars per share)	$0.39	$0.21	$1.06	$0.64	$0.91

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Fair Values of Derivative Instruments [Abstract]	'	'	'	'	'
Current assets	$10.90	'	$10.90	'	$29.30
Long-term assets	3.9	'	3.9	'	5.1
Total derivative assets	14.8	'	14.8	'	34.4
Current liabilities	5.5	'	5.5	'	7.4
Long-term liabilities	1.6	'	1.6	'	4.8
Total derivative liabilities	7.1	'	7.1	'	12.2
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Fair value, net	7.7	'	7.7	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'	'
Gain (Loss) Recognized in OCI - Effective Portion	-11.3	-22.6	2.4	70.9	'
Gain (Loss) Reclassified from OCI into Income - Effective Portion	3	13.5	12.3	25.6	'
Cash flow commodity hedge deferred net gain to be reclassified within twelve months	6	'	6	'	'
Cash flow interest rate swaps deferred net loss to be reclassified within twelve months	3.8	'	3.8	'	'
Interest Expense, Net [Member]	'	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'	'
Gain (Loss) Reclassified from OCI into Income - Effective Portion	-1.5	-1.9	-4.7	-6.1	'
Revenue [Member]	'	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'	'
Gain (Loss) Reclassified from OCI into Income - Effective Portion	4.5	15.4	17	31.7	'
Asset Position [Member] \| Gross Presentation [Member]	'	'	'	'	'
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Counterparties with offsetting position	13.1	'	13.1	'	28.2
Counterparties without offsetting position - assets	1.7	'	1.7	'	6.2
Counterparties without offsetting position - liabilities	0	'	0	'	0
Fair value, net	14.8	'	14.8	'	34.4
Asset Position [Member] \| Pro-forma Net Presentation [Member]	'	'	'	'	'
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Counterparties with offsetting position	8.2	'	8.2	'	18
Counterparties without offsetting position - assets	1.7	'	1.7	'	6.2
Counterparties without offsetting position - liabilities	0	'	0	'	0
Fair value, net	9.9	'	9.9	'	24.2
Liability Position [Member] \| Gross Presentation [Member]	'	'	'	'	'
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Counterparties with offsetting position	4.9	'	4.9	'	10.2
Counterparties without offsetting position - assets	0	'	0	'	0
Counterparties without offsetting position - liabilities	2.2	'	2.2	'	2
Fair value, net	7.1	'	7.1	'	12.2
Liability Position [Member] \| Pro-forma Net Presentation [Member]	'	'	'	'	'
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Counterparties with offsetting position	0	'	0	'	0
Counterparties without offsetting position - assets	0	'	0	'	0
Counterparties without offsetting position - liabilities	2.2	'	2.2	'	2
Fair value, net	2.2	'	2.2	'	2
Current Position [Member] \| Asset Position [Member] \| Gross Presentation [Member]	'	'	'	'	'
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Counterparties with offsetting position	10.3	'	10.3	'	23.8
Counterparties without offsetting position - assets	0.6	'	0.6	'	5.5
Counterparties without offsetting position - liabilities	0	'	0	'	0
Fair value, net	10.9	'	10.9	'	29.3
Current Position [Member] \| Asset Position [Member] \| Pro-forma Net Presentation [Member]	'	'	'	'	'
