Magellan Midstream Partners (MMP) 10-Q 1 Nov 13 2013 Q3 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	9 Months Ended
	Sep. 30, 2013	Oct. 31, 2013
Document And Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Sep-13	'
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'
Entity Registrant Name	'MAGELLAN MIDSTREAM PARTNERS LP	'
Entity Central Index Key	'0001126975	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	226,679,438

Consolidated_Statements_Of_Inc

Consolidated Statements Of Income (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Transportation and terminals revenue	$295,326	$255,492	$805,059	$721,807
Product sales revenue	144,852	70,178	504,485	546,476
Affiliate management fee revenue	3,657	199	10,624	596
Total revenue	443,835	325,869	1,320,168	1,268,879
Costs and expenses:	'	'	'	'
Operating	103,262	103,272	245,858	254,050
Product purchases	120,299	85,819	396,025	478,929
Depreciation and amortization	35,270	31,692	105,788	94,688
General and administrative	32,755	27,551	96,073	76,709
Total costs and expenses	291,586	248,334	843,744	904,376
Earnings of non-controlled entities	2,375	1,749	5,162	4,875
Operating profit	154,624	79,284	481,586	369,378
Interest expense	31,852	29,113	95,295	87,354
Interest income	-215	-16	-250	-80
Interest capitalized	-3,780	-1,439	-10,474	-3,331
Debt placement fee amortization expense	540	519	1,620	1,556
Income before provision for income taxes	126,227	51,107	395,395	283,879
Provision for income taxes	604	585	3,165	2,012
Net income	$125,623	$50,522	$392,230	$281,867
Basic and diluted net income per limited partner unit	$0.55	$0.22	$1.73	$1.25
Weighted average number of limited partner units outstanding used for basic and diluted net income per unit calculation	226,866	226,431	226,812	226,348

Consolidated_Statements_Of_Com

Consolidated Statements Of Comprehensive Income (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Net income	$125,623		$50,522		$392,230		$281,867
Other comprehensive income:	'		'		'		'
Net gain (loss) on cash flow hedges(1)	-36	[1]	9,666	[1]	-4,596	[1]	12,341	[1]
Reclassification of net loss (gain) on cash flow hedges to income(2)	-41	[2]	-1,425	[2]	4,285	[2]	-1,507	[2]
Changes in employee benefit plan assets and benefit obligations recognized in income(3)	491	[3]	-2,812	[3]	1,473	[3]	-1,107	[3]
Adjustment to recognize the funded status of postretirement plans	-367		8,325		-367		8,325
Total other comprehensive income	47		13,754		795		18,052
Comprehensive income	$125,670		$64,276		$393,025		$299,919
[1]	See Note 8–Derivative Financial Instruments for additional information on unrealized gains and losses on cash flow hedges recognized in accumulated other comprehensive loss.
[2]	See Note 8–Derivative Financial Instruments for additional information on amounts reclassified out of accumulated other comprehensive loss into income.
[3]	These accumulated other comprehensive loss components are included in the computation of net periodic pension cost (see Note 6–Employee Benefit Plans).

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
ASSETS	'	'
Cash and cash equivalents	$14,228	$328,278
Trade accounts receivable (less allowance for doubtful accounts of $5 at December 31, 2012)	107,710	91,114
Other accounts receivable	6,827	12,329
Inventory	208,485	221,888
Energy commodity derivatives contracts, net	8,441	0
Energy commodity derivatives deposits	10,294	18,304
Other current assets	31,296	28,365
Total current assets	387,281	700,278
Property, plant and equipment	4,764,325	4,408,550
Less: Accumulated depreciation	1,039,139	943,248
Net property, plant and equipment	3,725,186	3,465,302
Investments in non-controlled entities	291,384	107,356
Long-term receivables	3,140	5,135
Goodwill	53,260	53,260
Other intangibles (less accumulated amortization of $16,715 and $8,130 at December 31, 2012 and September 30, 2013, respectively)	7,969	13,274
Debt placement costs (less accumulated amortization of $7,886 and $9,506 at December 31, 2012 and September 30, 2013, respectively)	13,532	15,080
Tank bottom inventory	63,184	58,493
Other noncurrent assets	3,069	1,889
Total assets	4,548,005	4,420,067
LIABILITIES AND PARTNERS' CAPITAL	'	'
Accounts payable	83,190	112,002
Accrued payroll and benefits	38,216	32,434
Accrued interest payable	37,174	42,059
Accrued taxes other than income	38,395	33,089
Environmental liabilities	14,169	14,442
Deferred revenue	67,882	46,371
Accrued product purchases	69,702	72,049
Energy commodity derivatives contracts, net	0	7,338
Current portion of long-term debt	249,954	0
Other current liabilities	43,078	32,836
Total current liabilities	641,760	392,620
Long-term debt	2,236,761	2,393,408
Long-term pension and benefits	63,036	68,134
Other noncurrent liabilities	20,068	16,382
Environmental liabilities	23,327	33,821
Commitments and contingencies	'	'
Partners’ capital:	'	'
Limited partner unitholders (226,201 units and 226,679 units outstanding at December 31, 2012 and September 30, 2013, respectively)	1,597,316	1,550,760
Accumulated other comprehensive loss	-34,263	-35,058
Total partners’ capital	1,563,053	1,515,702
Total liabilities and partners' capital	$4,548,005	$4,420,067

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Trade accounts receivable, allowance for doubtful accounts	$0	$5
Other intangibles, accumulated amortization	8,130	16,715
Debt placement costs, accumulated amortization	$9,506	$7,886
Limited partner unitholders, units outstanding	226,679	226,201

Consolidated_Statements_Of_Cas

Consolidated Statements Of Cash Flows (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Operating Activities:	'	'
Net income	$392,230	$281,867
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation and amortization expense	105,788	94,688
Debt placement fee amortization expense	1,620	1,556
Loss on sale, retirement and impairment of assets	4,269	10,575
Earnings of non-controlled entities	-5,162	-4,875
Distributions from investments in non-controlled entities	1,907	4,875
Equity-based incentive compensation expense	14,499	12,555
Changes in employee benefit plan assets and benefit obligations	1,473	-1,107
Changes in operating assets and liabilities:	'	'
Trade accounts receivable and other accounts receivable	-11,094	-22,561
Inventory	13,403	38,144
Energy commodity derivatives contracts, net of derivatives deposits	-8,887	7,047
Accounts payable	956	-14,840
Accrued payroll and benefits	5,782	-279
Accrued interest payable	-4,885	-7,283
Accrued taxes other than income	5,306	4,363
Accrued product purchases	-2,347	10,726
Deferred revenue	21,511	5,082
Current and noncurrent environmental liabilities	-10,767	1,977
Other current and noncurrent assets and liabilities	-4,361	-10,268
Net cash provided by operating activities	521,241	412,242
Investing Activities:	'	'
Additions to property, plant and equipment	-289,669	-230,015
Proceeds from sale and disposition of assets	2,414	255
Increase (decrease) in accounts payable related to capital expenditures	-29,768	45,197
Acquisition of business	-57,000	0
Acquisition of assets	-22,500	0
Investments in non-controlled entities	-181,377	-37,495
Distributions in excess of earnings of non-controlled entities	604	1,228
Net cash used by investing activities	-577,296	-220,830
Financing Activities:	'	'
Distributions paid	-349,087	-293,778
Net borrowings under revolver	98,400	0
Increase in outstanding checks	4,951	6,238
Settlement of tax withholdings on long-term incentive compensation	-12,259	-13,001
Net cash used by financing activities	-257,995	-300,541
Change in cash and cash equivalents	-314,050	-109,129
Cash and cash equivalents at beginning of period	328,278	209,620
Cash and cash equivalents at end of period	14,228	100,491
Supplemental non-cash financing activity:	'	'
Issuance of limited partner units in settlement of equity-based incentive plan awards	$6,404	$7,295

Organization_Description_of_Bu

Organization, Description of Business And Basis Of Presentation	9 Months Ended
	Sep. 30, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization, Description of Business and Basis of Presentation	'
	Organization, Description of Business and Basis of Presentation
	Organization
	Unless indicated otherwise, the terms “our,” “we,” “us” and similar language refer to Magellan Midstream Partners, L.P. together with its subsidiaries. We are a Delaware limited partnership and our limited partner units are traded on the New York Stock Exchange under the ticker symbol “MMP.” Magellan GP, LLC, a wholly-owned Delaware limited liability company, serves as our general partner.
	During first quarter 2013, we completed a reorganization of our reporting segments. This reorganization was effected to reflect strategic changes in our businesses, particularly in the area of our crude oil activities, which have had or will have a significant impact on the way we manage our operations. Accordingly, we have updated our segment disclosures for all previous periods included in this report. Our reportable segments offer different products and services and are managed separately because each requires different marketing strategies and business knowledge.
	Description of Business
	We are principally engaged in the transportation, storage and distribution of refined petroleum products and crude oil.  As of September 30, 2013, our asset portfolio consisted of:
	•	our refined products segment, including almost 9,100 miles of refined products pipeline system with 49 connected terminals as well as 27 independent terminals not connected to our pipeline system and our 1,100-mile ammonia pipeline system;
	•	our crude oil segment, comprised of approximately 800 miles of crude oil pipelines and storage facilities with an aggregate leasable storage capacity of approximately 15 million barrels; and
	•	our marine storage segment, consisting of marine terminals located along coastal waterways with an aggregate storage capacity of more than 26 million barrels.
	Products transported, stored and distributed through our pipelines and terminals include:
	•	refined products, which are the output from refineries and are primarily used as fuels by consumers. Refined products include gasoline, diesel fuel, aviation fuel, kerosene and heating oil.  Collectively, diesel fuel and heating oil are referred to as distillates;
	•	liquefied petroleum gases, or LPGs, which are produced as by-products of the crude oil refining process and in connection with natural gas production. LPGs include butane and propane;
	•	blendstocks, which are blended with refined products to change or enhance their characteristics such as increasing a gasoline's octane or oxygen content. Blendstocks include alkylates and oxygenates;
	•	heavy oils and feedstocks, which are used as burner fuels or feedstocks for further processing by refineries and petrochemical facilities. Heavy oils and feedstocks include No. 6 fuel oil and vacuum gas oil;
	•	crude oil and condensate, which are used as feedstocks by refineries and petrochemical facilities;
	•	biofuels, such as ethanol and biodiesel, which are increasingly required by government mandates; and
	•	ammonia, which is primarily used as a nitrogen fertilizer.
	Except for ammonia, we use the term petroleum products to describe any, or a combination, of the above-noted products.
	Basis of Presentation
	In the opinion of management, our accompanying consolidated financial statements which are unaudited, except for the consolidated balance sheet as of December 31, 2012, which is derived from our audited financial statements, include all normal and recurring adjustments necessary to present fairly our financial position as of September 30, 2013, the results of operations for the three and nine months ended September 30, 2012 and 2013 and cash flows for the nine months ended September 30, 2012 and 2013. The results of operations for the nine months ended September 30, 2013 are not necessarily indicative of the results to be expected for the full year ending December 31, 2013.
	Pursuant to the rules and regulations of the Securities and Exchange Commission, the financial statements in this report do not include all of the information and notes normally included with financial statements prepared in accordance with accounting principles generally accepted in the United States. These financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2012 and the updates to our Annual Report reflecting changes in our reporting segments included in our Current Report on Form 8-K filed with the Securities and Exchange Commission on April 29, 2013.

Product_Sales_Revenues

Product Sales Revenues	9 Months Ended
	Sep. 30, 2013
Product Sales Revenues [Abstract]	'
Product Sales Revenues	'
	Product Sales Revenue
	The amounts reported as product sales revenue on our consolidated statements of income include revenue from the physical sale of petroleum products and from mark-to-market adjustments from New York Mercantile Exchange ("NYMEX") contracts. We use NYMEX contracts to hedge against changes in the price of refined products we expect to sell from our business activities where we acquire or produce petroleum products. Some of these NYMEX contracts qualify for hedge accounting treatment and we designate and account for these as either cash flow or fair value hedges. The effective portion of the fair value changes in contracts designated as cash flow hedges are recognized as adjustments to product sales when the hedged product is physically sold. Ineffectiveness in the contracts designated as cash flow hedges is recognized as an adjustment to product sales in the period the ineffectiveness occurs. We account for NYMEX contracts that do not qualify for hedge accounting treatment as economic hedges, with the period changes in fair value recognized as product sales, except for those agreements that economically hedge the inventories associated with our pipeline system overages (the period changes in the fair value of these agreements are charged to operating expense). See Note 8 – Derivative Financial Instruments for further disclosures regarding our NYMEX contracts.
	For the three and nine months ended September 30, 2012 and 2013, product sales revenue included the following (in thousands):
		Three Months Ended September 30,						Nine Months Ended September 30,
		2012			2013			2012			2013
	Physical sale of petroleum products	$	113,500		$	146,887		$	584,624		$	500,347
	NYMEX contract adjustments:
	Change in value of NYMEX contracts that did not qualify for hedge accounting treatment and the effective portion of gains and losses of matured NYMEX contracts that qualified for hedge accounting treatment associated with our butane blending and fractionation activities(1)	(36,172		)	(2,035		)	(33,211		)	4,149
	Change in value of NYMEX contracts that did not qualify for hedge accounting treatment associated with the Houston-to-El Paso pipeline linefill working inventory(1)	(7,080		)	—			(5,159		)	—
	Other	(70		)	—			222			(11		)
	Total NYMEX contract adjustments	(43,322		)	(2,035		)	(38,148		)	4,138
	Total product sales revenue	$	70,178		$	144,852		$	546,476		$	504,485
	(1) The associated petroleum products for these activities are, to the extent still owned as of the statement date, or were, to the extent no longer owned as of the statement date, classified as inventory in current assets on our consolidated balance sheets.

