Magellan Midstream Partners (MMP) 10-Q 5 Aug 14 2014 Q2 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	6 Months Ended
	Jun. 30, 2014	Aug. 04, 2014
Document And Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Jun-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'
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	'	227,068,257

Consolidated_Statements_Of_Inc

Consolidated Statements Of Income (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Transportation and terminals revenue	$353,568	$282,462	$671,205	$509,733
Product sales revenue	137,657	157,922	433,720	359,633
Affiliate management fee revenue	5,221	3,528	10,127	6,967
Total revenue	496,446	443,912	1,115,052	876,333
Costs and expenses:	'	'	'	'
Operating	124,874	77,415	198,371	142,596
Cost of product sales	109,103	115,328	307,143	275,726
Depreciation, amortization and impairments	46,897	34,186	84,408	70,518
General and administrative	39,309	33,262	74,244	63,318
Total costs and expenses	320,183	260,191	664,166	552,158
Earnings of non-controlled entities	1,955	736	2,421	2,787
Operating profit	178,218	184,457	453,307	326,962
Interest expense	37,265	31,720	73,681	63,443
Interest income	-406	-13	-797	-35
Interest capitalized	-6,843	-3,243	-12,153	-6,694
Debt placement fee amortization expense	602	540	1,201	1,080
Income before provision for income taxes	147,600	155,453	391,375	269,168
Provision for income taxes	1,340	1,813	2,561	2,561
Net income	$146,260	$153,640	$388,814	$266,607
Basic and diluted net income per limited partner unit (in dollars per unit)	$0.64	$0.68	$1.71	$1.18
Weighted average number of limited partner units outstanding used for basic and diluted net income per unit calculation (in units)	227,288	226,864	227,215	226,785

Consolidated_Statements_Of_Com

Consolidated Statements Of Comprehensive Income (USD $)	3 Months Ended				6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013
Net income	$146,260		$153,640		$388,814		$266,607
Other comprehensive income:	'		'		'		'
Net loss on cash flow hedges(1)	0	[1]	0	[1]	-3,613	[1]	-4,560	[1]
Reclassification of net loss (gain) on cash flow hedges to income(1)	-153	[1]	-41	[1]	-179	[1]	4,326	[1]
Amortization of prior service credit(2)	-928	[2]	-851	[2]	-1,823	[2]	-1,702	[2]
Amortization of actuarial loss(2)	1,192	[2]	1,354	[2]	2,016	[2]	2,684	[2]
Settlement cost(2)	1,569	[2]	0	[2]	1,569	[2]	0	[2]
Total other comprehensive income (loss)	1,680		462		-2,030		748
Comprehensive income	$147,940		$154,102		$386,784		$267,355
[1]	See Note 9–Derivative Financial Instruments for details of the amount of gain/loss recognized in accumulated other comprehensive loss ("AOCL") on derivatives and the amount of gain/loss reclassified from AOCL into income.
[2]	These AOCL components are included in the computation of net periodic pension cost (see Note 7–Employee Benefit Plans).

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
ASSETS	'	'
Cash and cash equivalents	$731	$25,235
Trade accounts receivable	91,691	116,295
Other accounts receivable	11,404	6,462
Inventory	188,942	187,224
Energy commodity derivatives deposits	29,070	14,782
Other current assets	36,620	46,735
Total current assets	358,458	396,733
Property, plant and equipment	5,089,277	4,986,750
Less: Accumulated depreciation	1,146,550	1,070,492
Net property, plant and equipment	3,942,727	3,916,258
Investments in non-controlled entities	645,090	360,852
Long-term receivables	30,028	2,730
Goodwill	53,260	53,260
Other intangibles (less accumulated amortization of $8,809 and $10,168 at December 31, 2013 and June 30, 2014, respectively)	5,931	7,290
Debt placement costs (less accumulated amortization of $9,113 and $7,820 at December 31, 2013 and June 30, 2014, respectively)	19,191	17,505
Tank bottom inventory	67,668	61,915
Other noncurrent assets	1,906	4,269
Total assets	5,124,259	4,820,812
LIABILITIES AND PARTNERS' CAPITAL	'	'
Accounts payable	72,050	76,326
Accrued payroll and benefits	30,809	42,243
Accrued interest payable	45,973	44,935
Accrued taxes other than income	34,895	38,574
Environmental liabilities	12,747	12,147
Deferred revenue	69,338	63,164
Accrued product purchases	37,755	63,033
Energy commodity derivatives contracts, net	11,140	6,737
Current portion of long-term debt	0	249,971
Other current liabilities	31,919	41,146
Total current liabilities	346,626	638,276
Long-term debt	2,910,496	2,435,316
Long-term pension and benefits	54,046	51,637
Other noncurrent liabilities	28,167	21,802
Environmental liabilities	21,919	26,339
Commitments and contingencies	'	'
Partners’ capital:	'	'
Limited partner unitholders (226,679 units and 227,068 units outstanding at December 31, 2013 and June 30, 2014, respectively)	1,784,539	1,666,946
Accumulated other comprehensive loss	-21,534	-19,504
Total partners’ capital	1,763,005	1,647,442
Total liabilities and partners' capital	$5,124,259	$4,820,812

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, except Share data, unless otherwise specified
Other intangibles, accumulated amortization	$10,168	$8,809
Debt placement costs, accumulated amortization	$7,820	$9,113
Limited partner unitholders, units outstanding	227,068,257	226,679,438

Consolidated_Statements_Of_Cas

Consolidated Statements Of Cash Flows (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Operating Activities:	'	'
Net income	$388,814	$266,607
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation, amortization and impairments	84,408	70,518
Debt placement fee amortization expense	1,201	1,080
Loss on sale and retirement of assets	3,310	2,298
Earnings of non-controlled entities	-2,421	-2,787
Distributions from investments in non-controlled entities	1,713	1,302
Equity-based incentive compensation expense	12,753	10,282
Changes in employee benefit plan assets and benefit obligations	1,762	982
Changes in operating assets and liabilities:	'	'
Trade accounts receivable and other accounts receivable	25,486	8,167
Inventory	-1,718	13,984
Energy commodity derivatives contracts, net of derivatives deposits	-4,133	-4,628
Accounts payable	486	-322
Accrued payroll and benefits	-11,434	-4,429
Accrued interest payable	1,038	-633
Accrued taxes other than income	-3,679	-2,737
Accrued product purchases	-25,278	-22,885
Deferred revenue	6,174	7,815
Current and noncurrent environmental liabilities	-3,820	-12,850
Other current and noncurrent assets and liabilities	2,694	7,909
Net cash provided by operating activities	477,356	339,673
Investing Activities:	'	'
Additions to property, plant and equipment	-149,138	-181,165
Proceeds from sale and disposition of assets	107	2,305
Decrease in accounts payable related to capital expenditures	-4,112	-30,044
Investments in non-controlled entities	-285,945	-99,667
Distributions in excess of earnings of non-controlled entities	1,765	750
Net cash used by investing activities	-437,323	-307,821
Financing Activities:	'	'
Distributions paid	-271,914	-228,380
Net commercial paper borrowings	220,977	0
Borrowings under long-term notes	257,713	0
Payments on notes	-250,000	0
Debt placement costs	-2,887	0
Net payment on financial derivatives	-3,613	0
Settlement of tax withholdings on long-term incentive compensation	-14,813	-12,259
Net cash used by financing activities	-64,537	-240,639
Change in cash and cash equivalents	-24,504	-208,787
Cash and cash equivalents at beginning of period	25,235	328,278
Cash and cash equivalents at end of period	731	119,491
Supplemental non-cash investing and financing activities:	'	'
Issuance of limited partner units in settlement of equity-based incentive plan awards	$7,315	$6,404

Organization_Description_of_Bu

Organization, Description of Business And Basis Of Presentation	6 Months Ended
	Jun. 30, 2014
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.
	Description of Business
	We are principally engaged in the transportation, storage and distribution of refined petroleum products and crude oil.  As of June 30, 2014, our asset portfolio including the assets of our joint ventures consisted of:
	•	our refined products segment, including our 9,500-mile refined products pipeline system with 54 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 1,100 miles of active crude oil pipelines and storage facilities with an aggregate storage capacity of approximately 18 million barrels, of which 12 million barrels is used for leased storage; and
	•	our marine storage segment, consisting of five marine terminals located along coastal waterways with an aggregate storage capacity of approximately 27 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, oxygenates and natural gasoline;
	•	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, 2013 which is derived from our audited financial statements, include all normal and recurring adjustments necessary to present fairly our financial position as of June 30, 2014, the results of operations for the three and six months ended June 30, 2013 and 2014 and cash flows for the six months ended June 30, 2013 and 2014. The results of operations for the six months ended June 30, 2014 are not necessarily indicative of the results to be expected for the full year ending December 31, 2014.
	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, 2013.