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Counterparties with offsetting position	6.5	'	6.5	'	16.4
Counterparties without offsetting position - assets	0.6	'	0.6	'	5.5
Counterparties without offsetting position - liabilities	0	'	0	'	0
Fair value, net	7.1	'	7.1	'	21.9
Current Position [Member] \| Liability Position [Member] \| Gross Presentation [Member]	'	'	'	'	'
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Counterparties with offsetting position	3.8	'	3.8	'	7.4
Counterparties without offsetting position - assets	0	'	0	'	0
Counterparties without offsetting position - liabilities	1.7	'	1.7	'	0
Fair value, net	5.5	'	5.5	'	7.4
Current Position [Member] \| Liability Position [Member] \| Pro-forma Net Presentation [Member]	'	'	'	'	'
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Counterparties with offsetting position	0	'	0	'	0
Counterparties without offsetting position - assets	0	'	0	'	0
Counterparties without offsetting position - liabilities	1.7	'	1.7	'	0
Fair value, net	1.7	'	1.7	'	0
Long-term Position [Member] \| Asset Position [Member] \| Gross Presentation [Member]	'	'	'	'	'
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Counterparties with offsetting position	2.8	'	2.8	'	4.4
Counterparties without offsetting position - assets	1.1	'	1.1	'	0.7
Counterparties without offsetting position - liabilities	0	'	0	'	0
Fair value, net	3.9	'	3.9	'	5.1
Long-term Position [Member] \| Asset Position [Member] \| Pro-forma Net Presentation [Member]	'	'	'	'	'
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Counterparties with offsetting position	1.7	'	1.7	'	1.6
Counterparties without offsetting position - assets	1.1	'	1.1	'	0.7
Counterparties without offsetting position - liabilities	0	'	0	'	0
Fair value, net	2.8	'	2.8	'	2.3
Long-term Position [Member] \| Liability Position [Member] \| Gross Presentation [Member]	'	'	'	'	'
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Counterparties with offsetting position	1.1	'	1.1	'	2.8
Counterparties without offsetting position - assets	0	'	0	'	0
Counterparties without offsetting position - liabilities	0.5	'	0.5	'	2
Fair value, net	1.6	'	1.6	'	4.8
Long-term Position [Member] \| Liability Position [Member] \| Pro-forma Net Presentation [Member]	'	'	'	'	'
Derivative, Fair Value, Net [Abstract]	'	'	'	'	'
Counterparties with offsetting position	0	'	0	'	0
Counterparties without offsetting position - assets	0	'	0	'	0
Counterparties without offsetting position - liabilities	0.5	'	0.5	'	2
Fair value, net	0.5	'	0.5	'	2
Commodity Contracts [Member]	'	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'	'
Gain (Loss) Recognized in OCI - Effective Portion	-11.3	-22.6	2.4	70.9	'
Unrealized gain (loss) on hedges, before tax	1.1	'	1.1	'	3.2
Unrealized gain (loss) on hedges, after tax	0.6	'	0.6	'	1.9
Interest Rate Swap [Member]	'	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'	'
Unrealized gain (loss) on hedges, before tax	-0.5	'	-0.5	'	-1.2
Unrealized gain (loss) on hedges, after tax	-0.3	'	-0.3	'	-0.7