Segment_Disclosures

Segment Disclosures	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
Segment Disclosures	'
	Segment Disclosures
	During the first quarter of 2013, we revised our reporting segments. See Note 1 – Organization, Description of Business and Basis of Presentation for a discussion of this matter.
	Our reportable segments are strategic business units that offer different products and services. Our segments are managed separately because each segment requires different marketing strategies and business knowledge. Management evaluates performance based on segment operating margin, which includes revenue from affiliates and external customers, operating expenses, product purchases and earnings of non-controlled entities. Transactions between our business segments are conducted and recorded on the same basis as transactions with third-party entities.
	We believe that investors benefit from having access to the same financial measures used by management. Operating margin, which is presented in the following tables, is an important measure used by management to evaluate the economic performance of our core operations. Operating margin is not a generally accepted accounting principles ("GAAP") measure, but the components of operating margin are computed using amounts that are determined in accordance with GAAP. A reconciliation of operating margin to operating profit, which is its nearest comparable GAAP financial measure, is included in the tables below. Operating profit includes depreciation and amortization expense and general and administrative ("G&A") expenses that management does not focus on when evaluating the core profitability of our separate operating segments.
		Three Months Ended September 30, 2012
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	193,880	$	23,868		$	37,744		$	—		$	255,492
	Product sales revenue	66,776		—			3,402			—			70,178
	Affiliate management fee revenue	—		199			—			—			199
	Total revenue	260,656		24,067			41,146			—			325,869
	Operating expenses	80,705		3,441			19,824			(698		)	103,272
	Product purchases	84,041		—			1,778			—			85,819
	(Earnings) losses of non-controlled entities	—		(1,752		)	3			—			(1,749		)
	Operating margin	95,910		22,378			19,541			698			138,527
	Depreciation and amortization expense	21,432		2,885			6,677			698			31,692
	G&A expenses	21,948		1,375			4,228			—			27,551
	Operating profit	$	52,530	$	18,118		$	8,636		$	—		$	79,284
		Three Months Ended September 30, 2013
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	205,859	$	49,519		$	39,948		$	—		$	295,326
	Product sales revenue	143,549		—			1,303			—			144,852
	Affiliate management fee revenue	—		3,369			288			—			3,657
	Total revenue	349,408		52,888			41,539			—			443,835
	Operating expenses	82,174		4,034			17,813			(759		)	103,262
	Product purchases	120,429		—			(130		)	—			120,299
	Earnings of non-controlled entities	—		(1,770		)	(605		)	—			(2,375		)
	Operating margin	146,805		50,624			24,461			759			222,649
	Depreciation and amortization expense	21,851		5,538			7,122			759			35,270
	G&A expenses	22,741		5,100			4,914			—			32,755
	Operating profit	$	102,213	$	39,986		$	12,425		$	—		$	154,624
		Nine Months Ended September 30, 2012
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	538,812	$	67,626		$	115,369		$	—		$	721,807
	Product sales revenue	539,434		—			7,042			—			546,476
	Affiliate management fee revenue	—		596			—			—			596
	Total revenue	1,078,246		68,222			122,411			—			1,268,879
	Operating expenses	204,064		4,046			48,042			(2,102		)	254,050
	Product purchases	475,839		—			3,090			—			478,929
	(Earnings) losses of non-controlled entities	—		(4,913		)	38			—			(4,875		)
	Operating margin	398,343		69,089			71,241			2,102			540,775
	Depreciation and amortization expense	64,075		8,641			19,870			2,102			94,688
	G&A expenses	61,258		3,766			11,685			—			76,709
	Operating profit	$	273,010	$	56,682		$	39,686		$	—		$	369,378
		Nine Months Ended September 30, 2013
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	573,615	$	113,905		$	117,539		$	—		$	805,059
	Product sales revenue	499,285		—			5,200			—			504,485
	Affiliate management fee revenue	—		9,767			857			—			10,624
	Total revenue	1,072,900		123,672			123,596			—			1,320,168
	Operating expenses	194,911		13,168			40,060			(2,281		)	245,858
	Product purchases	393,187		—			2,838			—			396,025
	Earnings of non-controlled entities	—		(3,255		)	(1,907		)	—			(5,162		)
	Operating margin	484,802		113,759			82,605			2,281			683,447
	Depreciation and amortization expense	64,428		18,111			20,968			2,281			105,788
	G&A expenses	67,235		14,142			14,696			—			96,073
Operating profit	$	353,139	$	81,506		$	46,941		$	—		$	481,586

Investments_in_NonControlled_E

Investments in Non-Controlled Entities (Notes)	9 Months Ended
	Sep. 30, 2013
Equity Method Investments and Joint Ventures [Abstract]	'
Investments in Non-Controlled Entities	'
	Investments in Non-Controlled Entities
	We own a 50% interest in Texas Frontera, LLC ("Texas Frontera"), which owns 0.8 million barrels of refined products storage at our Galena Park, Texas terminal. The storage capacity owned by this venture is leased to an affiliate of Texas Frontera under a long-term lease agreement. Texas Frontera began operations in October 2012. We receive management fees from Texas Frontera, which we report as affiliate management fee revenue on our consolidated statements of income.
	We own a 50% interest in Osage Pipe Line Company, LLC ("Osage"), which owns a 135-mile crude oil pipeline that we operate. We receive management fees from Osage, which we report as affiliate management fee revenue on our consolidated statements of income.
	We own a 50% interest in Double Eagle Pipeline LLC ("Double Eagle"), which owns a 140-mile pipeline that connects to an existing pipeline owned by an affiliate of Double Eagle. Double Eagle is operated by a third-party entity. This pipeline, which began operating in second quarter 2013, transports condensate from the Eagle Ford shale formation to our terminal in Corpus Christi, Texas. We receive connection fees from Double Eagle that are included in our transportation and terminals revenue on our consolidated statements of income. For the three and nine months ended September 30, 2013, we received connection fees of $0.5 million and $0.8 million, respectively, and we recorded a $0.2 million trade accounts receivable from Double Eagle at September 30, 2013.
	We own a 50% interest in BridgeTex Pipeline Company, LLC ("BridgeTex"), which is in the process of constructing a 450-mile pipeline with related infrastructure to transport crude oil from Colorado City, Texas for delivery to Houston and Texas City, Texas refineries. This pipeline is expected to begin service in mid-2014. We receive construction management fees from BridgeTex, which we report as affiliate management fee revenue on our consolidated statements of income.
	A summary of our investments in non-controlled entities follows (in thousands):
		Texas Frontera		Osage			Double Eagle		BridgeTex		Consolidated
	Investment at December 31, 2012	$	15,728	$	18,888		$	40,840	$	31,900	$	107,356
	Additional investment	—		—			33,454		147,923		181,377
	Earnings (losses) of non-controlled entities:
	Proportionate share of earnings	1,907		3,610			141		2		5,660
	Amortization of excess investment	—		(498		)	—		—		(498		)
	Earnings of non-controlled entities	1,907		3,112			141		2		5,162
	Less:
	Distributions of earnings from investments in non-controlled entities	1,907		—			—		—		1,907
	Distributions in excess of earnings of non-controlled entities	604		—			—		—		604
	Investment at September 30, 2013	$	15,124	$	22,000		$	74,435	$	179,825	$	291,384
	The operating results from Texas Frontera are included in our marine storage segment and the operating results from Osage, Double Eagle and BridgeTex are included in our crude oil segment.
	Our initial investment in Osage included an excess net investment amount of $21.7 million. Excess investment is the amount by which our initial investment exceeded our proportionate share of the book value of the net assets of the investment. The unamortized excess net investment amount at September 30, 2013 was $15.3 million.

Inventory

Inventory	9 Months Ended
	Sep. 30, 2013
Inventory Disclosure [Abstract]	'
Inventory	'
	Inventory
	Inventory at December 31, 2012 and September 30, 2013 was as follows (in thousands):
		December 31, 2012		September 30,
				2013
	Refined products	$	88,630	$	44,470
	Liquefied petroleum gases	45,657		93,202
	Transmix	63,026		57,238
	Crude oil	17,443		7,124
	Additives	7,132		6,451
	Total inventory	$	221,888	$	208,485

Employee_Benefit_Plans

Employee Benefit Plans	9 Months Ended
	Sep. 30, 2013
Compensation and Retirement Disclosure [Abstract]	'
Employee Benefit Plans	'
	Employee Benefit Plans
	We sponsor two union pension plans for certain union employees and a pension plan primarily for salaried employees, a postretirement benefit plan for selected employees and a defined contribution plan. The following tables present our consolidated net periodic benefit costs related to the pension and postretirement benefit plans for the three and nine months ended September 30, 2012 and 2013 (in thousands):
		Three Months Ended						Three Months Ended
		30-Sep-12						September 30, 2013
		Pension			Other  Post-			Pension			Other  Post-
		Benefits			Retirement			Benefits			Retirement
					Benefits						Benefits
	Components of net periodic benefit costs:
	Service cost	$	2,786		$	22		$	3,476		$	72
	Interest cost	1,240			101			1,342			103
	Expected return on plan assets	(1,448		)	—			(1,556		)	—
	Amortization of prior service cost (credit)(1)	77			—			76			(928		)
	Amortization of actuarial loss(1)	1,051			141			1,084			259
	Curtailment gain(1)	—			(4,081		)	—			—
	Net periodic benefit cost (credit)	$	3,706		$	(3,817	)	$	4,422		$	(494	)
		Nine Months Ended						Nine Months Ended
		30-Sep-12						30-Sep-13
		Pension			Other  Post-			Pension			Other  Post-
		Benefits			Retirement			Benefits			Retirement
					Benefits						Benefits
	Components of net periodic benefit costs:
	Service cost	$	9,166		$	297		$	10,426		$	216
	Interest cost	3,647			616			4,026			309
	Expected return on plan assets	(3,800		)	—			(4,671		)	—
	Amortization of prior service cost (credit)(1)	231			(424		)	230			(2,784		)
	Amortization of actuarial loss(1)	2,704			463			3,251			776
	Curtailment gain(1)	—			(4,081		)	—			—
	Net periodic benefit cost (credit)	$	11,948		$	(3,129	)	$	13,262		$	(1,483	)
	(1)These amounts are included in our Consolidated Statements of Comprehensive Income and Consolidated Statement of Cash Flows as changes in employee benefit plan assets and benefit obligations.

Debt

Debt	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Debt	'
	Debt
	Consolidated debt at December 31, 2012 and September 30, 2013 was as follows (in thousands, except as otherwise noted):
			December 31, 2012		September 30,		Weighted-Average Interest Rate at September 30,
					2013		2013 (1)
	Revolving credit facility		$	—	$	98,400	1.20%
	$250.0 million of 6.45% Notes due 2014		249,905		249,954		6.30%
	$250.0 million of 5.65% Notes due 2016		251,609		251,288		5.70%
	$250.0 million of 6.40% Notes due 2018		261,411		259,863		5.40%
	$550.0 million of 6.55% Notes due 2019		575,065		572,412		5.70%
	$550.0 million of 4.25% Notes due 2021		558,088		557,434		4.00%
	$250.0 million of 6.40% Notes due 2037		248,981		248,994		6.40%
	$250.0 million of 4.20% Notes due 2042		248,349		248,370		4.20%
	Total debt		$	2,393,408	$	2,486,715	5.20%
	-1	Weighted-average interest rate includes the impact of interest rate contracts, the amortization/accretion of discounts and premiums and the amortization/accretion of gains and losses realized on historical cash flow and fair value hedges on interest expense.
	The revolving credit facility and notes detailed in the table above are senior indebtedness.
	The face value of our debt at December 31, 2012 and September 30, 2013 was $2.4 billion. The difference between the face value and carrying value of the debt outstanding is the unamortized portion of terminated fair value hedges and the unamortized discounts and premiums on debt issuances. Realized gains and losses on fair value hedges and note discounts and premiums are being amortized or accreted to the applicable notes over the respective lives of those notes.
	6.45% Notes due 2014. The maturity date of our $250.0 million of 6.45% notes is June 1, 2014. The carrying amount of these notes was recorded as current portion of long-term debt on our consolidated balance sheet as of September 30, 2013.
	Revolving Credit Facility. The total borrowing capacity under our revolving credit facility, which matures in October 2016, is $800.0 million. Borrowings under the facility are unsecured and bear interest at LIBOR plus a spread ranging from 0.875% to 1.75% based on our credit ratings and amounts outstanding under the facility. Additionally, an unused commitment fee is assessed at a rate from 0.125% to 0.3%, depending on our credit ratings. The unused commitment fee was 0.2% at September 30, 2013. Borrowings under this facility may be used for general purposes, including capital expenditures. As of September 30, 2013, there was $98.4 million of borrowings outstanding under this facility and $5.6 million was obligated for letters of credit. Amounts obligated for letters of credit are not reflected as debt on our consolidated balance sheets but decrease our borrowing capacity under the facility.
	See Note 14 – Subsequent Events for a discussion of debt we issued after September 30, 2013.