Product_Sales_Revenues

Product Sales Revenues	6 Months Ended
	Jun. 30, 2014
Product Sales Revenue [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 in which 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 9 – Derivative Financial Instruments for further disclosures regarding our NYMEX contracts.
	For the three and six months ended June 30, 2013 and 2014, product sales revenue included the following (in thousands):
		Three Months Ended					Six Months Ended
		June 30,					June 30,
		2013		2014			2013			2014
	Physical sale of petroleum products	$	145,580	$	154,310		$	353,460		$	447,550
	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)	12,342		(16,666		)	6,184			(13,843		)
	Other	—		13			(11		)	13
	Total NYMEX contract adjustments	12,342		(16,653		)	6,173			(13,830		)
	Total product sales revenue	$	157,922	$	137,657		$	359,633		$	433,720
	(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	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Segment Disclosures	'
	Segment Disclosures
	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, cost of product sales 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 consider when evaluating the core profitability of our separate operating segments.
		Three Months Ended June 30, 2013
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	202,397	$	41,158		$	38,907		$	—		$	282,462
	Product sales revenue	156,321		—			1,601			—			157,922
	Affiliate management fee revenue	—		3,239			289			—			3,528
	Total revenue	358,718		44,397			40,797			—			443,912
	Operating expenses	66,456		4,027			7,694			(762		)	77,415
	Cost of product sales	114,460		—			868			—			115,328
	Earnings of non-controlled entities	—		(110		)	(626		)	—			(736		)
	Operating margin	177,802		40,480			32,861			762			251,905
	Depreciation, amortization and impairments	21,224		5,104			7,096			762			34,186
	G&A expenses	23,292		4,915			5,055			—			33,262
	Operating profit	$	133,286	$	30,461		$	20,710		$	—		$	184,457
		Three Months Ended June 30, 2014
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	232,489	$	79,556		$	41,523		$	—		$	353,568
	Product sales revenue	136,334		—			1,323			—			137,657
	Affiliate management fee revenue	—		4,902			319			—			5,221
	Total revenue	368,823		84,458			43,165			—			496,446
	Operating expenses	97,302		11,867			16,544			(839		)	124,874
	Cost of product sales	108,817		—			286			—			109,103
	Earnings of non-controlled entities	—		(888		)	(1,067		)	—			(1,955		)
	Operating margin	162,704		73,479			27,402			839			264,424
	Depreciation, amortization and impairments	32,083		6,725			7,250			839			46,897
	G&A expenses	25,374		7,697			6,238			—			39,309
	Operating profit	$	105,247	$	59,057		$	13,914		$	—		$	178,218
		Six Months Ended June 30, 2013
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	367,756	$	64,386		$	77,591		$	—		$	509,733
	Product sales revenue	355,736		—			3,897			—			359,633
	Affiliate management fee revenue	—		6,398			569			—			6,967
	Total revenue	723,492		70,784			82,057			—			876,333
	Operating expenses	112,737		9,134			22,247			(1,522		)	142,596
	Cost of product sales	272,758		—			2,968			—			275,726
	Earnings of non-controlled entities	—		(1,485		)	(1,302		)	—			(2,787		)
	Operating margin	337,997		63,135			58,144			1,522			460,798
	Depreciation, amortization and impairments	42,577		12,573			13,846			1,522			70,518
	G&A expenses	44,494		9,042			9,782			—			63,318
	Operating profit	$	250,926	$	41,520		$	34,516		$	—		$	326,962
		Six Months Ended June 30, 2014
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	442,725	$	147,459		$	81,021		$	—		$	671,205
	Product sales revenue	430,044		—			3,676			—			433,720
	Affiliate management fee revenue	—		9,497			630			—			10,127
	Total revenue	872,769		156,956			85,327			—			1,115,052
	Operating expenses	148,459		20,925			30,630			(1,643		)	198,371
	Cost of product sales	306,573		—			570			—			307,143
	Earnings of non-controlled entities	—		(708		)	(1,713		)	—			(2,421		)
	Operating margin	417,737		136,739			55,840			1,643			611,959
	Depreciation, amortization and impairments	55,255		13,188			14,322			1,643			84,408
	G&A expenses	48,393		13,691			12,160			—			74,244
	Operating profit	$	314,089	$	109,860		$	29,358		$	—		$	453,307

Investments_in_NonControlled_E

Investments in Non-Controlled Entities (Notes)	6 Months Ended
	Jun. 30, 2014
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 approximately one million barrels of refined products storage at our Galena Park, Texas terminal. The storage capacity owned by this joint venture is leased to an affiliate of Texas Frontera under a long-term lease agreement. 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 in Oklahoma and Kansas 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 transports condensate from the Eagle Ford shale formation in South Texas via a 195-mile pipeline to our terminal in Corpus Christi, Texas. Double Eagle is operated by an affiliate of the other 50% member of Double Eagle. In addition to our equity ownership in Double Eagle, we receive throughput revenue from Double Eagle that is included in our transportation and terminals revenue on our consolidated statements of income. For the three and six months ended June 30, 2014, we received throughput revenue of $0.8 million and $1.3 million, respectively. We recorded a $0.2 million and $0.3 million trade accounts receivable from Double Eagle at December 31, 2013 and June 30, 2014, respectively.
	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 the third quarter of 2014. We receive construction management fees from BridgeTex, which we report as affiliate management fee revenue on our consolidated statements of income.
	We received $4.8 million from BridgeTex in 2013 as a deposit for the purchase of emission reduction credits, which were necessary for the operation of BridgeTex's tanks in East Houston, Texas. In second quarter 2014, we transferred these emission reduction credits to BridgeTex and recorded $2.4 million as a reduction of operating expense. We recorded the remaining $2.4 million as an adjustment to our investment in BridgeTex, which will be amortized to earnings of non-controlled entities over the weighted average depreciable lives of the BridgeTex assets.
	Also during 2013, we received $1.4 million from BridgeTex for the purchase of easement rights from us, of which $0.7 million was recorded as a reduction of operating expense and $0.7 million was recorded as an adjustment to our investment in BridgeTex, which will be amortized to earnings of non-controlled entities over the weighted average depreciable lives of the BridgeTex assets.
	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 as earnings of non-controlled entities.
	A summary of our investments in non-controlled entities follows (in thousands):
		BridgeTex			All Others			Consolidated
	Investment at December 31, 2013	$	246,875		$	113,977		$	360,852
	Additional investment	281,803			4,142			285,945
	Other adjustment to investment	—			(650		)	(650		)
	Earnings (losses) of non-controlled entities:
	Proportionate share of earnings (loss)	(140		)	2,936			2,796
	Amortization of excess investment and capitalized interest	—			(375		)	(375		)
	Earnings (losses) of non-controlled entities	(140		)	2,561			2,421
	Less:
	Distributions of earnings from investments in non-controlled entities	—			1,713			1,713
	Distributions in excess of earnings of non-controlled entities	—			1,765			1,765
	Investment at June 30, 2014	$	528,538		$	116,552		$	645,090
	Summarized financial information of our non-controlled entities as of and for the six months ended June 30, 2014 follows (in thousands):
		BridgeTex			All Others			Consolidated
	Current assets	$	60,296		$	20,128		$	80,424
	Noncurrent assets	907,337			184,876			1,092,213
	Total assets	$	967,633		$	205,004		$	1,172,637
	Current liabilities	107,742			6,410			114,152
	Noncurrent liabilities	—			98			98
	Total liabilities	$	107,742		$	6,508		$	114,250
	Equity	$	859,891		$	198,496		$	1,058,387
	Revenue	$	—		$	18,464		$	18,464
	Net income (loss)	$	(280	)	$	5,871		$	5,591

Business_Combinations_Business

Business Combinations Business Combinations (Notes)	6 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Business Combination Disclosure [Text Block]	'
	Business Combinations
	During 2013, we acquired certain refined petroleum products pipelines and terminals from Plains All American Pipeline, L.P. We have accounted for this acquisition as a business combination under the acquisition method of accounting in accordance with Accounting Standards Codification ("ASC") 805, Business Combinations. The acquisition was completed in two parts, as follows:
	•	New Mexico/Texas System. In July 2013, we acquired approximately 250 miles of common carrier pipeline that transports refined petroleum products from El Paso, Texas north to Albuquerque, New Mexico and transports products south to the U.S.–Mexico border for delivery within Mexico via a third-party pipeline for $57.0 million. We funded this acquisition with cash on hand.
	•	Rocky Mountain System. In November 2013, we acquired approximately 550 miles of common carrier pipeline that distributes refined petroleum products in Colorado, South Dakota and Wyoming for $135.0 million. The system includes four terminals with nearly 1.7 million barrels of storage. We funded this acquisition primarily with proceeds from our debt offering in October 2013.
	We completed our valuation process of this 2013 business combination during the current quarter, and there were no changes to our preliminary purchase price allocation amounts since December 31, 2013 (as reported in our 2013 annual report on Form 10-K).