Designated as Hedging Instrument [Member]	'	'	'	'	'
Fair Values of Derivative Instruments [Abstract]	'	'	'	'	'
Total derivative assets	14.7	'	14.7	'	34.3
Total derivative liabilities	7	'	7	'	12
Designated as Hedging Instrument [Member] \| Commodity Contracts [Member]	'	'	'	'	'
Fair Values of Derivative Instruments [Abstract]	'	'	'	'	'
Current assets	10.8	'	10.8	'	29.2
Long-term assets	3.9	'	3.9	'	5.1
Current liabilities	5.4	'	5.4	'	7.2
Long-term liabilities	1.6	'	1.6	'	4.8
Not Designated as Hedging Instrument [Member]	'	'	'	'	'
Fair Values of Derivative Instruments [Abstract]	'	'	'	'	'
Total derivative assets	0.1	'	0.1	'	0.1
Total derivative liabilities	0.1	'	0.1	'	0.2
Not Designated as Hedging Instrument [Member] \| Commodity Contracts [Member]	'	'	'	'	'
Fair Values of Derivative Instruments [Abstract]	'	'	'	'	'
Current assets	0.1	'	0.1	'	0.1
Long-term assets	0	'	0	'	0
Current liabilities	0.1	'	0.1	'	0.2
Long-term liabilities	$0	'	$0	'	$0
Instruments - Swaps [Member] \| Year 2013 [Member] \| Natural Gas [Member]	'	'	'	'	'
Derivative Line [Items]	'	'	'	'	'
Notional volumes of commodity hedges (per day)	'	'	41,090	'	'
Instruments - Swaps [Member] \| Year 2013 [Member] \| NGL [Member]	'	'	'	'	'
Derivative Line [Items]	'	'	'	'	'
Notional volumes of commodity hedges (per day)	'	'	5,650	'	'
Instruments - Swaps [Member] \| Year 2013 [Member] \| Condensate [Member]	'	'	'	'	'
Derivative Line [Items]	'	'	'	'	'
Notional volumes of commodity hedges (per day)	'	'	2,045	'	'
Instruments - Swaps [Member] \| Year 2014 [Member] \| Natural Gas [Member]	'	'	'	'	'
Derivative Line [Items]	'	'	'	'	'
Notional volumes of commodity hedges (per day)	'	'	33,050	'	'
Instruments - Swaps [Member] \| Year 2014 [Member] \| NGL [Member]	'	'	'	'	'
Derivative Line [Items]	'	'	'	'	'
Notional volumes of commodity hedges (per day)	'	'	1,000	'	'
Instruments - Swaps [Member] \| Year 2014 [Member] \| Condensate [Member]	'	'	'	'	'
Derivative Line [Items]	'	'	'	'	'
Notional volumes of commodity hedges (per day)	'	'	1,450	'	'
Instruments - Swaps [Member] \| Year 2015 [Member] \| Natural Gas [Member]	'	'	'	'	'
Derivative Line [Items]	'	'	'	'	'
Notional volumes of commodity hedges (per day)	'	'	19,551	'	'
Instruments - Swaps [Member] \| Year 2015 [Member] \| NGL [Member]	'	'	'	'	'
Derivative Line [Items]	'	'	'	'	'
Notional volumes of commodity hedges (per day)	'	'	0	'	'
Instruments - Swaps [Member] \| Year 2015 [Member] \| Condensate [Member]	'	'	'	'	'
Derivative Line [Items]	'	'	'	'	'
Notional volumes of commodity hedges (per day)	'	'	0	'	'
Instruments - Swaps [Member] \| Year 2016 [Member] \| Natural Gas [Member]	'	'	'	'	'
Derivative Line [Items]	'	'	'	'	'
Notional volumes of commodity hedges (per day)	'	'	10,000	'	'
Instruments - Swaps [Member] \| Year 2016 [Member] \| NGL [Member]	'	'	'	'	'
Derivative Line [Items]	'	'	'	'	'
Notional volumes of commodity hedges (per day)	'	'	0	'	'
Instruments - Swaps [Member] \| Year 2016 [Member] \| Condensate [Member]	'	'	'	'	'
Derivative Line [Items]	'	'	'	'	'
Notional volumes of commodity hedges (per day)	'	'	0	'	'