Derivative_Financial_Instrumen

Derivative Financial Instruments	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Financial Instruments	'
	Derivative Financial Instruments
	Interest Rate Derivatives
	We periodically enter into interest rate derivatives to economically hedge debt, interest or expected debt issuances, and we have historically designated these derivatives as cash flow or fair value hedges for accounting purposes. Adjustments resulting from discontinued hedges continue to be recognized in accordance with their historic hedging relationships.
	In September 2013, we entered into $150.0 million of Treasury lock contracts to hedge against the risk of variability of future interest payments on a portion of the debt we expected to issue in early October 2013. The fair value of these contracts at September 30, 2013 was a liability of less than $0.1 million. These contracts were settled on October 3, 2013 for a loss of $0.2 million (see Note 14 – Subsequent Events, for more information about this settlement). We have accounted for these contracts as cash flow hedges.
	During 2012, we terminated and settled certain interest rate swap agreements and realized a gain of $11.0 million, which was recorded to other comprehensive income. The purpose of these swaps was to hedge against the variability of future interest payments on the refinancing of our debt that matures in 2014. If management were to determine that it was probable this forecasted transaction would not occur in 2014, the $11.0 million gain we have recorded to other comprehensive income would be reclassified into earnings.
	Commodity Derivatives
	Our butane blending activities produce gasoline products, and we can reasonably estimate the timing and quantities of sales of these products. We use a combination of forward purchase and sale contracts, NYMEX contracts and butane futures agreements to help manage price changes, which has the effect of locking in most of the product margin realized from our butane blending activities that we choose to hedge.
	We account for the forward physical purchase and sale contracts we use in our butane blending and fractionation activities as normal purchases and sales. Forward contracts that qualify for and are elected as normal purchases and sales are accounted for using traditional accrual accounting. As of September 30, 2013, we had commitments under these forward purchase and sale contracts as follows (in millions):
		Market Value				Barrels
	Forward purchase contracts	$	158.8			2.6
	Forward sale contracts	$	44.4			0.4
	We use NYMEX contracts to hedge against changes in the price of petroleum products we expect to sell in future periods. Our NYMEX contracts fall into one of three hedge categories:
	Hedge Category		Hedge Purpose		Accounting Treatment
	Qualifies For Hedge Accounting Treatment
	Cash Flow Hedge		To hedge the variability in cash flows related to a forecasted transaction.		The effective portion of changes in the value of the hedge are recorded to accumulated other comprehensive income/loss and reclassified to earnings when the forecasted transaction occurs. Any ineffectiveness is recognized currently in earnings.
	Fair Value Hedge		To hedge against changes in the fair value of a recognized asset or liability.		The effective portion of changes in the value of the hedge are recorded as adjustments to the asset or liability being hedged. Any ineffectiveness is recognized currently in earnings.
	Does Not Qualify For Hedge Accounting Treatment
	Economic Hedge		To effectively serve as either a fair value or a cash flow hedge; however, the derivative agreement does not qualify for hedge accounting treatment or is ASC 815, Derivatives and Hedging.		Changes in the value of these agreements are recognized currently in earnings.
	We also use exchange-traded butane futures agreements, which are not designated as hedges for accounting purposes, to hedge against changes in the price of butane we expect to purchase in the future. Changes in the fair value of these agreements are recognized currently in earnings as adjustments to product purchases.
	Additionally, we currently hold petroleum product inventories that we obtained from overages on our pipeline systems. We use NYMEX contracts, which are not designated as hedges for accounting purposes, to help manage price changes related to these overage inventory barrels. Changes in the fair value of these agreements are recognized currently in earnings as adjustments to operating expense.
	As outlined in the table below, our open NYMEX contracts and butane futures agreements at September 30, 2013 were as follows:
	Type of Contract/Accounting Methodology		Product Represented by the Contract and Associated Barrels		Maturity Dates
	NYMEX - Fair Value Hedges		0.7 million barrels of crude oil		Between October 2013 and November 2016
	NYMEX - Economic Hedges		3.2 million barrels of refined products and crude oil		Between October 2013 and April 2014
	Butane Futures Agreements - Economic Hedges		0.4 million barrels of butane		Between October 2013 and April 2014
	At September 30, 2013, we had made margin deposits of $10.3 million related to our NYMEX contracts, which were recorded as a current asset under energy commodity derivatives deposits on our consolidated balance sheet. We have the right to offset the combined fair values of our open NYMEX contracts and our open butane futures agreements against our margin deposits under a master netting arrangement; however, we have elected to disclose the combined fair values of our open NYMEX and butane futures agreements separately from the related margin deposits on our consolidated balance sheets. Additionally, we have the right to offset the fair values of our NYMEX agreements and butane futures agreements together for each counterparty, which we have elected to do, and we report the combined net balances on our consolidated balance sheets. A schedule of the derivative amounts we have offset and the deposit amounts we could offset under a master netting arrangement are provided below as of December 31, 2012 and September 30, 2013 (in thousands):
			31-Dec-12
	Description		Gross Amounts of Recognized Liabilities				Gross Amounts of Assets Offset in the Consolidated Balance Sheet				Net Amounts of Liabilities Presented in the Consolidated Balance Sheet				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet				Net Amount
	Derivative-related balances		$	(9,388	)		$	2,050			$	(7,338	)		$	18,304			$	10,966
			30-Sep-13
	Description		Gross Amounts of Recognized Assets				Gross Amounts of Liabilities Offset in the Consolidated Balance Sheet				Net Amounts of Assets Presented in the Consolidated Balance Sheet				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet				Net Amount
	Derivative-related balances		$	9,573			$	(166	)		$	9,407			$	10,294			$	19,701
	Impact of Derivatives on Income Statement, Balance Sheet and AOCL
	The changes in derivative activity included in accumulated other comprehensive loss ("AOCL") for the three and nine months ended September 30, 2012 and 2013 were as follows (in thousands):
		Three Months Ended September 30,								Nine Months Ended September 30,
	Derivative Gains (Losses) Included in AOCL	2012				2013				2012				2013
	Beginning balance	$	5,754			$	13,892			$	3,161			$	14,126
	Net gain (loss) on cash flow hedges	9,666				(36		)		12,341				(4,596		)
	Reclassification of net loss (gain) on cash flow hedges to income	(1,425		)		(41		)		(1,507		)		4,285
	Ending balance	$	13,995			$	13,815			$	13,995			$	13,815
	As of September 30, 2013, the net gain estimated to be classified to interest expense over the next twelve months from AOCL is approximately $0.2 million.
	During 2013, we had open NYMEX contracts on 0.7 million barrels of crude oil that were designated as fair value hedges. These agreements hedge against the change in value of our crude oil linefill and tank bottom inventory. Because there was no ineffectiveness recognized on these hedges, the cumulative losses of $10.2 million from the agreements as of September 30, 2013 were fully offset by a cumulative increase of $10.2 million to tank bottom inventory and a cumulative increase of less than $0.1 million to our crude oil linefill, which is reported in other current assets; therefore, there was no net impact from these agreements on our results of operations.
	The following tables provide a summary of the effect on our consolidated statements of income for the three and nine months ended September 30, 2012 and 2013 of the effective portion of derivatives accounted for under ASC 815-30, Derivatives and Hedging—Cash Flow Hedges, that were designated as hedging instruments (in thousands):
			Three Months Ended September 30, 2012
	Derivative Instrument		Amount of Gain (Loss) Recognized in AOCL on Derivative						Location of Gain Reclassified from AOCL into Income		Amount of Gain Reclassified from AOCL into Income
	Interest rate contracts			$	10,126				Interest expense			$	41
	NYMEX commodity contracts			(460		)			Product sales revenue			1,384
	Total cash flow hedges			$	9,666				Total			$	1,425
			Three Months Ended September 30, 2013
	Derivative Instrument		Amount of Loss Recognized in AOCL on Derivative						Location of Gain Reclassified from AOCL into Income		Amount of Gain Reclassified from AOCL into Income
	Interest rate contracts			$	(36	)			Interest expense			$	41
	NYMEX commodity contracts			—					Product sales revenue			—
	Total cash flow hedges			$	(36	)			Total			$	41
			Nine Months Ended September 30, 2012
	Derivative Instrument		Amount of Gain Recognized in AOCL on Derivative						Location of Gain Reclassified from AOCL into Income		Amount of Gain Reclassified from AOCL into Income
	Interest rate contracts			$	11,134				Interest expense			$	123
	NYMEX commodity contracts			1,207					Product sales revenue			1,384
	Total cash flow hedges			$	12,341				Total			$	1,507
			Nine Months Ended September 30, 2013
	Derivative Instrument		Amount of Loss Recognized in AOCL on Derivative						Location of Gain (Loss) Reclassified from AOCL into Income		Amount of Gain (Loss) Reclassified from AOCL into Income
	Interest rate contracts			$	(36	)			Interest expense			$	123
	NYMEX commodity contracts			(4,560		)			Product sales revenue			(4,408		)
	Total cash flow hedges			$	(4,596	)			Total			$	(4,285	)
There was no ineffectiveness recognized on the financial instruments disclosed in the above tables during the three or nine months ended September 30, 2012 or 2013.
The following table provides a summary of the effect on our consolidated statements of income for the three and nine months ended September 30, 2012 and 2013 of derivatives accounted for under ASC 815-10-35; Derivatives and Hedging—Overall—Subsequent Measurement, that were not designated as hedging instruments (in thousands):
			Amount of Gain (Loss) Recognized on Derivative
			Three Months Ended								Nine Months Ended
Derivative Instrument	Location of Gain (Loss)		September 30, 2012				September 30, 2013				September 30, 2012				September 30, 2013
	Recognized on Derivative
NYMEX commodity contracts	Product sales revenue		$	(44,706	)		$	(2,035	)		$	(39,532	)		$	8,546
NYMEX commodity contracts	Operating expenses		(7,733		)		(3,107		)		(3,216		)		(1,645		)
Butane futures agreements	Product purchases		3,007				2,878				(1,620		)		2,117
	Total		$	(49,432	)		$	(2,264	)		$	(44,368	)		$	9,018
The following tables provide a summary of the fair value of derivatives accounted for under ASC 815, Derivatives and Hedging, which are presented on a net basis in our consolidated balance sheets, that were designated as hedging instruments as of December 31, 2012 and September 30, 2013 (in thousands):
	December 31, 2012
	Asset Derivatives						Liability Derivatives
Derivative Instrument	Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
NYMEX commodity contracts	Energy commodity derivatives contracts, net		$	473			Energy commodity derivatives contracts, net		$	207
	September 30, 2013
	Asset Derivatives						Liability Derivatives
Derivative Instrument	Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
NYMEX commodity contracts	Energy commodity derivatives contracts, net		$	214			Energy commodity derivatives contracts, net		$	—
NYMEX commodity contracts	Other noncurrent assets		966				Other noncurrent liabilities		—
Interest rate contracts	Other current assets		—				Other current liabilities		36
	Total		$	1,180			Total		$	36
The following tables provide a summary of the fair value of derivatives accounted for under ASC 815, Derivatives and Hedging, which are presented on a net basis in our consolidated balance sheets, that were not designated as hedging instruments as of December 31, 2012 and September 30, 2013 (in thousands):
	December 31, 2012
	Asset Derivatives						Liability Derivatives
Derivative Instrument	Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
NYMEX commodity contracts	Energy commodity derivatives contracts, net		$	227			Energy commodity derivatives contracts, net		$	8,954
Butane futures agreements	Energy commodity derivatives contracts, net		1,350				Energy commodity derivatives contracts, net		227
	Total		$	1,577			Total		$	9,181
	September 30, 2013
	Asset Derivatives						Liability Derivatives
Derivative Instrument	Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
NYMEX commodity contracts	Energy commodity derivatives contracts, net		$	5,683			Energy commodity derivatives contracts, net		$	166
Butane futures agreements	Energy commodity derivatives contracts, net		2,710				Energy commodity derivatives contracts, net		—
	Total		$	8,393			Total		$	166