Inventory

Inventory	6 Months Ended
	Jun. 30, 2014
Inventory Disclosure [Abstract]	'
Inventory	'
	Inventory
	Inventory at December 31, 2013 and June 30, 2014 was as follows (in thousands):
		December 31, 2013		June 30,
				2014
	Refined products	$	77,144	$	35,331
	Liquefied petroleum gases	23,476		57,103
	Transmix	72,156		80,619
	Crude oil	7,188		10,302
	Additives	7,260		5,587
	Total inventory	$	187,224	$	188,942

Employee_Benefit_Plans

Employee Benefit Plans	6 Months Ended
	Jun. 30, 2014
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 six months ended June 30, 2013 and 2014 (in thousands):
		Three Months Ended						Three Months Ended
		30-Jun-13						June 30, 2014
		Pension			Other  Post-			Pension			Other  Post-
		Benefits			Retirement			Benefits			Retirement
					Benefits						Benefits
	Components of net periodic benefit costs:
	Service cost	$	3,374		$	67		$	3,352		$	47
	Interest cost	1,334			91			2,030			139
	Expected return on plan assets	(1,645		)	—			(1,490		)	—
	Amortization of prior service cost (credit)(1)	77			(928		)	—			(928		)
	Amortization of actuarial loss(1)	1,145			209			930			262
	Settlement cost(1)	—			—			1,569			—
	Net periodic benefit cost (credit)	$	4,285		$	(561	)	$	6,391		$	(480	)
		Six Months Ended						Six Months Ended
		30-Jun-13						June 30, 2014
		Pension			Other  Post-			Pension			Other  Post-
		Benefits			Retirement			Benefits			Retirement
					Benefits						Benefits
	Components of net periodic benefit costs:
	Service cost	$	6,950		$	144		$	6,704		$	114
	Interest cost	2,684			206			3,689			253
	Expected return on plan assets	(3,115		)	—			(3,187		)	—
	Amortization of prior service cost (credit)(1)	154			(1,856		)	33			(1,856		)
	Amortization of actuarial loss(1)	2,167			517			1,559			457
	Settlement cost(1)	—			—			1,569			—
	Net periodic benefit cost (credit)	$	8,840		$	(989	)	$	10,367		$	(1,032	)
	(1) These amounts are included in our Consolidated Statements of Comprehensive Income and Consolidated Statements of Cash Flows as changes in employee benefit plan assets and benefit obligations.
	Contributions estimated to be paid into the plans in 2014 are $21.1 million and $0.7 million for the pension and postretirement benefit plans, respectively.

Debt

Debt	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Debt	'
	Debt
	Consolidated debt at December 31, 2013 and June 30, 2014 was as follows (in thousands, except as otherwise noted):
			December 31, 2013		June 30,		Weighted-Average
					2014		Interest Rate for Six Months Ending
							June 30, 2014 (1)
	Commercial paper(2)		$	—	$	220,977	0.30%
	Revolving credit facility(2)		—		—		1.30%
	$250.0 million of 6.45% Notes due 2014(2)		249,971		—		6.30%
	$250.0 million of 5.65% Notes due 2016		251,183		250,970		5.70%
	$250.0 million of 6.40% Notes due 2018		259,346		258,313		5.40%
	$550.0 million of 6.55% Notes due 2019		571,515		569,704		5.70%
	$550.0 million of 4.25% Notes due 2021		557,213		556,763		4.00%
	$250.0 million of 6.40% Notes due 2037		248,998		249,007		6.40%
	$250.0 million of 4.20% Notes due 2042		248,377		248,391		4.20%
	$550.0 million of 5.15% Notes due 2043		298,684		556,371		5.10%
	Total debt		$	2,685,287	$	2,910,496	5.10%
	-1	Weighted-average interest rate includes the amortization/accretion of discounts, premiums and gains/losses realized on historical cash flow and fair value hedges in interest expense.
	-2	These borrowings were outstanding for only a portion of the six month period ending June 30, 2014. The weighted-average interest rate for these borrowings was calculated based on the number of days the borrowings were outstanding during the noted period.
	All of the instruments detailed in the table above are senior indebtedness.
	The face value of our debt at December 31, 2013 and June 30, 2014 was $2.7 billion and $2.9 billion, respectively. 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.
	2014 Debt Offering
	In March 2014, we issued $250.0 million of our 5.15% notes due October 15, 2043 in an underwritten public offering. The notes were issued at 103.1% of par. We used the net proceeds from this offering of approximately $255.0 million, after underwriting discounts and offering expenses of $2.7 million, to repay borrowings outstanding under our revolving credit facility and for general partnership purposes, including expansion capital.
	Other Debt
	Revolving Credit Facility. The total borrowing capacity under our revolving credit facility, which matures in November 2018, is $1.0 billion. Borrowings outstanding under the facility are classified as long-term debt on our consolidated balance sheets. Borrowings under the facility are unsecured and bear interest at LIBOR plus a spread ranging from 1.0% to 1.75% based on our credit ratings. Additionally, an unused commitment fee is assessed at a rate from 0.10% to 0.28%, depending on our credit ratings. The unused commitment fee was 0.125% at June 30, 2014. Borrowings under this facility may be used for general partnership purposes, including capital expenditures. As of June 30, 2014, there were no 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.
	Commercial Paper Program. In April 2014, we initiated a commercial paper program. The maturities of the commercial paper notes vary, but may not exceed 397 days from the date of issuance. The commercial paper notes are sold under customary terms in the commercial paper market and are issued at a discount from par, or alternatively, are sold at par and bear varying interest rates on a fixed or floating basis. The commercial paper we can issue is limited by the amounts available under our revolving credit facility up to an aggregate principal amount of $1.0 billion. We have the ability and intent to refinance all of our commercial paper obligations on a long-term basis; therefore, we have elected to classify our commercial paper borrowings outstanding as long-term debt on our consolidated balance sheets.
	In second quarter 2014, proceeds from commercial paper borrowings were used in part to repay our 6.45% senior notes due June 1, 2014.