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

In Millions, unless otherwise specified

Commodity Derivative Contracts [Member]

Contingent Liability[Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 2 [Member]

Fair Value, Inputs, Level 3 [Member]

Carrying (Reported) Amount, Fair Value Disclosure [Member]

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

Assets from commodity derivative contracts

$14.80

$34.30

$13.60

$34.30

$1.20

$14.80

$34.30

Liability from commodity derivative contracts

7.1

12.1

6.7

11.5

0.4

0.6

7.1

12.1

Badlands contingent consideration liability (see Note 4)

15.3

Cash and cash equivalents

83.7

76.3

83.7

76.3

TRC Senior secured revolving credit facility

Partnership's Senior secured revolving credit facility

400

620

400

620

400

620

Partnership's Senior unsecured notes

2,261

1,945.20

2,261

1,945.20

2,229.90

1,773.30

Partnership's accounts receivable securitization facility

168

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Derivative financial instruments, fair value, net

7.7

Derivative fair value commodity price increases 10 percent, net asset

12.4

Derivative fair value commodity price decreases 10 percent, net asset

27.8

Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]

Balance, December 31, 2012

-0.6

-15.3

Settlements included in Revenue

1.4

Change in valuation of contingent liability included in Other Income

15.3

Balance, June 30, 2013

$0.80

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	9 Months Ended
Commitments and Contingencies (Details) (USD $)	Sep. 30, 2013
Loss Contingencies [Line Items]	'
Penalty for alleged violations of certain air quality permit conditions	$130,600
Corporate Joint Venture [Member]	'
Loss Contingencies [Line Items]	'
Percentage of ownership in Versado Gas Processors, L.L.C (in hundredths)	63.00%

Supplemental_Cash_Flow_Informa2

Supplemental Cash Flow Information (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Cash [Abstract]	'	'
Interest paid, net of capitalized interest	$83	$82.90
Income taxes paid, net of refunds	23.1	24.4
Non-cash:	'	'
Deadstock inventory transferred to property, plant and equipment	28.3	2.9
Accrued distribution equivalent rights	1.1	1.6
Receivables from unit offerings	3.3	0
Change in capital accruals	3.8	9.3
Transfers from materials and supplies to property, plant and equipment	15.1	0
Change in ARO estimate	$1.40	$0