Commitments_And_Contingencies

Commitments And Contingencies	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	Clean Air Act - Section 185 Liability
	Section 185 of the Clean Air Act ("CAA 185") requires states to collect annual fees from major source facilities located in severe or extreme nonattainment ozone areas that did not meet the attainment deadline.  The CAA 185 fees are required annually until the area is redesignated as an attainment area for ozone. The Environmental Protection Agency ("EPA") is required to collect the fees if a state does not administer and enforce CAA 185.  The Houston-Galveston region was initially determined to be a severe nonattainment area that did not meet its 2007 attainment deadline and, as such, would be subject to CAA 185. In June 2013, the Texas Commission on Environmental Quality (“TCEQ”) adopted its “Failure to Attain Rule” to implement the requirements of CAA 185 which will provide for the collection of an annual failure to attain fee for excess emissions but does not require retroactive assessment of Section 185 fees for the annual periods of 2008 through 2011. As a result, we reduced our accrual and decreased our environmental expense by $10.6 million in the second quarter of 2013 in accordance with the TCEQ's final rule. The total accrual as of September 30, 2013 was $0.7 million.
	Environmental Liabilities
	Liabilities recognized for estimated environmental costs were $48.3 million and $37.5 million at December 31, 2012 and September 30, 2013, respectively. We have classified environmental liabilities as current or noncurrent based on management’s estimates regarding the timing of actual payments. Management estimates that expenditures associated with these environmental liabilities will be paid over the next 10 years. Environmental expenses recognized as a result of changes in our environmental liabilities are included in operating expenses on our consolidated statements of income. Environmental expenses for the three and nine months ended September 30, 2012 were $10.0 million and $12.7 million, respectively. Environmental expenses for the three and nine months ended September 30, 2013 were $2.9 million and $(5.8) million, respectively, with the year-to-date amount including the $10.6 million favorable adjustment to the CAA 185 liability noted above.
	Environmental Receivables
	Receivables from insurance carriers and other third parties related to environmental matters at December 31, 2012 were $7.9 million, of which $2.8 million and $5.1 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheet. Receivables from insurance carriers and other third parties related to environmental matters at September 30, 2013 were $4.9 million, of which $1.8 million and $3.1 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheet.
	Other
	We are a party to various other claims, legal actions and complaints arising in the ordinary course of business, including without limitation those disclosed in Item 1, Legal Proceedings of Part II of this report on Form 10-Q. While the results cannot be predicted with certainty, management believes the ultimate resolution of these claims, legal actions and complaints after consideration of amounts accrued, insurance coverage or other indemnification arrangements will not have a material adverse effect on our results of operations, financial position or cash flows.

LongTerm_Incentive_Plan

Long-Term Incentive Plan	9 Months Ended
	Sep. 30, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Long-Term Incentive Plan	'
	Long-Term Incentive Plan
	We have a long-term incentive plan (“LTIP”) for certain of our employees and for directors of our general partner. The LTIP primarily consists of phantom units and permits the grant of awards covering an aggregate of 9.4 million of our limited partner units as of September 30, 2013. The remaining units available under the LTIP at September 30, 2013 total 1.8 million. The compensation committee of our general partner’s board of directors administers our LTIP.
	Our equity-based incentive compensation expense was as follows (in thousands):
		Three Months Ended						Nine Months Ended
		September 30, 2012						30-Sep-12
		Equity		Liability		Total		Equity		Liability		Total
		Method		Method				Method		Method
	Performance-based awards:
	2010 awards	$	1,489	$	1,776	$	3,265	$	3,666	$	2,954	$	6,620
	2011 awards	684		566		1,250		2,111		1,021		3,132
	2012 awards	581		259		840		1,711		557		2,268
	Retention awards	192		—		192		535		—		535
	Total	$	2,946	$	2,601	$	5,547	$	8,023	$	4,532	$	12,555
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense					$	4,940					$	11,160
	Operating expense					607						1,395
	Total					$	5,547					$	12,555
		Three Months Ended						Nine Months Ended
		30-Sep-13						30-Sep-13
		Equity		Liability		Total		Equity		Liability		Total
		Method		Method				Method		Method
	Performance-based awards:
	2010 awards	$	—	$	—	$	—	$	121	$	73	$	194
	2011 awards	1,101		717		1,818		4,204		2,940		7,144
	2012 awards	856		432		1,288		2,563		1,413		3,976
	2013 awards	763		223		986		2,222		610		2,832
	Retention awards	125		—		125		353		—		353
	Total	$	2,845	$	1,372	$	4,217	$	9,463	$	5,036	$	14,499
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense					$	4,126					$	13,928
	Operating expense					91						571
	Total					$	4,217					$	14,499

Distributions

Distributions	9 Months Ended
	Sep. 30, 2013
Distributions Made to Members or Limited Partners [Abstract]	'
Distributions	'
	Distributions
	Distributions we paid during 2012 and 2013 were as follows (in thousands, except per unit amounts):
	Payment Date	Per Unit Cash			Total Cash Distribution to Limited Partners
		Distribution
		Amount
	2/14/12		$	0.4075		$	92,177
	5/15/12		0.42			95,004
	8/14/12		0.47125			106,597
	Through 9/30/2012		1.29875			293,778
	11/14/12		0.485			109,707
	Total		$	1.78375		$	403,485
	2/14/13		$	0.5		$	113,340
	5/15/13		0.5075			115,040
	8/14/13		0.5325			120,707
	Through 9/30/2013		1.54			349,087
	11/14/2013(1)		0.5575			126,374
	Total		$	2.0975		$	475,461
	(1) Our general partner's board of directors declared this cash distribution on October 24, 2013 to be paid on November 14, 2013 to unitholders of record at the close of business on November 7, 2013.

Fair_Value

Fair Value	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Fair Value	'
	Fair Value
	Fair Value Methods and Assumptions - Financial Assets and Liabilities
	We used the following methods and assumptions in estimating fair value for our financial assets and liabilities:
	•	Cash and cash equivalents. Cash equivalents include money market and mutual fund accounts and commercial paper. The carrying amounts reported on our consolidated balance sheets approximate fair value due to the short-term maturity or variable rates of these instruments.
	•	Energy commodity derivatives deposits. This asset represents short-term deposits we have made associated with our energy commodity derivatives contracts. The carrying amount reported on our consolidated balance sheets approximates fair value as the deposits change daily in relation to the associated contracts and are held in separate accounts.
	•	Energy commodity derivatives contracts. These include NYMEX futures and exchange-traded butane futures agreements related to petroleum products. These contracts are carried at fair value on our consolidated balance sheets and are valued based on quoted prices in active markets. See Note 8 – Derivative Financial Instruments for further disclosures regarding these contracts.
	•	Treasury lock hedge derivative agreements.  These agreements were entered into to protect against the risk of variability in interest payments related to a future debt issuance (see Note 8 – Derivative Financial Instruments for further disclosures regarding these agreements). Fair value was determined based on an assumed exchange, at the end of each period, in an orderly transaction with a market participant in the market in which the financial instrument is traded, adjusted for the effect of counter-party credit risk.  The exchange value was calculated using present value techniques on estimated future cash flows based on forward interest rate curves.
	•	Long-term receivables. These are primarily insurance receivables, whose fair value was determined by estimating the present value of future cash flows using a risk-free rate of interest derived from U.S. treasury rates.
	•	Debt. The fair value of our publicly traded notes was based on the prices of those notes at December 31, 2012 and September 30, 2013; however, where recent observable market trades were not available, prices were determined using adjustments to the last traded value for that debt issuance or by adjustments to the prices of similar debt instruments of peer entities that are actively traded. The carrying amount of borrowings, if any, under our revolving credit facility approximates fair value due to the variable rates of that instrument.
	Fair Value Measurements - Financial Assets and Liabilities
	The following tables summarize the carrying amounts, fair values and recurring fair value measurements recorded or disclosed as of December 31, 2012 and September 30, 2013, based on the three levels established by ASC 820-10-50; Fair Value Measurements and Disclosures—Overall—Disclosure. The carrying values of cash and cash equivalents (classified as Level 1) and energy commodity derivatives deposits approximate fair value because of the short-term nature or variable rates of these instruments; therefore, these items are not presented in the following tables.
		As of December 31, 2012
	Assets / (Liabilities) ($ in thousands)							Fair Value Measurements
		Carrying Amount			Fair Value			Quoted Prices in			Significant			Significant
								Active Markets			Other			Unobservable
								for Identical			Observable			Inputs
								Assets			Inputs			(Level 3)
								(Level 1)			(Level 2)
	Energy commodity derivatives contracts (liabilities)	$	(7,338	)	$	(7,338	)	$	(7,338	)	$	—		$	—
	Long-term receivables	$	5,135		$	5,108		$	—		$	—		$	5,108
	Debt	$	(2,393,408	)	$	(2,721,985	)	$	(2,721,985	)	$	—		$	—
		As of September 30, 2013
	Assets / (Liabilities) ($ in thousands)							Fair Value Measurements
		Carrying Amount			Fair Value			Quoted Prices in			Significant			Significant
								Active Markets			Other			Unobservable
								for Identical			Observable			Inputs
								Assets			Inputs			(Level 3)
								(Level 1)			(Level 2)
	Energy commodity derivatives contracts (assets)	$	9,407		$	9,407		$	9,407		$	—		$	—
	Treasury lock hedge agreements	$	(36	)	$	(36	)	$	—		$	(36	)	$	—
	Long-term receivables	$	3,140		$	3,097		$	—		$	—		$	3,097
	Debt	$	(2,486,715	)	$	(2,676,025	)	$	—		$	(2,676,025	)	$	—
	During second quarter 2013, we reevaluated the market in which our debt securities trade.  Based on that review, we determined that this market no longer included sufficient market activity to qualify as an active market, as defined in ASC 820, Fair Value Measurements.  As a result, we transferred the hierarchical reporting level of the fair value measurement of our debt securities from Level 1 to Level 2.  Our policy is to effect transfers between hierarchical reporting levels at the end of the reporting period where it has been determined that a change is required.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	Barry R. Pearl is an independent member of our general partner's board of directors and is also a director of Targa Resources Partners, L.P. ("Targa"). In the normal course of business, we purchase butane from subsidiaries of Targa. For the three months ended September 30, 2012 and 2013, we made purchases of butane from subsidiaries of Targa of less than $0.1 million and $1.0 million, respectively. For the nine months ended September 30, 2012 and 2013, we made purchases of butane from subsidiaries of Targa of $12.5 million and $15.6 million, respectively. These purchases were made on the same terms as comparable third-party transactions. We had $0.1 million and $0 payable to Targa at December 31, 2012 and September 30, 2013, respectively.
	See Note 4 – Investments in Non-Controlled Entities for a discussion of affiliate joint venture transactions we account for under the equity method.

Subsequent_Events

Subsequent Events	9 Months Ended
	Sep. 30, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	Subsequent Events
	Recognizable events
	No recognizable events occurred during the period.
	Non-recognizable events
	In October 2013, we issued $300.0 million of 5.15% notes due October 15, 2043 in an underwritten public offering. The notes were issued for the discounted price of 99.56% of par. We intend to use the net proceeds from this offering of approximately $295.6 million, after underwriting discounts and estimated offering expenses, to repay borrowings outstanding under our revolving credit facility and for general partnership purposes, which may include capital expenditures.
	In September 2013, we entered into $150.0 million of Treasury lock contracts to protect against the risk of variability in future interest payments associated with the $300.0 million of notes discussed above (see Note 8 – Derivative Financial Instruments for more information on the Treasury lock contracts). In October 2013, we settled these Treasury lock contracts and realized a loss of $0.2 million. The loss was recorded to other comprehensive income and will be recognized into earnings as an adjustment to our periodic interest accruals over the next 30 years to coincide with interest payments on the underlying debt.
	In October 2013, our general partner's board of directors declared a quarterly distribution of $0.5575 per unit to be paid on November 14, 2013 to unitholders of record at the close of business on November 7, 2013. The total cash distributions expected to be paid are $126.4 million.