Derivative_Financial_Instrumen

Derivative Financial Instruments	6 Months Ended
	Jun. 30, 2014
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 first quarter 2014, we entered into $200.0 million of interest rate swap agreements to hedge against the variability of future interest payments on an anticipated debt issuance. We accounted for these agreements as cash flow hedges. When we issued $250.0 million of 5.15% notes due 2043 later in the first quarter of 2014, we settled the associated interest rate swap agreements for a loss of $3.6 million. The loss was recorded to other comprehensive income and is being recognized into earnings as an adjustment to our periodic interest expense accruals over the life of the associated notes. This loss was also reported as net payment on financial derivatives in the financing activities of our consolidated statements of cash flows.
	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 as a deferred cash flow hedging gain. The purpose of these swaps was to hedge against the variability of future interest payments on the refinancing of our debt that matured in June 2014. We recognized ineffectiveness of $0.2 million in earnings on this deferred hedging gain in second quarter 2014 due to timing of our debt refinancing.
	Commodity Derivatives
	Hedging Strategies
	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 June 30, 2014, we had commitments under these forward purchase and sale contracts as follows (in millions):
		Notional Value				Barrels
	Forward purchase contracts	$	137.7			2.4
	Forward sale contracts	$	8.8			0.1
	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 is 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 is 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 under ASC 815, Derivatives and Hedging.		Changes in the value of these agreements are recognized currently in earnings.
	Period changes in the fair value of NYMEX agreements that are accounted for as economic hedges, other than those economic hedges of our pipeline product overages (see discussion of these below), the effective portion of changes in the fair value of cash flow hedges that are reclassified from accumulated other comprehensive income/loss and any ineffectiveness associated with hedges related to our commodity activities are recognized currently in earnings as adjustments to product sales.
	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. Period changes in the fair value of these agreements are recognized currently in earnings as adjustments to cost of product sales.
	Additionally, we currently hold petroleum product inventories that we obtained from overages on our pipeline systems. We use NYMEX contracts that are not designated as hedges for accounting purposes to help manage price changes related to these overage inventory barrels. Period 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 June 30, 2014 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 July 2014 and November 2016
	NYMEX - Economic Hedges		3.4 million barrels of refined products and crude oil		Between July 2014 and April 2015
	Butane Futures Agreements - Economic Hedges		0.9 million barrels of butane		Between September 2014 and April 2015
	Energy Commodity Derivatives Contracts and Deposits Offsets
	At June 30, 2014, we had made margin deposits of $29.1 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, 2013 and June 30, 2014 (in thousands):
			31-Dec-13
	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(1)				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet				Net Asset Amount
	Energy commodity derivatives		$	(7,167	)		$	2,665			$	(4,502	)		$	14,782			$	10,280
			30-Jun-14
	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(2)				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet				Net Asset Amount
	Energy commodity derivatives		$	(16,577	)		$	1,920			$	(14,657	)		$	29,070			$	14,413
	(1) Net amount includes energy commodity derivative contracts classified as current liabilities, net, of $6,737 and noncurrent assets of $2,235.
	(2) Net amount includes energy commodity derivative contracts classified as current liabilities, net, of $11,140 and noncurrent liabilities of $3,517.
	Impact of Derivatives on Income Statement, Balance Sheet, Cash Flows and AOCL
	The changes in derivative activity included in AOCL for the three and six months ended June 30, 2013 and 2014 were as follows (in thousands):
		Three Months Ended June 30,								Six Months Ended June 30,
	Derivative Gains (Losses) Included in AOCL	2013				2014				2013				2014
	Beginning balance	$	13,933			$	9,988			$	14,126			$	13,627
	Net loss on cash flow hedges	—				—				(4,560		)		(3,613		)
	Reclassification of net loss (gain) on cash flow hedges to income	(41		)		(153		)		4,326				(179		)
	Ending balance	$	13,892			$	9,835			$	13,892			$	9,835
	During 2014, 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 inventories. Because there was no ineffectiveness recognized on these hedges, the cumulative losses of $14.9 million from the agreements as of June 30, 2014 were fully offset by a cumulative increase of $14.7 million to tank bottom inventory and a cumulative increase of $0.2 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 six months ended June 30, 2013 and 2014 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 June 30, 2013
			Amount of Gain Recognized in AOCL on Derivative						Location of Gain Reclassified from AOCL into  Income		Amount of Gain Reclassified from AOCL into Income
	Derivative Instrument										Effective Portion						Ineffective Portion
	Interest rate contracts			$	—				Interest expense			$	41					$	—
			Three Months Ended June 30, 2014
			Amount of Gain (Loss) Recognized in AOCL on Derivative						Location of Gain (Loss) Reclassified from AOCL into  Income		Amount of Gain (Loss) Reclassified from AOCL into Income
	Derivative Instrument										Effective Portion						Ineffective Portion
	Interest rate contracts			$	—				Interest expense			$	(30	)				$	183
			Six Months Ended June 30, 2013
			Amount of Gain (Loss) Recognized in AOCL on Derivative						Location of Gain (Loss) Reclassified from AOCL into  Income		Amount of Gain (Loss) Reclassified from AOCL into Income
	Derivative Instrument										Effective Portion						Ineffective Portion
	Interest rate contracts			$	—				Interest expense			$	82					$	—
	NYMEX commodity contracts			(4,560		)			Product sales revenue			(4,408		)				—
	Total cash flow hedges			$	(4,560	)			Total			$	(4,326	)				$	—
			Six Months Ended June 30, 2014
			Amount of Gain (Loss) Recognized in AOCL on Derivative						Location of Gain (Loss) Reclassified from AOCL into  Income		Amount of Gain (Loss) Reclassified from AOCL into Income
Derivative Instrument										Effective Portion						Ineffective Portion
Interest rate contracts			$	(3,613	)			Interest expense			$	(4	)				$	183
As of June 30, 2014, the net loss estimated to be classified to interest expense over the next twelve months from AOCL is approximately $0.3 million.
The following table provides a summary of the effect on our consolidated statements of income for the three months ended June 30, 2013 and 2014 of derivatives accounted for under ASC 815; Derivatives and Hedging—Overall, that were not designated as hedging instruments (in thousands):
				Amount of Gain (Loss) Recognized on Derivative
		Location of Gain (Loss)		Three Months Ended June 30,								Six Months Ended June 30,
Derivative Instrument		Recognized on Derivative		2013				2014				2013				2014
NYMEX commodity contracts		Product sales revenue		$	12,342			$	(16,653	)		$	10,581			$	(13,830	)
NYMEX commodity contracts		Operating expenses		3,348				(4,268		)		1,462				(3,903		)
Butane futures agreements		Cost of product sales		20				632				(761		)		776
		Total		$	15,710			$	(20,289	)		$	11,282			$	(16,957	)
The impact of the derivatives in the above table was reflected as cash from operations on our consolidated statements of cash flows.
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, 2013 and June 30, 2014 (in thousands):
		December 31, 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		$	—			Energy commodity derivatives contracts, net		$	146
NYMEX commodity contracts		Other noncurrent assets		2,235				Other noncurrent liabilities		—
		Total		$	2,235			Total		$	146
		June 30, 2014
		Asset Derivatives						Liability Derivatives
Derivative Instrument		Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
NYMEX commodity contracts		Energy commodity derivatives contracts, net		$	34			Energy commodity derivatives contracts, net		$	—
NYMEX commodity contracts		Other noncurrent assets		—				Other noncurrent liabilities		3,517
		Total		$	34			Total		$	3,517
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, 2013 and June 30, 2014 (in thousands):
		December 31, 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		$	48			Energy commodity derivatives contracts, net		$	7,021
Butane futures agreements		Energy commodity derivatives contracts, net		382				Energy commodity derivatives contracts, net		—
		Total		$	430			Total		$	7,021
		June 30, 2014
		Asset Derivatives						Liability Derivatives
Derivative Instrument		Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
NYMEX commodity contracts		Energy commodity derivatives contracts, net		$	1,184			Energy commodity derivatives contracts, net		$	12,971
Butane futures agreements		Energy commodity derivatives contracts, net		702				Energy commodity derivatives contracts, net		89
		Total		$	1,886			Total		$	13,060

Commitments_And_Contingencies

Commitments And Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	Environmental Liabilities
	Liabilities recognized for estimated environmental costs were $38.5 million and $34.7 million at December 31, 2013 and June 30, 2014, 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 six months ended June 30, 2013 were $(9.4) million and $(8.7) million, respectively, and both of these amounts include a $10.6 million favorable adjustment to a Clean Air Act – Section 185 liability in second quarter 2013. Environmental expenses for the three and six months ended June 30, 2014 were $0.1 million and $0.4 million, respectively.
	Environmental Receivables
	Receivables from insurance carriers and other third parties related to environmental matters at December 31, 2013 were $4.8 million, of which $2.1 million and $2.7 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 June 30, 2014 were $4.6 million, of which $2.1 million and $2.5 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheet.
	Other
	In January 2014, we placed into operation a 36-mile pipeline we constructed in Texas and New Mexico at a cost of approximately $36.4 million.  We entered into a long-term throughput and deficiency agreement with a customer on this pipeline, which contains minimum volume/payment commitments. This agreement is being accounted for as a direct financing lease.
	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	6 Months Ended
	Jun. 30, 2014
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 payout of 9.4 million of our limited partner units. The estimated units available under the LTIP at June 30, 2014 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						Six Months Ended
		June 30, 2013						30-Jun-13
		Equity		Liability		Total		Equity		Liability		Total
		Method		Method				Method		Method
	Performance/market-based awards:
	2010 awards	$	—	$	—	$	—	$	121	$	73	$	194
	2011 awards	2,120		1,076		3,196		3,103		2,223		5,326
	2012 awards	826		370		1,196		1,707		981		2,688
	2013 awards	733		198		931		1,459		387		1,846
	Retention awards	103		—		103		228		—		228
	Total	$	3,782	$	1,644	$	5,426	$	6,618	$	3,664	$	10,282
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense					$	5,317					$	9,802
	Operating expense					109						480
	Total					$	5,426					$	10,282
		Three Months Ended						Six Months Ended
		30-Jun-14						30-Jun-14
		Equity		Liability		Total		Equity		Liability		Total
		Method		Method				Method		Method
	Performance/market-based awards:
	2012 awards	$	1,022	$	1,617	$	2,639	$	2,044	$	2,541	$	4,585
	2013 awards	2,195		1,305		3,500		3,376		1,853		5,229
	2014 awards	1,228		—		1,228		2,132		—		2,132
	Retention awards	298		—		298		807		—		807
	Total	$	4,743	$	2,922	$	7,665	$	8,359	$	4,394	$	12,753
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense					$	7,486					$	12,460
	Operating expense					179						293
	Total					$	7,665					$	12,753
	On February 3, 2014, 178,184 phantom unit awards were issued pursuant to our long-term incentive plan. These grants included both performance-based and retention awards and have a three-year vesting period that will end on December 31, 2016.
	On February 3, 2014, we issued 388,819 limited partner units, of which 387,216 were issued to settle unit award grants to certain employees that vested on December 31, 2013 and 1,603 were issued to settle the equity-based retainer paid to a member of our general partner's board of directors.

Distributions

Distributions	6 Months Ended
	Jun. 30, 2014
Distributions Made to Members or Limited Partners [Abstract]	'
Distributions	'
	Distributions
	Distributions we paid during 2013 and 2014 were as follows (in thousands, except per unit amounts):
	Payment Date	Per Unit Cash			Total Cash Distribution to Limited Partners
		Distribution
		Amount
	2/14/13		$	0.5		$	113,340
	5/15/13		0.5075			115,040
	Through 06/30/2013		1.0075			228,380
	8/14/13		0.5325			120,707
	11/14/13		0.5575			126,374
	Total		$	2.0975		$	475,461
	2/14/14		$	0.585		$	132,835
	5/15/14		0.6125			139,079
	Through 06/30/2014		1.1975			271,914
	8/14/2014(1)		0.64			145,324
	Total		$	1.8375		$	417,238
	(1) Our general partner's board of directors declared this cash distribution on July 24, 2014 to be paid on August 14, 2014 to unitholders of record at the close of business on August 4, 2014.

Fair_Value

Fair Value	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value	'
	Fair Value
	Recurring
	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:
	•	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 9 – Derivative Financial Instruments for further disclosures regarding these contracts.
	•	Long-term receivables. These include lease payments receivable under a direct-financing leasing arrangement and insurance receivables. Fair value was determined by estimating the present value of future cash flows using current market rates.
	•	Debt. The fair value of our publicly traded notes was based on the prices of those notes at December 31, 2013 and June 30, 2014; 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 and our commercial paper program approximates fair value due to the frequent repricing of these obligations.
	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, 2013 and June 30, 2014, based on the three levels established by ASC 820; Fair Value Measurements and Disclosures (in thousands):
			As of December 31, 2013
	Assets (Liabilities)								Fair Value Measurements using:
			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)		$	(4,502	)	$	(4,502	)	$	(4,502	)	$	—		$	—
	Long-term receivables		$	2,730		$	2,658		$	—		$	—		$	2,658
	Debt		$	(2,685,287	)	$	(2,815,210	)	$	—		$	(2,815,210	)	$	—
			As of June 30, 2014
	Assets (Liabilities)								Fair Value Measurements using:
			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)		$	(14,657	)	$	(14,657	)	$	(14,657	)	$	—		$	—
	Long-term receivables		$	30,028		$	31,451		$	—		$	—		$	31,451
	Debt		$	(2,910,496	)	$	(3,175,687	)	$	—		$	(3,175,687	)	$	—
	Non-recurring
	During second quarter 2014, we recognized a $9.4 million impairment to a certain pipeline terminal and related assets. The inputs for the valuation models used in determining the fair value of this pipeline terminal and related assets were Level 3—Significant Unobservable Inputs. Management is considering divesting these assets and their carrying values were adjusted to an estimated sales value.  The impairment was recorded to depreciation, amortization and impairments.  The terminal and related assets are part of our Refined Products segment. As of June 30, 2014, the carrying amount and fair value of this asset were $10.0 million.