Segment_Information_Details

Segment Information (Details) (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
	Segment
	Division
Segment Information [Abstract]	'	'	'	'	'
Number of divisions	2	'	'	'	'
Number of reportable segments	4	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	$1,420.60	$1,306.60	$4,031.70	$4,111	'
Fees from midstream services	136.2	86.9	364.5	247.4	'
Revenues	1,556.80	1,393.50	4,396.20	4,358.40	5,885.70
Operating Margin	199.4	162.2	542.6	519.4	'
Total assets	5,725.30	3,881.50	5,725.30	3,881.50	5,105
Capital Expenditures	284.5	161.5	727.1	400.2	'
Depreciation and amortization expenses	-69	-48.6	-198.7	-144.3	'
General and administrative expenses	-37.7	-35.7	-112.5	-106.5	'
Interest expense, net	-33.4	-30	-97.9	-91	'
Income tax expense	-13	-6	-30.3	-24.7	'
Other, net	3.1	-22.9	2.4	-21.2	'
Net income	49.4	19	105.6	131.7	159.3
Field Gathering and Processing [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	403.6	325.8	1,101.30	1,014.30	'
Operating Margin	70.6	53.8	191.8	180.6	'
Total assets	3,095.90	1,717.30	3,095.90	1,717.30	'
Capital Expenditures	177.5	66.7	388.8	139.6	'
Coastal Gathering and Processing [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	241.6	218.4	700.6	720.7	'
Operating Margin	21.1	18	61.2	92.3	'
Total assets	385.8	421.8	385.8	421.8	'
Capital Expenditures	4.3	28.2	15.1	32.8	'
Logistics Assets [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	135.7	124.6	380	355.3	'
Operating Margin	70.5	50.4	178.9	139.2	'
Total assets	1,407.50	977.5	1,407.50	977.5	'
Capital Expenditures	99.9	64	317.7	213.8	'
Marketing and Distribution [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	1,424.80	1,322.50	4,024.60	4,122.50	'
Operating Margin	32.5	25.4	94	77.8	'
Total assets	638.8	491.7	638.8	491.7	'
Capital Expenditures	1.7	0.9	2.4	10.4	'
Other Segment [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	4.8	14	17	28.1	'
Operating Margin	4.8	14	17	28.1	'
Total assets	14.8	44.8	14.8	44.8	'
Capital Expenditures	0	0	0	0	'
Corporate and Eliminations [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	-653.6	-612.4	-1,827.10	-1,884.10	'
Operating Margin	0	0	0	0	'
Total assets	105.2	117.8	105.2	117.8	'
Capital Expenditures	1.1	1.7	3.1	3.2	'
TRC Non- Partnership [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Revenues	-0.1	0.6	-0.2	1.6	'
Operating Margin	-0.1	0.6	-0.3	1.4	'
Total assets	77.3	110.6	77.3	110.6	'
Capital Expenditures	0	0	0	0.4	'
Natural gas sales [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	317.7	252.1	920.5	642.7	'
NGL sales [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	1,025.20	957.4	2,885.60	3,198.40	'
Condensate sales [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	35.3	29	95.3	87	'
Petroleum Products [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	37.9	52.7	113.4	152.5	'
Derivative activities [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	4.5	15.4	16.9	30.4	'
Fractionating and treating fees [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Fees from midstream services	38.2	28.6	98.9	84	'
Storage And Terminaling Fees [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Fees from midstream services	63	41.6	170.3	107.4	'
Gathering and processing fees [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Fees from midstream services	30	11.8	75.5	30.1	'
Total Other Revenues [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Fees from midstream services	5	4.9	19.8	25.9	'
Total outside Revenues [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	1,420.60	1,306.60	4,031.70	4,111	'
Fees from midstream services	136.2	86.9	364.5	247.4	'
Revenues	1,556.80	1,393.50	4,396.20	4,358.40	'
Total outside Revenues [Member] \| Field Gathering and Processing [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	56.5	42.2	145.7	134.2	'
Fees from midstream services	27.4	8.5	70.3	27.3	'
Revenues	83.9	50.7	216	161.5	'
Total outside Revenues [Member] \| Coastal Gathering and Processing [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	71.1	60.5	223.8	172	'
Fees from midstream services	7.4	7.4	25.9	15.9	'
Revenues	78.5	67.9	249.7	187.9	'
Total outside Revenues [Member] \| Logistics Assets [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	38.8	52.9	117	152.9	'
Fees from midstream services	53	43.6	147.6	125.6	'
Revenues	91.8	96.5	264.6	278.5	'
Total outside Revenues [Member] \| Marketing and Distribution [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	1,249.50	1,136.40	3,528.40	3,622.20	'
Fees from midstream services	48.4	27.4	120.7	78.5	'
Revenues	1,297.90	1,163.80	3,649.10	3,700.70	'
Total outside Revenues [Member] \| Other Segment [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	4.8	14	17	28.1	'
Fees from midstream services	0	0	0	0	'
Revenues	4.8	14	17	28.1	'
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	0.1	'
Revenues	0	0	0	0.1	'
Total outside Revenues [Member] \| TRC Non- Partnership [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	-0.1	0.6	-0.2	1.6	'
Fees from midstream services	0	0	0	0	'
Revenues	-0.1	0.6	-0.2	1.6	'
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	318.9	274.8	882.9	851.9	'
Fees from midstream services	0.8	0.3	2.4	0.9	'
Revenues	319.7	275.1	885.3	852.8	'
Total Intersegment Revenues [Member] \| Coastal Gathering and Processing [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	163.1	150.5	450.9	532.7	'
Fees from midstream services	0	0	0	0.1	'
Revenues	163.1	150.5	450.9	532.8	'
Total Intersegment Revenues [Member] \| Logistics Assets [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	1.8	0.5	3.6	0.6	'
Fees from midstream services	42.1	27.6	111.8	76.2	'
Revenues	43.9	28.1	115.4	76.8	'
Total Intersegment Revenues [Member] \| Marketing and Distribution [Member]	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Sale of commodities	118.5	151.5	354.7	398.3	'
Fees from midstream services	8.4	7.2	20.8	23.5	'
Revenues	126.9	158.7	375.5	421.8	'
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	-602.3	-577.3	-1,692.10	-1,783.50	'
Fees from midstream services	-51.3	-35.1	-135	-100.7	'
Revenues	-653.6	-612.4	-1,827.10	-1,884.20	'
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	'