Product_Sales_Revenues_Tables

Product Sales Revenues (Tables)	9 Months Ended
	Sep. 30, 2013
Product Sales Revenues [Abstract]	'
Components of Product Sales Revenues	'
	For the three and nine months ended September 30, 2012 and 2013, product sales revenue included the following (in thousands):
		Three Months Ended September 30,						Nine Months Ended September 30,
		2012			2013			2012			2013
	Physical sale of petroleum products	$	113,500		$	146,887		$	584,624		$	500,347
	NYMEX contract adjustments:
	Change in value of NYMEX contracts that did not qualify for hedge accounting treatment and the effective portion of gains and losses of matured NYMEX contracts that qualified for hedge accounting treatment associated with our butane blending and fractionation activities(1)	(36,172		)	(2,035		)	(33,211		)	4,149
	Change in value of NYMEX contracts that did not qualify for hedge accounting treatment associated with the Houston-to-El Paso pipeline linefill working inventory(1)	(7,080		)	—			(5,159		)	—
	Other	(70		)	—			222			(11		)
	Total NYMEX contract adjustments	(43,322		)	(2,035		)	(38,148		)	4,138
	Total product sales revenue	$	70,178		$	144,852		$	546,476		$	504,485
	(1) The associated petroleum products for these activities are, to the extent still owned as of the statement date, or were, to the extent no longer owned as of the statement date, classified as inventory in current assets on our consolidated balance sheets.

Segment_Disclosures_Tables

Segment Disclosures (Tables)	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
Schedule of Business Segment Reporting Information	'
		Three Months Ended September 30, 2012
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	193,880	$	23,868		$	37,744		$	—		$	255,492
	Product sales revenue	66,776		—			3,402			—			70,178
	Affiliate management fee revenue	—		199			—			—			199
	Total revenue	260,656		24,067			41,146			—			325,869
	Operating expenses	80,705		3,441			19,824			(698		)	103,272
	Product purchases	84,041		—			1,778			—			85,819
	(Earnings) losses of non-controlled entities	—		(1,752		)	3			—			(1,749		)
	Operating margin	95,910		22,378			19,541			698			138,527
	Depreciation and amortization expense	21,432		2,885			6,677			698			31,692
	G&A expenses	21,948		1,375			4,228			—			27,551
	Operating profit	$	52,530	$	18,118		$	8,636		$	—		$	79,284
		Three Months Ended September 30, 2013
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	205,859	$	49,519		$	39,948		$	—		$	295,326
	Product sales revenue	143,549		—			1,303			—			144,852
	Affiliate management fee revenue	—		3,369			288			—			3,657
	Total revenue	349,408		52,888			41,539			—			443,835
	Operating expenses	82,174		4,034			17,813			(759		)	103,262
	Product purchases	120,429		—			(130		)	—			120,299
	Earnings of non-controlled entities	—		(1,770		)	(605		)	—			(2,375		)
	Operating margin	146,805		50,624			24,461			759			222,649
	Depreciation and amortization expense	21,851		5,538			7,122			759			35,270
	G&A expenses	22,741		5,100			4,914			—			32,755
	Operating profit	$	102,213	$	39,986		$	12,425		$	—		$	154,624
		Nine Months Ended September 30, 2012
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	538,812	$	67,626		$	115,369		$	—		$	721,807
	Product sales revenue	539,434		—			7,042			—			546,476
	Affiliate management fee revenue	—		596			—			—			596
	Total revenue	1,078,246		68,222			122,411			—			1,268,879
	Operating expenses	204,064		4,046			48,042			(2,102		)	254,050
	Product purchases	475,839		—			3,090			—			478,929
	(Earnings) losses of non-controlled entities	—		(4,913		)	38			—			(4,875		)
	Operating margin	398,343		69,089			71,241			2,102			540,775
	Depreciation and amortization expense	64,075		8,641			19,870			2,102			94,688
	G&A expenses	61,258		3,766			11,685			—			76,709
	Operating profit	$	273,010	$	56,682		$	39,686		$	—		$	369,378
		Nine Months Ended September 30, 2013
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	573,615	$	113,905		$	117,539		$	—		$	805,059
	Product sales revenue	499,285		—			5,200			—			504,485
	Affiliate management fee revenue	—		9,767			857			—			10,624
	Total revenue	1,072,900		123,672			123,596			—			1,320,168
	Operating expenses	194,911		13,168			40,060			(2,281		)	245,858
	Product purchases	393,187		—			2,838			—			396,025
	Earnings of non-controlled entities	—		(3,255		)	(1,907		)	—			(5,162		)
	Operating margin	484,802		113,759			82,605			2,281			683,447
	Depreciation and amortization expense	64,428		18,111			20,968			2,281			105,788
	G&A expenses	67,235		14,142			14,696			—			96,073
	Operating profit	$	353,139	$	81,506		$	46,941		$	—		$	481,586

Investments_in_NonControlled_E1

Investments in Non-Controlled Entities (Tables)	9 Months Ended
	Sep. 30, 2013
Equity Method Investments and Joint Ventures [Abstract]	'
Schedule of Equity Method Investments	'
	A summary of our investments in non-controlled entities follows (in thousands):
		Texas Frontera		Osage			Double Eagle		BridgeTex		Consolidated
	Investment at December 31, 2012	$	15,728	$	18,888		$	40,840	$	31,900	$	107,356
	Additional investment	—		—			33,454		147,923		181,377
	Earnings (losses) of non-controlled entities:
	Proportionate share of earnings	1,907		3,610			141		2		5,660
	Amortization of excess investment	—		(498		)	—		—		(498		)
	Earnings of non-controlled entities	1,907		3,112			141		2		5,162
	Less:
	Distributions of earnings from investments in non-controlled entities	1,907		—			—		—		1,907
	Distributions in excess of earnings of non-controlled entities	604		—			—		—		604
	Investment at September 30, 2013	$	15,124	$	22,000		$	74,435	$	179,825	$	291,384

Inventory_Tables

Inventory (Tables)	9 Months Ended
	Sep. 30, 2013
Inventory Disclosure [Abstract]	'
Schedule of Inventory	'
	Inventory at December 31, 2012 and September 30, 2013 was as follows (in thousands):
		December 31, 2012		September 30,
				2013
	Refined products	$	88,630	$	44,470
	Liquefied petroleum gases	45,657		93,202
	Transmix	63,026		57,238
	Crude oil	17,443		7,124
	Additives	7,132		6,451
	Total inventory	$	221,888	$	208,485

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	9 Months Ended
	Sep. 30, 2013
Compensation and Retirement Disclosure [Abstract]	'
Schedule Of Consolidated Net Periodic Benefit Costs	'
	The following tables present our consolidated net periodic benefit costs related to the pension and postretirement benefit plans for the three and nine months ended September 30, 2012 and 2013 (in thousands):
		Three Months Ended						Three Months Ended
		30-Sep-12						September 30, 2013
		Pension			Other  Post-			Pension			Other  Post-
		Benefits			Retirement			Benefits			Retirement
					Benefits						Benefits
	Components of net periodic benefit costs:
	Service cost	$	2,786		$	22		$	3,476		$	72
	Interest cost	1,240			101			1,342			103
	Expected return on plan assets	(1,448		)	—			(1,556		)	—
	Amortization of prior service cost (credit)(1)	77			—			76			(928		)
	Amortization of actuarial loss(1)	1,051			141			1,084			259
	Curtailment gain(1)	—			(4,081		)	—			—
	Net periodic benefit cost (credit)	$	3,706		$	(3,817	)	$	4,422		$	(494	)
		Nine Months Ended						Nine Months Ended
		30-Sep-12						30-Sep-13
		Pension			Other  Post-			Pension			Other  Post-
		Benefits			Retirement			Benefits			Retirement
					Benefits						Benefits
	Components of net periodic benefit costs:
	Service cost	$	9,166		$	297		$	10,426		$	216
	Interest cost	3,647			616			4,026			309
	Expected return on plan assets	(3,800		)	—			(4,671		)	—
	Amortization of prior service cost (credit)(1)	231			(424		)	230			(2,784		)
	Amortization of actuarial loss(1)	2,704			463			3,251			776
	Curtailment gain(1)	—			(4,081		)	—			—
	Net periodic benefit cost (credit)	$	11,948		$	(3,129	)	$	13,262		$	(1,483	)
	(1)These amounts are included in our Consolidated Statements of Comprehensive Income and Consolidated Statement of Cash Flows as changes in employee benefit plan assets and benefit obligations.

Debt_Tables

Debt (Tables)	9 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Consolidated Debt	'
	Consolidated debt at December 31, 2012 and September 30, 2013 was as follows (in thousands, except as otherwise noted):
			December 31, 2012		September 30,		Weighted-Average Interest Rate at September 30,
					2013		2013 (1)
	Revolving credit facility		$	—	$	98,400	1.20%
	$250.0 million of 6.45% Notes due 2014		249,905		249,954		6.30%
	$250.0 million of 5.65% Notes due 2016		251,609		251,288		5.70%
	$250.0 million of 6.40% Notes due 2018		261,411		259,863		5.40%
	$550.0 million of 6.55% Notes due 2019		575,065		572,412		5.70%
	$550.0 million of 4.25% Notes due 2021		558,088		557,434		4.00%
	$250.0 million of 6.40% Notes due 2037		248,981		248,994		6.40%
	$250.0 million of 4.20% Notes due 2042		248,349		248,370		4.20%
	Total debt		$	2,393,408	$	2,486,715	5.20%
	-1	Weighted-average interest rate includes the impact of interest rate contracts, the amortization/accretion of discounts and premiums and the amortization/accretion of gains and losses realized on historical cash flow and fair value hedges on interest expense.