Related_Party_Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2014
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 June 30, 2013 and 2014, we made purchases of butane from subsidiaries of Targa of $0.4 million and $1.6 million, respectively. For the six months ended June 30, 2013 and 2014, we made purchases of butane from subsidiaries of Targa of $14.6 million and $13.8 million, respectively. These purchases were made on the same terms as comparable third-party transactions. There were no amounts payable to Targa at December 31, 2013 or June 30, 2014.
	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	6 Months Ended
	Jun. 30, 2014
Subsequent Events [Abstract]	'
Subsequent Events	'
	Subsequent Events
	Recognizable events
	No recognizable events occurred during the period.
	Non-recognizable events
	In July 2014, our general partner's board of directors declared a quarterly distribution of $0.64 per unit to be paid on August 14, 2014 to unitholders of record at the close of business on August 4, 2014. The total cash distributions expected to be paid are $145.3 million.

Product_Sales_Revenues_Tables

Product Sales Revenues (Tables)	6 Months Ended
	Jun. 30, 2014
Product Sales Revenue [Abstract]	'
Components of Product Sales Revenues	'
	For the three and six months ended June 30, 2013 and 2014, product sales revenue included the following (in thousands):
		Three Months Ended					Six Months Ended
		June 30,					June 30,
		2013		2014			2013			2014
	Physical sale of petroleum products	$	145,580	$	154,310		$	353,460		$	447,550
	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)	12,342		(16,666		)	6,184			(13,843		)
	Other	—		13			(11		)	13
	Total NYMEX contract adjustments	12,342		(16,653		)	6,173			(13,830		)
	Total product sales revenue	$	157,922	$	137,657		$	359,633		$	433,720
	(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)	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Schedule of Business Segment Reporting Information	'
	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 consider when evaluating the core profitability of our separate operating segments.
		Three Months Ended June 30, 2013
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	202,397	$	41,158		$	38,907		$	—		$	282,462
	Product sales revenue	156,321		—			1,601			—			157,922
	Affiliate management fee revenue	—		3,239			289			—			3,528
	Total revenue	358,718		44,397			40,797			—			443,912
	Operating expenses	66,456		4,027			7,694			(762		)	77,415
	Cost of product sales	114,460		—			868			—			115,328
	Earnings of non-controlled entities	—		(110		)	(626		)	—			(736		)
	Operating margin	177,802		40,480			32,861			762			251,905
	Depreciation, amortization and impairments	21,224		5,104			7,096			762			34,186
	G&A expenses	23,292		4,915			5,055			—			33,262
	Operating profit	$	133,286	$	30,461		$	20,710		$	—		$	184,457
		Three Months Ended June 30, 2014
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	232,489	$	79,556		$	41,523		$	—		$	353,568
	Product sales revenue	136,334		—			1,323			—			137,657
	Affiliate management fee revenue	—		4,902			319			—			5,221
	Total revenue	368,823		84,458			43,165			—			496,446
	Operating expenses	97,302		11,867			16,544			(839		)	124,874
	Cost of product sales	108,817		—			286			—			109,103
	Earnings of non-controlled entities	—		(888		)	(1,067		)	—			(1,955		)
	Operating margin	162,704		73,479			27,402			839			264,424
	Depreciation, amortization and impairments	32,083		6,725			7,250			839			46,897
	G&A expenses	25,374		7,697			6,238			—			39,309
	Operating profit	$	105,247	$	59,057		$	13,914		$	—		$	178,218
		Six Months Ended June 30, 2013
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	367,756	$	64,386		$	77,591		$	—		$	509,733
	Product sales revenue	355,736		—			3,897			—			359,633
	Affiliate management fee revenue	—		6,398			569			—			6,967
	Total revenue	723,492		70,784			82,057			—			876,333
	Operating expenses	112,737		9,134			22,247			(1,522		)	142,596
	Cost of product sales	272,758		—			2,968			—			275,726
	Earnings of non-controlled entities	—		(1,485		)	(1,302		)	—			(2,787		)
	Operating margin	337,997		63,135			58,144			1,522			460,798
	Depreciation, amortization and impairments	42,577		12,573			13,846			1,522			70,518
	G&A expenses	44,494		9,042			9,782			—			63,318
	Operating profit	$	250,926	$	41,520		$	34,516		$	—		$	326,962
		Six Months Ended June 30, 2014
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	442,725	$	147,459		$	81,021		$	—		$	671,205
	Product sales revenue	430,044		—			3,676			—			433,720
	Affiliate management fee revenue	—		9,497			630			—			10,127
	Total revenue	872,769		156,956			85,327			—			1,115,052
	Operating expenses	148,459		20,925			30,630			(1,643		)	198,371
	Cost of product sales	306,573		—			570			—			307,143
	Earnings of non-controlled entities	—		(708		)	(1,713		)	—			(2,421		)
	Operating margin	417,737		136,739			55,840			1,643			611,959
	Depreciation, amortization and impairments	55,255		13,188			14,322			1,643			84,408
	G&A expenses	48,393		13,691			12,160			—			74,244
	Operating profit	$	314,089	$	109,860		$	29,358		$	—		$	453,307

Investments_in_NonControlled_E1

Investments in Non-Controlled Entities (Tables)	6 Months Ended
	Jun. 30, 2014
Equity Method Investments and Joint Ventures [Abstract]	'
Schedule of Equity Method Investments	'
	A summary of our investments in non-controlled entities follows (in thousands):
		BridgeTex			All Others			Consolidated
	Investment at December 31, 2013	$	246,875		$	113,977		$	360,852
	Additional investment	281,803			4,142			285,945
	Other adjustment to investment	—			(650		)	(650		)
	Earnings (losses) of non-controlled entities:
	Proportionate share of earnings (loss)	(140		)	2,936			2,796
	Amortization of excess investment and capitalized interest	—			(375		)	(375		)
	Earnings (losses) of non-controlled entities	(140		)	2,561			2,421
	Less:
	Distributions of earnings from investments in non-controlled entities	—			1,713			1,713
	Distributions in excess of earnings of non-controlled entities	—			1,765			1,765
	Investment at June 30, 2014	$	528,538		$	116,552		$	645,090
	Summarized financial information of our non-controlled entities as of and for the six months ended June 30, 2014 follows (in thousands):
		BridgeTex			All Others			Consolidated
	Current assets	$	60,296		$	20,128		$	80,424
	Noncurrent assets	907,337			184,876			1,092,213
	Total assets	$	967,633		$	205,004		$	1,172,637
	Current liabilities	107,742			6,410			114,152
	Noncurrent liabilities	—			98			98
	Total liabilities	$	107,742		$	6,508		$	114,250
	Equity	$	859,891		$	198,496		$	1,058,387
	Revenue	$	—		$	18,464		$	18,464
	Net income (loss)	$	(280	)	$	5,871		$	5,591

Inventory_Tables

Inventory (Tables)	6 Months Ended
	Jun. 30, 2014
Inventory Disclosure [Abstract]	'
Schedule of Inventory	'
	Inventory at December 31, 2013 and June 30, 2014 was as follows (in thousands):
		December 31, 2013		June 30,
				2014
	Refined products	$	77,144	$	35,331
	Liquefied petroleum gases	23,476		57,103
	Transmix	72,156		80,619
	Crude oil	7,188		10,302
	Additives	7,260		5,587
	Total inventory	$	187,224	$	188,942

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	6 Months Ended
	Jun. 30, 2014
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 six months ended June 30, 2013 and 2014 (in thousands):
		Three Months Ended						Three Months Ended
		30-Jun-13						June 30, 2014
		Pension			Other  Post-			Pension			Other  Post-
		Benefits			Retirement			Benefits			Retirement
					Benefits						Benefits
	Components of net periodic benefit costs:
	Service cost	$	3,374		$	67		$	3,352		$	47
	Interest cost	1,334			91			2,030			139
	Expected return on plan assets	(1,645		)	—			(1,490		)	—
	Amortization of prior service cost (credit)(1)	77			(928		)	—			(928		)
	Amortization of actuarial loss(1)	1,145			209			930			262
	Settlement cost(1)	—			—			1,569			—
	Net periodic benefit cost (credit)	$	4,285		$	(561	)	$	6,391		$	(480	)
		Six Months Ended						Six Months Ended
		30-Jun-13						June 30, 2014
		Pension			Other  Post-			Pension			Other  Post-
		Benefits			Retirement			Benefits			Retirement
					Benefits						Benefits
	Components of net periodic benefit costs:
	Service cost	$	6,950		$	144		$	6,704		$	114
	Interest cost	2,684			206			3,689			253
	Expected return on plan assets	(3,115		)	—			(3,187		)	—
	Amortization of prior service cost (credit)(1)	154			(1,856		)	33			(1,856		)
	Amortization of actuarial loss(1)	2,167			517			1,559			457
	Settlement cost(1)	—			—			1,569			—
	Net periodic benefit cost (credit)	$	8,840		$	(989	)	$	10,367		$	(1,032	)
	(1) These amounts are included in our Consolidated Statements of Comprehensive Income and Consolidated Statements of Cash Flows as changes in employee benefit plan assets and benefit obligations.