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule Of Forward Purchase And Sales Contracts	'
	As of September 30, 2013, we had commitments under these forward purchase and sale contracts as follows (in millions):
		Market Value				Barrels
	Forward purchase contracts	$	158.8			2.6
	Forward sale contracts	$	44.4			0.4
Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements	'
	As outlined in the table below, our open NYMEX contracts and butane futures agreements at September 30, 2013 were as follows:
	Type of Contract/Accounting Methodology		Product Represented by the Contract and Associated Barrels		Maturity Dates
	NYMEX - Fair Value Hedges		0.7 million barrels of crude oil		Between October 2013 and November 2016
	NYMEX - Economic Hedges		3.2 million barrels of refined products and crude oil		Between October 2013 and April 2014
	Butane Futures Agreements - Economic Hedges		0.4 million barrels of butane		Between October 2013 and April 2014
Derivatives and Offset Amounts [Table Text Block]	'
	A schedule of the derivative amounts we have offset and the deposit amounts we could offset under a master netting arrangement are provided below as of December 31, 2012 and September 30, 2013 (in thousands):
			31-Dec-12
	Description		Gross Amounts of Recognized Liabilities				Gross Amounts of Assets Offset in the Consolidated Balance Sheet				Net Amounts of Liabilities Presented in the Consolidated Balance Sheet				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet				Net Amount
	Derivative-related balances		$	(9,388	)		$	2,050			$	(7,338	)		$	18,304			$	10,966
			30-Sep-13
	Description		Gross Amounts of Recognized Assets				Gross Amounts of Liabilities Offset in the Consolidated Balance Sheet				Net Amounts of Assets Presented in the Consolidated Balance Sheet				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet				Net Amount
	Derivative-related balances		$	9,573			$	(166	)		$	9,407			$	10,294			$	19,701
Derivative Gains Included In Accumulated Other Comprehensive Loss (AOCL)	'
	The changes in derivative activity included in accumulated other comprehensive loss ("AOCL") for the three and nine months ended September 30, 2012 and 2013 were as follows (in thousands):
		Three Months Ended September 30,								Nine Months Ended September 30,
	Derivative Gains (Losses) Included in AOCL	2012				2013				2012				2013
	Beginning balance	$	5,754			$	13,892			$	3,161			$	14,126
	Net gain (loss) on cash flow hedges	9,666				(36		)		12,341				(4,596		)
	Reclassification of net loss (gain) on cash flow hedges to income	(1,425		)		(41		)		(1,507		)		4,285
	Ending balance	$	13,995			$	13,815			$	13,995			$	13,815
Derivatives And Hedging-Cash Flow Hedges	'
	The following tables provide a summary of the effect on our consolidated statements of income for the three and nine months ended September 30, 2012 and 2013 of the effective portion of derivatives accounted for under ASC 815-30, Derivatives and Hedging—Cash Flow Hedges, that were designated as hedging instruments (in thousands):
			Three Months Ended September 30, 2012
	Derivative Instrument		Amount of Gain (Loss) Recognized in AOCL on Derivative						Location of Gain Reclassified from AOCL into Income		Amount of Gain Reclassified from AOCL into Income
	Interest rate contracts			$	10,126				Interest expense			$	41
	NYMEX commodity contracts			(460		)			Product sales revenue			1,384
	Total cash flow hedges			$	9,666				Total			$	1,425
			Three Months Ended September 30, 2013
	Derivative Instrument		Amount of Loss Recognized in AOCL on Derivative						Location of Gain Reclassified from AOCL into Income		Amount of Gain Reclassified from AOCL into Income
	Interest rate contracts			$	(36	)			Interest expense			$	41
	NYMEX commodity contracts			—					Product sales revenue			—
	Total cash flow hedges			$	(36	)			Total			$	41
			Nine Months Ended September 30, 2012
	Derivative Instrument		Amount of Gain Recognized in AOCL on Derivative						Location of Gain Reclassified from AOCL into Income		Amount of Gain Reclassified from AOCL into Income
	Interest rate contracts			$	11,134				Interest expense			$	123
	NYMEX commodity contracts			1,207					Product sales revenue			1,384
	Total cash flow hedges			$	12,341				Total			$	1,507
			Nine Months Ended September 30, 2013
	Derivative Instrument		Amount of Loss Recognized in AOCL on Derivative						Location of Gain (Loss) Reclassified from AOCL into Income		Amount of Gain (Loss) Reclassified from AOCL into Income
	Interest rate contracts			$	(36	)			Interest expense			$	123
	NYMEX commodity contracts			(4,560		)			Product sales revenue			(4,408		)
	Total cash flow hedges			$	(4,596	)			Total			$	(4,285	)
Derivatives And Hedging-Overall-Subsequent Measurement	'
	The following table provides a summary of the effect on our consolidated statements of income for the three and nine months ended September 30, 2012 and 2013 of derivatives accounted for under ASC 815-10-35; Derivatives and Hedging—Overall—Subsequent Measurement, that were not designated as hedging instruments (in thousands):
				Amount of Gain (Loss) Recognized on Derivative
				Three Months Ended								Nine Months Ended
	Derivative Instrument	Location of Gain (Loss)		September 30, 2012				September 30, 2013				September 30, 2012				September 30, 2013
		Recognized on Derivative
	NYMEX commodity contracts	Product sales revenue		$	(44,706	)		$	(2,035	)		$	(39,532	)		$	8,546
	NYMEX commodity contracts	Operating expenses		(7,733		)		(3,107		)		(3,216		)		(1,645		)
	Butane futures agreements	Product purchases		3,007				2,878				(1,620		)		2,117
		Total		$	(49,432	)		$	(2,264	)		$	(44,368	)		$	9,018
Derivatives And Hedging-Designated	'
	The following tables provide a summary of the fair value of derivatives accounted for under ASC 815, Derivatives and Hedging, which are presented on a net basis in our consolidated balance sheets, that were designated as hedging instruments as of December 31, 2012 and September 30, 2013 (in thousands):
		December 31, 2012
		Asset Derivatives						Liability Derivatives
	Derivative Instrument	Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
	NYMEX commodity contracts	Energy commodity derivatives contracts, net		$	473			Energy commodity derivatives contracts, net		$	207
		September 30, 2013
		Asset Derivatives						Liability Derivatives
	Derivative Instrument	Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
	NYMEX commodity contracts	Energy commodity derivatives contracts, net		$	214			Energy commodity derivatives contracts, net		$	—
	NYMEX commodity contracts	Other noncurrent assets		966				Other noncurrent liabilities		—
	Interest rate contracts	Other current assets		—				Other current liabilities		36
		Total		$	1,180			Total		$	36
Derivatives And Hedging-Nondesignated	'
	The following tables provide a summary of the fair value of derivatives accounted for under ASC 815, Derivatives and Hedging, which are presented on a net basis in our consolidated balance sheets, that were not designated as hedging instruments as of December 31, 2012 and September 30, 2013 (in thousands):
		December 31, 2012
		Asset Derivatives						Liability Derivatives
	Derivative Instrument	Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
	NYMEX commodity contracts	Energy commodity derivatives contracts, net		$	227			Energy commodity derivatives contracts, net		$	8,954
	Butane futures agreements	Energy commodity derivatives contracts, net		1,350				Energy commodity derivatives contracts, net		227
		Total		$	1,577			Total		$	9,181
		September 30, 2013
		Asset Derivatives						Liability Derivatives
	Derivative Instrument	Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
	NYMEX commodity contracts	Energy commodity derivatives contracts, net		$	5,683			Energy commodity derivatives contracts, net		$	166
	Butane futures agreements	Energy commodity derivatives contracts, net		2,710				Energy commodity derivatives contracts, net		—
		Total		$	8,393			Total		$	166

LongTerm_Incentive_Plan_Tables

Long-Term Incentive Plan (Tables)	9 Months Ended
	Sep. 30, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Equity-Based Incentive Compensation Expense	'
	Our equity-based incentive compensation expense was as follows (in thousands):
		Three Months Ended						Nine Months Ended
		September 30, 2012						30-Sep-12
		Equity		Liability		Total		Equity		Liability		Total
		Method		Method				Method		Method
	Performance-based awards:
	2010 awards	$	1,489	$	1,776	$	3,265	$	3,666	$	2,954	$	6,620
	2011 awards	684		566		1,250		2,111		1,021		3,132
	2012 awards	581		259		840		1,711		557		2,268
	Retention awards	192		—		192		535		—		535
	Total	$	2,946	$	2,601	$	5,547	$	8,023	$	4,532	$	12,555
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense					$	4,940					$	11,160
	Operating expense					607						1,395
	Total					$	5,547					$	12,555
		Three Months Ended						Nine Months Ended
		30-Sep-13						30-Sep-13
		Equity		Liability		Total		Equity		Liability		Total
		Method		Method				Method		Method
	Performance-based awards:
	2010 awards	$	—	$	—	$	—	$	121	$	73	$	194
	2011 awards	1,101		717		1,818		4,204		2,940		7,144
	2012 awards	856		432		1,288		2,563		1,413		3,976
	2013 awards	763		223		986		2,222		610		2,832
	Retention awards	125		—		125		353		—		353
	Total	$	2,845	$	1,372	$	4,217	$	9,463	$	5,036	$	14,499
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense					$	4,126					$	13,928
	Operating expense					91						571
	Total					$	4,217					$	14,499

Distributions_Tables

Distributions (Tables)	9 Months Ended
	Sep. 30, 2013
Distributions Made to Members or Limited Partners [Abstract]	'
Schedule Of Distributions	'
	Distributions we paid during 2012 and 2013 were as follows (in thousands, except per unit amounts):
	Payment Date	Per Unit Cash			Total Cash Distribution to Limited Partners
		Distribution
		Amount
	2/14/12		$	0.4075		$	92,177
	5/15/12		0.42			95,004
	8/14/12		0.47125			106,597
	Through 9/30/2012		1.29875			293,778
	11/14/12		0.485			109,707
	Total		$	1.78375		$	403,485
	2/14/13		$	0.5		$	113,340
	5/15/13		0.5075			115,040
	8/14/13		0.5325			120,707
	Through 9/30/2013		1.54			349,087
	11/14/2013(1)		0.5575			126,374
	Total		$	2.0975		$	475,461
	(1) Our general partner's board of directors declared this cash distribution on October 24, 2013 to be paid on November 14, 2013 to unitholders of record at the close of business on

Fair_Value_Tables

Fair Value (Tables)	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Schedule Of Fair Value, Assets and Liabilities Measured on Recurring Basis	'
	The following tables summarize the carrying amounts, fair values and recurring fair value measurements recorded or disclosed as of December 31, 2012 and September 30, 2013, based on the three levels established by ASC 820-10-50; Fair Value Measurements and Disclosures—Overall—Disclosure. The carrying values of cash and cash equivalents (classified as Level 1) and energy commodity derivatives deposits approximate fair value because of the short-term nature or variable rates of these instruments; therefore, these items are not presented in the following tables.
		As of December 31, 2012
	Assets / (Liabilities) ($ in thousands)							Fair Value Measurements
		Carrying Amount			Fair Value			Quoted Prices in			Significant			Significant
								Active Markets			Other			Unobservable
								for Identical			Observable			Inputs
								Assets			Inputs			(Level 3)
								(Level 1)			(Level 2)
	Energy commodity derivatives contracts (liabilities)	$	(7,338	)	$	(7,338	)	$	(7,338	)	$	—		$	—
	Long-term receivables	$	5,135		$	5,108		$	—		$	—		$	5,108
	Debt	$	(2,393,408	)	$	(2,721,985	)	$	(2,721,985	)	$	—		$	—
		As of September 30, 2013
	Assets / (Liabilities) ($ in thousands)							Fair Value Measurements
		Carrying Amount			Fair Value			Quoted Prices in			Significant			Significant
								Active Markets			Other			Unobservable
								for Identical			Observable			Inputs
								Assets			Inputs			(Level 3)
								(Level 1)			(Level 2)
	Energy commodity derivatives contracts (assets)	$	9,407		$	9,407		$	9,407		$	—		$	—
	Treasury lock hedge agreements	$	(36	)	$	(36	)	$	—		$	(36	)	$	—
	Long-term receivables	$	3,140		$	3,097		$	—		$	—		$	3,097
	Debt	$	(2,486,715	)	$	(2,676,025	)	$	—		$	(2,676,025	)	$	—

Organization_Description_of_Bu1

Organization, Description of Business And Basis Of Presentation Organization, Description of Business and Basis of Presentation (Narrative) (Details)	Sep. 30, 2013
	Terminal
	mi
Refined Products [Member]	'
Organization and Description of Business [Line Items]	'
Length of Refined Products Pipeline	9,100
Number of Pipeline Terminals	49
Number of Independent Terminals	27
Length of Ammonia Pipeline System	1,100
Crude Oil Pipeline and Terminals [Member]	'
Organization and Description of Business [Line Items]	'
Length of Crude Oil Pipeline	800
Storage Capacity	15,000,000
Marine Storage [Member]	'
Organization and Description of Business [Line Items]	'
Storage Capacity	26,000,000

Product_Sales_Revenues_Compone

Product Sales Revenues (Components Of Product Sales Revenues) (Details) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Product Sales Revenue [Line Items]	'		'		'		'
Physical sale of petroleum products	$146,887		$113,500		$500,347		$584,624
Total NYMEX contract adjustments	-2,035		-43,322		4,138		-38,148
Total product sales revenue	144,852		70,178		504,485		546,476
Petroleum Products Blending and Fractionation Activities [Member]	'		'		'		'
Product Sales Revenue [Line Items]	'		'		'		'
Total NYMEX contract adjustments	-2,035	[1]	-36,172	[1]	4,149	[1]	-33,211	[1]
Houston-To-El Paso Pipeline Section Line Fill and Working Inventory [Member]	'		'		'		'
Product Sales Revenue [Line Items]	'		'		'		'
Total NYMEX contract adjustments	0	[1]	-7,080	[1]	0	[1]	-5,159	[1]
Other Commodity Activities [Member]	'		'		'		'
Product Sales Revenue [Line Items]	'		'		'		'
Total NYMEX contract adjustments	$0		($70)		($11)		$222
[1]	The associated petroleum products for these activities are, to the extent still owned as of the statement date, or were, to the extent no longer owned as of the statement date, classified as inventory in current assets on our consolidated balance sheets.

Segment_Disclosures_Schedule_O

Segment Disclosures (Schedule Of Business Segment Reporting Information) (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Segment Reporting Information [Line Items]	'	'	'	'
Transportation and terminals revenue	$295,326	$255,492	$805,059	$721,807
Product sales revenue	144,852	70,178	504,485	546,476
Affiliate management fee revenue	3,657	199	10,624	596
Total revenue	443,835	325,869	1,320,168	1,268,879
Operating expenses	103,262	103,272	245,858	254,050
Product purchases	120,299	85,819	396,025	478,929
Earnings of non-controlled entities	-2,375	-1,749	-5,162	-4,875
Operating margin	222,649	138,527	683,447	540,775
Depreciation and amortization expense	35,270	31,692	105,788	94,688
G&A expenses	32,755	27,551	96,073	76,709
Operating profit	154,624	79,284	481,586	369,378
Operating Segments [Member] | Refined Products [Member]	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Transportation and terminals revenue	205,859	193,880	573,615	538,812
Product sales revenue	143,549	66,776	499,285	539,434
Affiliate management fee revenue	0	0	0	0
Total revenue	349,408	260,656	1,072,900	1,078,246
Operating expenses	82,174	80,705	194,911	204,064
Product purchases	120,429	84,041	393,187	475,839
Earnings of non-controlled entities	0	0	0	0
Operating margin	146,805	95,910	484,802	398,343
Depreciation and amortization expense	21,851	21,432	64,428	64,075
G&A expenses	22,741	21,948	67,235	61,258
Operating profit	102,213	52,530	353,139	273,010
Operating Segments [Member] | Crude Oil Pipeline and Terminals [Member]	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Transportation and terminals revenue	49,519	23,868	113,905	67,626
Product sales revenue	0	0	0	0
Affiliate management fee revenue	3,369	199	9,767	596
Total revenue	52,888	24,067	123,672	68,222
Operating expenses	4,034	3,441	13,168	4,046
Product purchases	0	0	0	0
Earnings of non-controlled entities	-1,770	-1,752	-3,255	-4,913
Operating margin	50,624	22,378	113,759	69,089
Depreciation and amortization expense	5,538	2,885	18,111	8,641
G&A expenses	5,100	1,375	14,142	3,766
Operating profit	39,986	18,118	81,506	56,682
Operating Segments [Member] | Marine Storage [Member]	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Transportation and terminals revenue	39,948	37,744	117,539	115,369
Product sales revenue	1,303	3,402	5,200	7,042
Affiliate management fee revenue	288	0	857	0
Total revenue	41,539	41,146	123,596	122,411
Operating expenses	17,813	19,824	40,060	48,042
Product purchases	-130	1,778	2,838	3,090
Earnings of non-controlled entities	-605	3	-1,907	38
Operating margin	24,461	19,541	82,605	71,241
Depreciation and amortization expense	7,122	6,677	20,968	19,870
G&A expenses	4,914	4,228	14,696	11,685
Operating profit	12,425	8,636	46,941	39,686
Intersegment Eliminations [Member]	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Transportation and terminals revenue	0	0	0	0
Product sales revenue	0	0	0	0
Affiliate management fee revenue	0	0	0	0
Total revenue	0	0	0	0
Operating expenses	-759	-698	-2,281	-2,102
Product purchases	0	0	0	0
Earnings of non-controlled entities	0	0	0	0
Operating margin	759	698	2,281	2,102
Depreciation and amortization expense	759	698	2,281	2,102
G&A expenses	0	0	0	0
Operating profit	$0	$0	$0	$0

Investments_in_NonControlled_E2

Investments in Non-Controlled Entities (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Change in Equity Method Investments [Roll Forward]	'	'	'	'
Investment at December 31, 2012	'	'	$107,356,000	'
Additional investment	'	'	181,377,000	37,495,000
Proportionate share of earnings	'	'	5,660,000	'
Amortization of excess investment	'	'	-498,000	'
Earnings of non-controlled entities	2,375,000	1,749,000	5,162,000	4,875,000
Distributions of earnings from investments in non-controlled entities	'	'	1,907,000	4,875,000
Distributions in excess of earnings of non-controlled entities	'	'	604,000	1,228,000
Investment at September 30, 2013	291,384,000	'	291,384,000	'
Texas Frontera Llc [Member]	'	'	'	'
Change in Equity Method Investments [Roll Forward]	'	'	'	'
Investment at December 31, 2012	'	'	15,728,000	'
Additional investment	'	'	0	'
Proportionate share of earnings	'	'	1,907,000	'
Amortization of excess investment	'	'	0	'
Earnings of non-controlled entities	'	'	1,907,000	'
Distributions of earnings from investments in non-controlled entities	'	'	1,907,000	'
Distributions in excess of earnings of non-controlled entities	'	'	604,000	'
Investment at September 30, 2013	15,124,000	'	15,124,000	'
Interest in equity method investment	50.00%	'	50.00%	'
Storage Capacity	800,000	'	800,000	'
Osage Pipeline Co [Member]	'	'	'	'
Change in Equity Method Investments [Roll Forward]	'	'	'	'
Investment at December 31, 2012	'	'	18,888,000	'
Additional investment	'	'	0	'
Proportionate share of earnings	'	'	3,610,000	'
Amortization of excess investment	'	'	-498,000	'
Earnings of non-controlled entities	'	'	3,112,000	'
Distributions of earnings from investments in non-controlled entities	'	'	0	'
Distributions in excess of earnings of non-controlled entities	'	'	0	'
Investment at September 30, 2013	22,000,000	'	22,000,000	'
Interest in equity method investment	50.00%	'	50.00%	'
Length of Crude Oil Pipeline	135	'	135	'
Equity Method Investments Excess Investment Gross	21,700,000	'	21,700,000	'
Equity Method Investments Unamortized Excess Investment Net	15,300,000	'	15,300,000	'
Double Eagle Pipeline Llc [Member]	'	'	'	'
Change in Equity Method Investments [Roll Forward]	'	'	'	'
Investment at December 31, 2012	'	'	40,840,000	'
Additional investment	'	'	33,454,000	'
Proportionate share of earnings	'	'	141,000	'
Amortization of excess investment	'	'	0	'
Earnings of non-controlled entities	'	'	141,000	'
Distributions of earnings from investments in non-controlled entities	'	'	0	'
Distributions in excess of earnings of non-controlled entities	'	'	0	'
Investment at September 30, 2013	74,435,000	'	74,435,000	'
Interest in equity method investment	50.00%	'	50.00%	'
Length of Crude Oil Pipeline	140	'	140	'
Related Party Transaction, Other Revenues from Transactions with Related Party	500,000	'	800,000	'
Accounts Receivable, Related Parties, Current	200,000	'	200,000	'
BridgeTex [Member]	'	'	'	'
Change in Equity Method Investments [Roll Forward]	'	'	'	'
Investment at December 31, 2012	'	'	31,900,000	'
Additional investment	'	'	147,923,000	'
Proportionate share of earnings	'	'	2,000	'
Amortization of excess investment	'	'	0	'
Earnings of non-controlled entities	'	'	2,000	'
Distributions of earnings from investments in non-controlled entities	'	'	0	'
Distributions in excess of earnings of non-controlled entities	'	'	0	'
Investment at September 30, 2013	$179,825,000	'	$179,825,000	'
Interest in equity method investment	50.00%	'	50.00%	'
Length of Crude Oil Pipeline	450	'	450	'

Inventory_Details

Inventory (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Refined products	$44,470	$88,630
Liquefied petroleum gases	93,202	45,657
Transmix	57,238	63,026
Crude oil	7,124	17,443
Additives	6,451	7,132
Total inventory	$208,485	$221,888

Employee_Benefit_Plans_Details

Employee Benefit Plans (Details) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Defined Benefit Plan Disclosure [Line Items]	'		'		'		'
Number of Union Pension Plans	'		'		2		'
Pension Benefits	'		'		'		'
Components of net periodic benefit costs:	'		'		'		'
Service cost	$3,476		$2,786		$10,426		$9,166
Interest cost	1,342		1,240		4,026		3,647
Expected return on plan assets	-1,556		-1,448		-4,671		-3,800
Amortization of prior service cost (credit)(1)	76	[1]	77	[1]	230	[1]	231	[1]
Amortization of actuarial loss(1)	1,084	[1]	1,051	[1]	3,251	[1]	2,704	[1]
Curtailment gain(1)	0	[1]	0	[1]	0	[1]	0	[1]
Net periodic benefit cost (credit)	4,422		3,706		13,262		11,948
Other Post-Retirement Benefits	'		'		'		'
Components of net periodic benefit costs:	'		'		'		'
Service cost	72		22		216		297
Interest cost	103		101		309		616
Expected return on plan assets	0		0		0		0
Amortization of prior service cost (credit)(1)	-928	[1]	0	[1]	-2,784	[1]	-424	[1]
Amortization of actuarial loss(1)	259	[1]	141	[1]	776	[1]	463	[1]
Curtailment gain(1)	0	[1]	-4,081	[1]	0	[1]	-4,081	[1]
Net periodic benefit cost (credit)	($494)		($3,817)		($1,483)		($3,129)
[1]	These amounts are included in our Consolidated Statements of Comprehensive Income and Consolidated Statement of Cash Flows as changes in employee benefit plan assets and benefit obligations.

Debt_Consolidated_Debt_Details

Debt (Consolidated Debt) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
Debt Instrument [Line Items]	'		'
Total debt	$2,486,715,000		$2,393,408,000
Weighted-Average Interest Rate	5.20%	[1]	'
Face value of debt	2,400,000,000		2,400,000,000
Revolving Credit Facility [Member]	'		'
Debt Instrument [Line Items]	'		'
Total debt	98,400,000		0
Weighted-Average Interest Rate	1.20%	[1]	'
Senior Notes [Member] | 6.45% Notes Due 2014 [Member]	'		'
Debt Instrument [Line Items]	'		'
Total debt	249,954,000		249,905,000
Weighted-Average Interest Rate	6.30%	[1]	'
Face value of debt	250,000,000		'
Debt Instrument, Interest Rate, Stated Percentage	6.45%		'
Senior Notes [Member] | 5.65% Notes Due 2016 [Member]	'		'
Debt Instrument [Line Items]	'		'
Total debt	251,288,000		251,609,000
Weighted-Average Interest Rate	5.70%	[1]	'
Face value of debt	250,000,000		'
Debt Instrument, Interest Rate, Stated Percentage	5.65%		'
Senior Notes [Member] | 6.40% Notes Due 2018 [Member]	'		'
Debt Instrument [Line Items]	'		'
Total debt	259,863,000		261,411,000
Weighted-Average Interest Rate	5.40%	[1]	'
Face value of debt	250,000,000		'
Debt Instrument, Interest Rate, Stated Percentage	6.40%		'
Senior Notes [Member] | 6.55% Notes Due 2019 [Member]	'		'
Debt Instrument [Line Items]	'		'
Total debt	572,412,000		575,065,000
Weighted-Average Interest Rate	5.70%	[1]	'
Face value of debt	550,000,000		'
Debt Instrument, Interest Rate, Stated Percentage	6.55%		'
Senior Notes [Member] | 4.25% Notes Due 2021 [Member]	'		'
Debt Instrument [Line Items]	'		'
Total debt	557,434,000		558,088,000
Weighted-Average Interest Rate	4.00%	[1]	'
Face value of debt	550,000,000		'
Debt Instrument, Interest Rate, Stated Percentage	4.25%		'
Senior Notes [Member] | 6.40% Notes Due 2037 [Member]	'		'
Debt Instrument [Line Items]	'		'
Total debt	248,994,000		248,981,000
Weighted-Average Interest Rate	6.40%	[1]	'
Face value of debt	250,000,000		'
Debt Instrument, Interest Rate, Stated Percentage	6.40%		'
Senior Notes [Member] | 4.20% Notes Due 2042 [Member]	'		'
Debt Instrument [Line Items]	'		'
Total debt	248,370,000		248,349,000
Weighted-Average Interest Rate	4.20%	[1]	'
Face value of debt	$250,000,000		'
Debt Instrument, Interest Rate, Stated Percentage	4.20%		'
[1]	Weighted-average interest rate includes the impact of interest rate contracts, the amortization/accretion of discounts and premiums and the amortization/accretion of gains and losses realized on historical cash flow and fair value hedges on interest expense.

Debt_Narrative_Details

Debt (Narrative) (Details) (USD $)	9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
Debt Instrument [Line Items]	'	'
Face value of debt	$2,400,000,000	$2,400,000,000
Long-term Debt	2,486,715,000	2,393,408,000
Revolving Credit Facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Borrowing capacity	800,000,000	'
Unused commitment fee	0.20%	'
Long-term Debt	98,400,000	0
Obligation for letters of credit	5,600,000	'
Revolving Credit Facility [Member] | Minimum [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt Instrument, Basis Spread on Variable Rate	0.88%	'
Unused commitment fee	0.13%	'
Revolving Credit Facility [Member] | Maximum [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt Instrument, Basis Spread on Variable Rate	1.75%	'
Unused commitment fee	0.30%	'
6.45% Notes Due 2014 [Member] | Senior Notes [Member]	'	'
Debt Instrument [Line Items]	'	'
Face value of debt	250,000,000	'
Debt Instrument, Interest Rate, Stated Percentage	6.45%	'
Long-term Debt	$249,954,000	$249,905,000

Derivative_Financial_Instrumen2

Derivative Financial Instruments (Narrative) (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Oct. 03, 2013

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Swap [Member]

NYMEX Commodity Contracts [Member]

NYMEX Commodity Contracts [Member]

NYMEX Commodity Contracts [Member]

NYMEX Commodity Contracts [Member]

NYMEX Commodity Contracts [Member]

NYMEX Commodity Contracts [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Subsequent Event [Member]

bbl

bbl

Tank Bottom Inventory [Member]

Other Current Assets [Member]

Interest Rate Contract [Member]

NYMEX Commodity Contracts [Member]

NYMEX Commodity Contracts [Member]

Interest Rate Contract [Member]

Other Current Liabilities [Member]

Other Current Liabilities [Member]

Other Current Liabilities [Member]

Derivative [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Notional Amount

'

'

'

'

'

$150,000,000

'

$150,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Liability, Fair Value, Gross Liability

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

36,000

36,000

0

207,000

'

Net gain (loss) on cash flow hedges(1)

-36,000

[1]

9,666,000

[1]

-4,596,000

[1]

12,341,000

[1]

'

-36,000

10,126,000

-36,000

11,134,000

11,000,000

0

-460,000

-4,560,000

1,207,000

'

'

'

'

'

'

-200,000

Energy commodity derivatives deposits

10,294,000

'

10,294,000

'

18,304,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months

'

'

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Barrels of crude oil designated as fair value hedges

'

'

'

'

'

'

'

'

'

'

700,000

'

700,000

'

'

'

'

'

'

'

'

Unrealized Gain Loss on Hedged Item in Fair Value Hedge Offset Amount

'

'

'

'

'

'

'

'

'

'

'

'

($10,200,000)

'

($10,200,000)

($100,000)

'

'

'

'

'

[1]

See Note 8–Derivative Financial Instruments for additional information on unrealized gains and losses on cash flow hedges recognized in accumulated other comprehensive loss.