Debt_Tables

Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Consolidated Debt	'
	Consolidated debt at December 31, 2013 and June 30, 2014 was as follows (in thousands, except as otherwise noted):
			December 31, 2013		June 30,		Weighted-Average
					2014		Interest Rate for Six Months Ending
							June 30, 2014 (1)
	Commercial paper(2)		$	—	$	220,977	0.30%
	Revolving credit facility(2)		—		—		1.30%
	$250.0 million of 6.45% Notes due 2014(2)		249,971		—		6.30%
	$250.0 million of 5.65% Notes due 2016		251,183		250,970		5.70%
	$250.0 million of 6.40% Notes due 2018		259,346		258,313		5.40%
	$550.0 million of 6.55% Notes due 2019		571,515		569,704		5.70%
	$550.0 million of 4.25% Notes due 2021		557,213		556,763		4.00%
	$250.0 million of 6.40% Notes due 2037		248,998		249,007		6.40%
	$250.0 million of 4.20% Notes due 2042		248,377		248,391		4.20%
	$550.0 million of 5.15% Notes due 2043		298,684		556,371		5.10%
	Total debt		$	2,685,287	$	2,910,496	5.10%
	-1	Weighted-average interest rate includes the amortization/accretion of discounts, premiums and gains/losses realized on historical cash flow and fair value hedges in interest expense.
	-2	These borrowings were outstanding for only a portion of the six month period ending June 30, 2014. The weighted-average interest rate for these borrowings was calculated based on the number of days the borrowings were outstanding during the noted period.

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule Of Forward Purchase And Sales Contracts	'
	As of June 30, 2014, we had commitments under these forward purchase and sale contracts as follows (in millions):
		Notional Value				Barrels
	Forward purchase contracts	$	137.7			2.4
	Forward sale contracts	$	8.8			0.1
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 June 30, 2014 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 July 2014 and November 2016
	NYMEX - Economic Hedges		3.4 million barrels of refined products and crude oil		Between July 2014 and April 2015
	Butane Futures Agreements - Economic Hedges		0.9 million barrels of butane		Between September 2014 and April 2015
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, 2013 and June 30, 2014 (in thousands):
			31-Dec-13
	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(1)				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet				Net Asset Amount
	Energy commodity derivatives		$	(7,167	)		$	2,665			$	(4,502	)		$	14,782			$	10,280
			30-Jun-14
	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(2)				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet				Net Asset Amount
	Energy commodity derivatives		$	(16,577	)		$	1,920			$	(14,657	)		$	29,070			$	14,413
	(1) Net amount includes energy commodity derivative contracts classified as current liabilities, net, of $6,737 and noncurrent assets of $2,235.
	(2) Net amount includes energy commodity derivative contracts classified as current liabilities, net, of $11,140 and noncurrent liabilities of $3,517.
Derivative Gains Included In Accumulated Other Comprehensive Loss (AOCL)	'
	The changes in derivative activity included in AOCL for the three and six months ended June 30, 2013 and 2014 were as follows (in thousands):
		Three Months Ended June 30,								Six Months Ended June 30,
	Derivative Gains (Losses) Included in AOCL	2013				2014				2013				2014
	Beginning balance	$	13,933			$	9,988			$	14,126			$	13,627
	Net loss on cash flow hedges	—				—				(4,560		)		(3,613		)
	Reclassification of net loss (gain) on cash flow hedges to income	(41		)		(153		)		4,326				(179		)
	Ending balance	$	13,892			$	9,835			$	13,892			$	9,835
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 six months ended June 30, 2013 and 2014 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 June 30, 2013
			Amount of Gain Recognized in AOCL on Derivative						Location of Gain Reclassified from AOCL into  Income		Amount of Gain Reclassified from AOCL into Income
	Derivative Instrument										Effective Portion						Ineffective Portion
	Interest rate contracts			$	—				Interest expense			$	41					$	—
			Three Months Ended June 30, 2014
			Amount of Gain (Loss) Recognized in AOCL on Derivative						Location of Gain (Loss) Reclassified from AOCL into  Income		Amount of Gain (Loss) Reclassified from AOCL into Income
	Derivative Instrument										Effective Portion						Ineffective Portion
	Interest rate contracts			$	—				Interest expense			$	(30	)				$	183
			Six Months Ended June 30, 2013
			Amount of Gain (Loss) Recognized in AOCL on Derivative						Location of Gain (Loss) Reclassified from AOCL into  Income		Amount of Gain (Loss) Reclassified from AOCL into Income
	Derivative Instrument										Effective Portion						Ineffective Portion
	Interest rate contracts			$	—				Interest expense			$	82					$	—
	NYMEX commodity contracts			(4,560		)			Product sales revenue			(4,408		)				—
	Total cash flow hedges			$	(4,560	)			Total			$	(4,326	)				$	—
			Six Months Ended June 30, 2014
			Amount of Gain (Loss) Recognized in AOCL on Derivative						Location of Gain (Loss) Reclassified from AOCL into  Income		Amount of Gain (Loss) Reclassified from AOCL into Income
	Derivative Instrument										Effective Portion						Ineffective Portion
	Interest rate contracts			$	(3,613	)			Interest expense			$	(4	)				$	183
Derivatives And Hedging-Overall-Subsequent Measurement	'
	The following table provides a summary of the effect on our consolidated statements of income for the three months ended June 30, 2013 and 2014 of derivatives accounted for under ASC 815; Derivatives and Hedging—Overall, that were not designated as hedging instruments (in thousands):
					Amount of Gain (Loss) Recognized on Derivative
			Location of Gain (Loss)		Three Months Ended June 30,								Six Months Ended June 30,
	Derivative Instrument		Recognized on Derivative		2013				2014				2013				2014
	NYMEX commodity contracts		Product sales revenue		$	12,342			$	(16,653	)		$	10,581			$	(13,830	)
	NYMEX commodity contracts		Operating expenses		3,348				(4,268		)		1,462				(3,903		)
	Butane futures agreements		Cost of product sales		20				632				(761		)		776
			Total		$	15,710			$	(20,289	)		$	11,282			$	(16,957	)
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, 2013 and June 30, 2014 (in thousands):
			December 31, 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		$	—			Energy commodity derivatives contracts, net		$	146
	NYMEX commodity contracts		Other noncurrent assets		2,235				Other noncurrent liabilities		—
			Total		$	2,235			Total		$	146
			June 30, 2014
			Asset Derivatives						Liability Derivatives
	Derivative Instrument		Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
	NYMEX commodity contracts		Energy commodity derivatives contracts, net		$	34			Energy commodity derivatives contracts, net		$	—
	NYMEX commodity contracts		Other noncurrent assets		—				Other noncurrent liabilities		3,517
			Total		$	34			Total		$	3,517
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, 2013 and June 30, 2014 (in thousands):
			December 31, 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		$	48			Energy commodity derivatives contracts, net		$	7,021
	Butane futures agreements		Energy commodity derivatives contracts, net		382				Energy commodity derivatives contracts, net		—
			Total		$	430			Total		$	7,021
			June 30, 2014
			Asset Derivatives						Liability Derivatives
	Derivative Instrument		Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
	NYMEX commodity contracts		Energy commodity derivatives contracts, net		$	1,184			Energy commodity derivatives contracts, net		$	12,971
	Butane futures agreements		Energy commodity derivatives contracts, net		702				Energy commodity derivatives contracts, net		89
			Total		$	1,886			Total		$	13,060

LongTerm_Incentive_Plan_Tables

Long-Term Incentive Plan (Tables)	6 Months Ended
	Jun. 30, 2014
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						Six Months Ended
		June 30, 2013						30-Jun-13
		Equity		Liability		Total		Equity		Liability		Total
		Method		Method				Method		Method
	Performance/market-based awards:
	2010 awards	$	—	$	—	$	—	$	121	$	73	$	194
	2011 awards	2,120		1,076		3,196		3,103		2,223		5,326
	2012 awards	826		370		1,196		1,707		981		2,688
	2013 awards	733		198		931		1,459		387		1,846
	Retention awards	103		—		103		228		—		228
	Total	$	3,782	$	1,644	$	5,426	$	6,618	$	3,664	$	10,282
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense					$	5,317					$	9,802
	Operating expense					109						480
	Total					$	5,426					$	10,282
		Three Months Ended						Six Months Ended
		30-Jun-14						30-Jun-14
		Equity		Liability		Total		Equity		Liability		Total
		Method		Method				Method		Method
	Performance/market-based awards:
	2012 awards	$	1,022	$	1,617	$	2,639	$	2,044	$	2,541	$	4,585
	2013 awards	2,195		1,305		3,500		3,376		1,853		5,229
	2014 awards	1,228		—		1,228		2,132		—		2,132
	Retention awards	298		—		298		807		—		807
	Total	$	4,743	$	2,922	$	7,665	$	8,359	$	4,394	$	12,753
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense					$	7,486					$	12,460
	Operating expense					179						293
	Total					$	7,665					$	12,753