Derivative_Financial_Instrumen3

Derivative Financial Instruments (Schedule Of Forward Purchase And Sales Contracts) (Details) (Forward Contracts [Member], USD $)	Sep. 30, 2013
In Millions, unless otherwise specified	bbl
Forward Contracts [Member]	'
Derivative [Line Items]	'
Forward purchase contracts, Amount	$158.80
Forward purchase contracts, Barrels	2,600,000
Forward sale contracts, Amount	$44.40
Forward sale contracts, Barrels	400,000

Derivative_Financial_Instrumen4

Derivative Financial Instruments (Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements) (Details)	Sep. 30, 2013
	bbl
Fair Value Hedging [Member]	'
Derivative [Line Items]	'
Barrels hedged	700,000
Economic Hedges [Member]	'
Derivative [Line Items]	'
Barrels hedged	3,200,000
Economic Hedges Futures [Member]	'
Derivative [Line Items]	'
Barrels hedged	400,000

Derivative_Financial_Instrumen5

Derivative Financial Instruments Schedule of Derivative Offset Amounts (Details) (Exchange Traded [Member], USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Exchange Traded [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$9,573	$2,050
Derivative Liability, Fair Value, Gross Liability	-166	-9,388
Derivative Liability Amount Not Offset	'	-7,338
Derivative Asset Amount Not Offset	9,407	'
Derivative Liability, Fair Value of Collateral	10,294	18,304
Margin Deposit Net of Commodity Contract	'	10,966
Excess Margin Deposit	$19,701	'

Derivative_Financial_Instrumen6

Derivative Financial Instruments (Derivative Gains Included In Accumulated Other Comprehensive Loss (AOCL) (Details) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Derivative Gains (Losses) Included in AOCL	'		'		'		'
Beginning balance	$13,892		$5,754		$14,126		$3,161
Net gain (loss) on cash flow hedges	-36	[1]	9,666	[1]	-4,596	[1]	12,341	[1]
Reclassification of net loss (gain) on cash flow hedges to income	-41	[2]	-1,425	[2]	4,285	[2]	-1,507	[2]
Ending balance	$13,815		$13,995		$13,815		$13,995
[1]	See Note 8–Derivative Financial Instruments for additional information on unrealized gains and losses on cash flow hedges recognized in accumulated other comprehensive loss.
[2]	See Note 8–Derivative Financial Instruments for additional information on amounts reclassified out of accumulated other comprehensive loss into income.

Derivative_Financial_Instrumen7

Derivative Financial Instruments (Derivatives And Hedging-Cash Flow Hedges) (Details) (USD $)	3 Months Ended				9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Net gain (loss) on cash flow hedges	($36)	[1]	$9,666	[1]	($4,596)	[1]	$12,341	[1]
Amount of gain (loss) reclassified from AOCL into Income	41	[2]	1,425	[2]	-4,285	[2]	1,507	[2]
Interest Rate Contract [Member]	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Net gain (loss) on cash flow hedges	-36		10,126		-36		11,134
Interest Rate Contract [Member] | Interest Expense [Member]	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of gain (loss) reclassified from AOCL into Income	41		41		123		123
NYMEX Commodity Contracts [Member]	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Net gain (loss) on cash flow hedges	0		-460		-4,560		1,207
NYMEX Commodity Contracts [Member] | Sales [Member]	'		'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'		'
Amount of gain (loss) reclassified from AOCL into Income	$0		$1,384		($4,408)		$1,384
[1]	See Note 8–Derivative Financial Instruments for additional information on unrealized gains and losses on cash flow hedges recognized in accumulated other comprehensive loss.
[2]	See Note 8–Derivative Financial Instruments for additional information on amounts reclassified out of accumulated other comprehensive loss into income.

Derivative_Financial_Instrumen8

Derivative Financial Instruments (Derivatives And Hedging-Overall-Subsequent Measurement) (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Gain (Loss) on Derivative, Net	($2,035)	($43,322)	$4,138	($38,148)
Not Designated as Hedging Instrument [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Gain (Loss) on Derivative, Net	-2,264	-49,432	9,018	-44,368
Not Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Sales [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Gain (Loss) on Derivative, Net	-2,035	-44,706	8,546	-39,532
Not Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Operating Expenses [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Gain (Loss) on Derivative, Net	-3,107	-7,733	-1,645	-3,216
Not Designated as Hedging Instrument [Member] | Butane Futures Agreements [Member] | Cost of Sales [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Gain (Loss) on Derivative, Net	$2,878	$3,007	$2,117	($1,620)

Derivative_Financial_Instrumen9

Derivative Financial Instruments (Derivatives And Hedging-Designated) (Details) (Designated as Hedging Instrument [Member], USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$1,180	'
Derivative Liability, Fair Value, Gross Liability	36	'
NYMEX Commodity Contracts [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	214	473
NYMEX Commodity Contracts [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	0	207
NYMEX Commodity Contracts [Member] | Other Noncurrent Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	966	'
NYMEX Commodity Contracts [Member] | Other Noncurrent Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	0	'
Interest Rate Contract [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	0	'
Interest Rate Contract [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	$36	'

Recovered_Sheet1

Derivative Financial Instruments (Derivatives And Hedging-Nondesignated) (Details) (Not Designated as Hedging Instrument [Member], USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$8,393	$1,577
Derivative Liability, Fair Value, Gross Liability	166	9,181
NYMEX Commodity Contracts [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	5,683	227
NYMEX Commodity Contracts [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	166	8,954
Butane Futures Agreements [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	2,710	1,350
Butane Futures Agreements [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	$0	$227

Commitments_And_Contingencies_

Commitments And Contingencies (Details) (USD $)	3 Months Ended		9 Months Ended			3 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Jun. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012
						TCEQ Fees	TCEQ Fees	Accounts Receivable [Member]	Accounts Receivable [Member]	Other Noncurrent Assets [Member]	Other Noncurrent Assets [Member]
Commitments And Contingencies [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Loss Contingency, Loss in Period	'	'	'	'	'	($10.60)	'	'	'	'	'
Loss contingency, estimate of possible loss	'	'	'	'	'	'	0.7	'	'	'	'
Liabilities recognized for estimated environmental costs	37.5	'	37.5	'	48.3	'	'	'	'	'	'
Estimated environmental liabilities, years	'	'	'10 years	'	'	'	'	'	'	'	'
Environmental expenses	2.9	10	-5.8	12.7	'	'	'	'	'	'	'
Receivables from insurance carriers related to environmental matters	$4.90	'	$4.90	'	$7.90	'	'	$1.80	$2.80	$3.10	$5.10

LongTerm_Incentive_Plan_Narrat

Long-Term Incentive Plan (Narrative) (Details)	Sep. 30, 2013
In Millions, unless otherwise specified
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Limited partners' capital account, units authorized for issuance	9.4
Limited partner unitholders, units remaining available	1.8

LongTerm_Incentive_Plan_Equity

Long-Term Incentive Plan (Equity-Based Incentive Compensation Expense) (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	$4,217	$5,547	$14,499	$12,555
2010 Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	0	3,265	194	6,620
2011 Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	1,818	1,250	7,144	3,132
2012 Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	1,288	840	3,976	2,268
2013 Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	986	'	2,832	'
Retention Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	125	192	353	535
G&A Expense [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	4,126	4,940	13,928	11,160
Operating Expenses [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	91	607	571	1,395
Equity Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	2,845	2,946	9,463	8,023
Equity Method [Member] | 2010 Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	0	1,489	121	3,666
Equity Method [Member] | 2011 Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	1,101	684	4,204	2,111
Equity Method [Member] | 2012 Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	856	581	2,563	1,711
Equity Method [Member] | 2013 Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	763	'	2,222	'
Equity Method [Member] | Retention Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	125	192	353	535
Liability Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	1,372	2,601	5,036	4,532
Liability Method [Member] | 2010 Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	0	1,776	73	2,954
Liability Method [Member] | 2011 Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	717	566	2,940	1,021
Liability Method [Member] | 2012 Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	432	259	1,413	557
Liability Method [Member] | 2013 Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	223	'	610	'
Liability Method [Member] | Retention Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	$0	$0	$0	$0

Distributions_Schedule_Of_Dist

Distributions (Schedule Of Distributions) (Details) (USD $)	0 Months Ended							9 Months Ended		12 Months Ended	0 Months Ended	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Aug. 14, 2013	15-May-13	Feb. 14, 2013	Nov. 14, 2012	Aug. 14, 2012	15-May-12	Feb. 14, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Nov. 14, 2013	Dec. 31, 2013
											Scenario, Forecast	Scenario, Forecast
Per Unit Cash Distribution Amount	$0.53	$0.51	$0.50	$0.49	$0.47	$0.42	$0.41	$1.54	$1.30	$1.78	$0.56	$2.10
Total Cash Distribution to Limited Partners	$120,707	$115,040	$113,340	$109,707	$106,597	$95,004	$92,177	$349,087	$293,778	$403,485	$126,374	$475,461

Fair_Value_Schedule_Of_Carryin

Fair Value (Schedule Of Carrying Amounts And Fair Values Of Financial Assets/Liabilities) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Debt	'	($2,721,985)
Quoted Prices in Active Markets for Identical Assets (Level 1) [Member] | NYMEX Commodity Contracts [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Derivative asset	9,407	'
Derivative Liability	'	-7,338
Significant Other Observable Inputs (Level 2) [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Debt	-2,676,025	'
Significant Other Observable Inputs (Level 2) [Member] | Interest Rate Contract [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Derivative Liability	-36	'
Significant Unobservable Inputs (Level 3) [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Long-term receivables	3,097	5,108
Carrying Amount [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Long-term receivables	3,140	5,135
Debt	-2,486,715	-2,393,408
Carrying Amount [Member] | NYMEX Commodity Contracts [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Derivative asset	9,407	'
Derivative Liability	'	-7,338
Carrying Amount [Member] | Interest Rate Contract [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Derivative Liability	-36	'
Fair Value [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Long-term receivables	3,097	5,108
Debt	-2,676,025	-2,721,985
Fair Value [Member] | NYMEX Commodity Contracts [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Derivative asset	9,407	'
Derivative Liability	'	-7,338
Fair Value [Member] | Interest Rate Contract [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Derivative Liability	($36)	'

Related_Party_Transactions_Det

Related Party Transactions (Details) (Targa Resource Partners, L.P., 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
Targa Resource Partners, L.P.	'	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'	'
Related Party Transaction, Amounts of Transaction	$1	$0.10	$15.60	$12.50	'
Accounts Payable, Related Parties	$0	'	$0	'	$0.10

Subsequent_Events_Details

Subsequent Events (Details) (USD $)

0 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

Aug. 14, 2013

15-May-13

Feb. 14, 2013

Nov. 14, 2012

Aug. 14, 2012

15-May-12

Feb. 14, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Nov. 14, 2013

Dec. 31, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Nov. 14, 2013

Oct. 03, 2013

Oct. 10, 2013

Scenario, Forecast

Scenario, Forecast

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Scenario, Forecast

Interest Rate Contract [Member]

Senior Notes [Member]

Five Point One Five Percentage Notes Due Two Thousand Forty Three [Member]

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt

'

'

'

'

'

'

'

$2,486,715,000

'

$2,486,715,000

'

$2,393,408,000

'

'

'

'

'

'

'

'

$300,000,000

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.15%

Notes At Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

99.56%

Net Proceeds From Debt Offering After Underwriting Discounts and Offering Expense

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

295,600,000

Derivative, Notional Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

150,000,000

'

150,000,000

'

'

'

'

Net gain (loss) on cash flow hedges(1)

'

'

'

'

'

'

'

-36,000

[1]

9,666,000

[1]

-4,596,000

[1]

12,341,000

[1]

'

'

'

-36,000

10,126,000

-36,000

11,134,000

'

-200,000

'

Cash distribution per unit

$0.53

$0.51

$0.50

$0.49

$0.47

$0.42

$0.41

$1.54

$1.30

$1.54

$1.30

$1.78

$0.56

$2.10

'

'

'

'

$0.56

'

'

Total cash distributions

$120,707,000

$115,040,000

$113,340,000

$109,707,000

$106,597,000

$95,004,000

$92,177,000

'

'

$349,087,000

$293,778,000

$403,485,000

$126,374,000

$475,461,000

'

'

'

'

$126,374,000

'

'

[1]

See Note 8–Derivative Financial Instruments for additional information on unrealized gains and losses on cash flow hedges recognized in accumulated other comprehensive loss.