Distributions_Tables

Distributions (Tables)	6 Months Ended
	Jun. 30, 2014
Distributions Made to Members or Limited Partners [Abstract]	'
Schedule Of Distributions	'
	Distributions we paid during 2013 and 2014 were as follows (in thousands, except per unit amounts):
	Payment Date	Per Unit Cash			Total Cash Distribution to Limited Partners
		Distribution
		Amount
	2/14/13		$	0.5		$	113,340
	5/15/13		0.5075			115,040
	Through 06/30/2013		1.0075			228,380
	8/14/13		0.5325			120,707
	11/14/13		0.5575			126,374
	Total		$	2.0975		$	475,461
	2/14/14		$	0.585		$	132,835
	5/15/14		0.6125			139,079
	Through 06/30/2014		1.1975			271,914
	8/14/2014(1)		0.64			145,324
	Total		$	1.8375		$	417,238
	(1) Our general partner's board of directors declared this cash distribution on July 24, 2014 to be paid on August 14, 2014 to unitholders of record at the close of business on August 4, 2014.

Fair_Value_Tables

Fair Value (Tables)	6 Months Ended
	Jun. 30, 2014
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, 2013 and June 30, 2014, based on the three levels established by ASC 820; Fair Value Measurements and Disclosures (in thousands):
		As of December 31, 2013
	Assets (Liabilities)							Fair Value Measurements using:
		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)	$	(4,502	)	$	(4,502	)	$	(4,502	)	$	—		$	—
	Long-term receivables	$	2,730		$	2,658		$	—		$	—		$	2,658
	Debt	$	(2,685,287	)	$	(2,815,210	)	$	—		$	(2,815,210	)	$	—
		As of June 30, 2014
	Assets (Liabilities)							Fair Value Measurements using:
		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)	$	(14,657	)	$	(14,657	)	$	(14,657	)	$	—		$	—
	Long-term receivables	$	30,028		$	31,451		$	—		$	—		$	31,451
	Debt	$	(2,910,496	)	$	(3,175,687	)	$	—		$	(3,175,687	)	$	—

Organization_Description_of_Bu1

Organization, Description of Business And Basis Of Presentation Organization, Description of Business and Basis of Presentation (Narrative) (Details)	Jun. 30, 2014
	Terminal
Refined Products [Member]	'
Organization and Description of Business [Line Items]	'
Number of Pipeline Terminals	54
Number of Independent Terminals	27
Refined Products [Member] | Refined Products Transportation Services [Member]	'
Organization and Description of Business [Line Items]	'
Pipeline Length	9,500
Refined Products [Member] | Ammonia Transportation Services [Member]	'
Organization and Description of Business [Line Items]	'
Pipeline Length	1,100
Crude Oil Pipeline and Terminals [Member]	'
Organization and Description of Business [Line Items]	'
Pipeline Length	1,100
Storage Capacity	18,000,000
Leaseable Storage Capacity	12,000,000
Marine Storage [Member]	'
Organization and Description of Business [Line Items]	'
Number of Independent Terminals	5
Storage Capacity	27,000,000

Product_Sales_Revenues_Compone

Product Sales Revenues (Components Of Product Sales Revenues) (Details) (USD $)	3 Months Ended				6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013
Product Sales Revenue [Line Items]	'		'		'		'
Physical sale of petroleum products	$154,310		$145,580		$447,550		$353,460
NYMEX Adjustments Included in Product Sales	-16,653		12,342		-13,830		6,173
Total product sales revenue	137,657		157,922		433,720		359,633
Butane Blending and Fractionation Activities [Member]	'		'		'		'
Product Sales Revenue [Line Items]	'		'		'		'
NYMEX Adjustments Included in Product Sales	-16,666	[1]	12,342	[1]	-13,843	[1]	6,184	[1]
Other Commodity Activities [Member]	'		'		'		'
Product Sales Revenue [Line Items]	'		'		'		'
NYMEX Adjustments Included in Product Sales	$13		$0		$13		($11)
[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		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Segment Reporting Information [Line Items]	'	'	'	'
Transportation and terminals revenue	$353,568	$282,462	$671,205	$509,733
Product sales revenue	137,657	157,922	433,720	359,633
Affiliate management fee revenue	5,221	3,528	10,127	6,967
Total revenue	496,446	443,912	1,115,052	876,333
Operating expenses	124,874	77,415	198,371	142,596
Cost of product sales	109,103	115,328	307,143	275,726
Earnings of non-controlled entities	-1,955	-736	-2,421	-2,787
Operating margin	264,424	251,905	611,959	460,798
Depreciation, amortization and impairments	46,897	34,186	84,408	70,518
G&A expenses	39,309	33,262	74,244	63,318
Operating profit	178,218	184,457	453,307	326,962
Operating Segments [Member] | Refined Products [Member]	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Transportation and terminals revenue	232,489	202,397	442,725	367,756
Product sales revenue	136,334	156,321	430,044	355,736
Affiliate management fee revenue	0	0	0	0
Total revenue	368,823	358,718	872,769	723,492
Operating expenses	97,302	66,456	148,459	112,737
Cost of product sales	108,817	114,460	306,573	272,758
Earnings of non-controlled entities	0	0	0	0
Operating margin	162,704	177,802	417,737	337,997
Depreciation, amortization and impairments	32,083	21,224	55,255	42,577
G&A expenses	25,374	23,292	48,393	44,494
Operating profit	105,247	133,286	314,089	250,926
Operating Segments [Member] | Crude Oil Pipeline and Terminals [Member]	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Transportation and terminals revenue	79,556	41,158	147,459	64,386
Product sales revenue	0	0	0	0
Affiliate management fee revenue	4,902	3,239	9,497	6,398
Total revenue	84,458	44,397	156,956	70,784
Operating expenses	11,867	4,027	20,925	9,134
Cost of product sales	0	0	0	0
Earnings of non-controlled entities	-888	-110	-708	-1,485
Operating margin	73,479	40,480	136,739	63,135
Depreciation, amortization and impairments	6,725	5,104	13,188	12,573
G&A expenses	7,697	4,915	13,691	9,042
Operating profit	59,057	30,461	109,860	41,520
Operating Segments [Member] | Marine Storage [Member]	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Transportation and terminals revenue	41,523	38,907	81,021	77,591
Product sales revenue	1,323	1,601	3,676	3,897
Affiliate management fee revenue	319	289	630	569
Total revenue	43,165	40,797	85,327	82,057
Operating expenses	16,544	7,694	30,630	22,247
Cost of product sales	286	868	570	2,968
Earnings of non-controlled entities	-1,067	-626	-1,713	-1,302
Operating margin	27,402	32,861	55,840	58,144
Depreciation, amortization and impairments	7,250	7,096	14,322	13,846
G&A expenses	6,238	5,055	12,160	9,782
Operating profit	13,914	20,710	29,358	34,516
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	-839	-762	-1,643	-1,522
Cost of product sales	0	0	0	0
Earnings of non-controlled entities	0	0	0	0
Operating margin	839	762	1,643	1,522
Depreciation, amortization and impairments	839	762	1,643	1,522
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

6 Months Ended

3 Months Ended

6 Months Ended

6 Months Ended

12 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jun. 30, 2014

Texas Frontera Llc [Member]

Osage Pipeline Co [Member]

Double Eagle Pipeline Llc [Member]

Double Eagle Pipeline Llc [Member]

Double Eagle Pipeline Llc [Member]

BridgeTex [Member]

BridgeTex [Member]

BridgeTex [Member]

BridgeTex [Member]

BridgeTex [Member]

BridgeTex [Member]

BridgeTex [Member]

All Other Equity Investments [Member]

bbl

mi

mi

mi

mi

Sale of Emission Reduction Credits [Member]

Sale of Emission Reduction Credits [Member]

Sale of Emission Reduction Credits [Member]

Sale of Easement Rights [Member]

Sale of Easement Rights [Member]

Sale of Easement Rights [Member]

Income Statement [Member]

Deferred Income [Member]

Income Statement [Member]

Deferred Income [Member]

Schedule of Equity Method Investments [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest in equity method investment

'

'

'

'

50.00%

50.00%

50.00%

50.00%

'

50.00%

'

'

'

'

'

'

'

Storage Capacity

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Pipeline Length

'

'

'

'

'

135

195

195

'

450

'

'

'

'

'

'

'

Related Party Transaction, Other Revenues from Transactions with Related Party

'

'

'

'

'

'

$800,000

$1,300,000

'

'

'

'

'

'

'

'

'

Accounts Receivable, Related Parties, Current

'

'

'

'

'

'

300,000

300,000

200,000

'

'

'

'

'

'

'

'

Related Party Transaction, Amounts of Transaction

'

'

'

'

'

'

'

'

'

'

4,800,000

2,400,000

2,400,000

1,400,000

700,000

700,000

'

Change in Equity Method Investments [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investment at December 31, 2013

'

'

360,852,000

'

'

'

'

'

'

246,875,000

'

'

'

'

'

'

113,977,000

Additional investment

'

'

285,945,000

99,667,000

'

'

'

'

'

281,803,000

'

'

'

'

'

'

4,142,000

Other adjustment to investment

'

'

-650,000

'

'

'

'

'

'

0

'

'

'

'

'

'

-650,000

Proportionate share of earnings (loss)

'

'

2,796,000

'

'

'

'

'

'

-140,000

'

'

'

'

'

'

2,936,000

Amortization of excess investment and capitalized interest

'

'

-375,000

'

'

'

'

'

'

0

'

'

'

'

'

'

-375,000

Earnings (losses) of non-controlled entities

1,955,000

736,000

2,421,000

2,787,000

'

'

'

'

'

-140,000

'

'

'

'

'

'

2,561,000

Distributions of earnings from investments in non-controlled entities

'

'

1,713,000

1,302,000

'

'

'

'

'

0

'

'

'

'

'

'

1,713,000

Distributions in excess of earnings of non-controlled entities

'

'

1,765,000

750,000

'

'

'

'

'

0

'

'

'

'

'

'

1,765,000

Investment at June 30, 2014

645,090,000

'

645,090,000

'

'

'

'

'

'

528,538,000

'

'

'

'

'

'

116,552,000

Equity Method Investment, Summarized Financial Information, Current Assets

80,424,000

'

80,424,000

'

'

'

'

'

'

60,296,000

'

'

'

'

'

'

20,128,000

Equity Method Investment, Summarized Financial Information, Noncurrent Assets

1,092,213,000

'

1,092,213,000

'

'

'

'

'

'

907,337,000

'

'

'

'

'

'

184,876,000

Equity Method Investment, Summarized Financial Information, Assets

1,172,637,000

'

1,172,637,000

'

'

'

'

'

'

967,633,000

'

'

'

'

'

'

205,004,000

Equity Method Investment, Summarized Financial Information, Current Liabilities

114,152,000

'

114,152,000

'

'

'

'

'

'

107,742,000

'

'

'

'

'

'

6,410,000

Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities

98,000

'

98,000

'

'

'

'

'

'

0

'

'

'

'

'

'

98,000

Equity Method Investment, Summarized Financial Information, Liabilities

114,250,000

'

114,250,000

'

'

'

'

'

'

107,742,000

'

'

'

'

'

'

6,508,000

Equity Method Investment Summarized Financial Information, Equity

1,058,387,000

'

1,058,387,000

'

'

'

'

'

'

859,891,000

'

'

'

'

'

'

198,496,000

Equity Method Investment, Summarized Financial Information, Revenue

'

'

18,464,000

'

'

'

'

'

'

0

'

'

'

'

'

'

18,464,000

Equity Method Investment, Summarized Financial Information, Net Income (Loss)

'

'

$5,591,000

'

'

'

'

'

'

($280,000)

'

'

'

'

'

'

$5,871,000

Business_Combinations_Business1

Business Combinations Business Combinations (Narrative) (Details) (Plains Pipeline Acquisition [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
	mi
New Mexico System [Member]	'
Business Acquisition [Line Items]	'
Pipeline Length	250
Payments to Acquire Businesses, Net of Cash Acquired	$57
Rocky Mountains [Member]	'
Business Acquisition [Line Items]	'
Pipeline Length	550
Payments to Acquire Businesses, Net of Cash Acquired	$135
Number of Pipeline Terminals	4
Storage Capacity	1,700,000

Inventory_Details

Inventory (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Refined products	$35,331	$77,144
Liquefied petroleum gases	57,103	23,476
Transmix	80,619	72,156
Crude oil	10,302	7,188
Additives	5,587	7,260
Total inventory	$188,942	$187,224

Employee_Benefit_Plans_Details

Employee Benefit Plans (Details) (USD $)	3 Months Ended				6 Months Ended
	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013
Defined Benefit Plan Disclosure [Line Items]	'		'		'		'
Number of Union Pension Plans	'		'		2		'
Pension Benefits	'		'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'		'
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	'		'		$21,100,000		'
Components of net periodic benefit costs:	'		'		'		'
Service cost	3,352,000		3,374,000		6,704,000		6,950,000
Interest cost	2,030,000		1,334,000		3,689,000		2,684,000
Expected return on plan assets	-1,490,000		-1,645,000		-3,187,000		-3,115,000
Amortization of prior service cost (credit)(1)	0	[1]	77,000	[1]	33,000	[1]	154,000	[1]
Amortization of actuarial loss(1)	930,000	[1]	1,145,000	[1]	1,559,000	[1]	2,167,000	[1]
Settlement cost(1)	1,569,000	[1]	0	[1]	1,569,000	[1]	0	[1]
Net periodic benefit cost (credit)	6,391,000		4,285,000		10,367,000		8,840,000
Other Post-Retirement Benefits	'		'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'		'
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	'		'		700,000		'
Components of net periodic benefit costs:	'		'		'		'
Service cost	47,000		67,000		114,000		144,000
Interest cost	139,000		91,000		253,000		206,000
Expected return on plan assets	0		0		0		0
Amortization of prior service cost (credit)(1)	-928,000	[1]	-928,000	[1]	-1,856,000	[1]	-1,856,000	[1]
Amortization of actuarial loss(1)	262,000	[1]	209,000	[1]	457,000	[1]	517,000	[1]
Settlement cost(1)	0	[1]	0	[1]	0	[1]	0	[1]
Net periodic benefit cost (credit)	($480,000)		($561,000)		($1,032,000)		($989,000)
[1]	These amounts are included in our Consolidated Statements of Comprehensive Income and Consolidated Statements of Cash Flows as changes in employee benefit plan assets and benefit obligations.

Debt_Consolidated_Debt_Details

Debt (Consolidated Debt) (Details) (USD $)	Jun. 30, 2014		Dec. 31, 2013
Debt Instrument [Line Items]	'		'
Total debt	$2,910,496,000		$2,685,287,000
Weighted-Average Interest Rate	5.10%	[1]	'
Debt Instrument, Face Amount	2,900,000,000		2,700,000,000
Commercial Paper [Member]	'		'
Debt Instrument [Line Items]	'		'
Total debt	220,977,000	[2]	0	[2]
Weighted-Average Interest Rate	0.30%	[1],[2]	'
Revolving Credit Facility [Member]	'		'
Debt Instrument [Line Items]	'		'
Total debt	0	[2]	0	[2]
Weighted-Average Interest Rate	1.30%	[1],[2]	'
Senior Notes [Member] | 6.45% Notes Due 2014 [Member]	'		'
Debt Instrument [Line Items]	'		'
Total debt	0	[2]	249,971,000	[2]
Weighted-Average Interest Rate	6.30%	[1],[2]	'
Debt Instrument, Face Amount	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	250,970,000		251,183,000
Weighted-Average Interest Rate	5.70%	[1]	'
Debt Instrument, Face Amount	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	258,313,000		259,346,000
Weighted-Average Interest Rate	5.40%	[1]	'
Debt Instrument, Face Amount	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	569,704,000		571,515,000
Weighted-Average Interest Rate	5.70%	[1]	'
Debt Instrument, Face Amount	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	556,763,000		557,213,000
Weighted-Average Interest Rate	4.00%	[1]	'
Debt Instrument, Face Amount	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	249,007,000		248,998,000
Weighted-Average Interest Rate	6.40%	[1]	'
Debt Instrument, Face Amount	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	248,391,000		248,377,000
Weighted-Average Interest Rate	4.20%	[1]	'
Debt Instrument, Face Amount	250,000,000		'
Debt Instrument, Interest Rate, Stated Percentage	4.20%		'
Senior Notes [Member] | 5.15% Notes Due 2043 [Member]	'		'
Debt Instrument [Line Items]	'		'
Total debt	556,371,000		298,684,000
Weighted-Average Interest Rate	5.10%	[1]	'
Debt Instrument, Face Amount	$550,000,000		'
Debt Instrument, Interest Rate, Stated Percentage	5.15%		'
[1]	Weighted-average interest rate includes the amortization/accretion of discounts, premiums and gains/losses realized on historical cash flow and fair value hedges in interest expense.
[2]	These borrowings were outstanding for only a portion of the six month period ending June 30, 2014. The weighted-average interest rate for these borrowings was calculated based on the number of days the borrowings were outstanding during the noted period.

Debt_Narrative_Details

Debt (Narrative) (Details) (USD $)	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Debt Instrument [Line Items]	'	'	'
Debt Instrument, Face Amount	$2,900,000,000	'	$2,700,000,000
Debt placement costs	-2,887,000	0	'
Senior Notes [Member] | 5.15% Notes Due 2043 [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Debt Instrument, Face Amount	550,000,000	'	'
Debt Instrument, Interest Rate, Stated Percentage	5.15%	'	'
Senior Notes [Member] | 5.15% Notes Due 2043 [Member] | Debt Offering Part Two [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Debt Instrument, Face Amount	250,000,000	'	'
Debt Instrument, Interest Rate, Stated Percentage	5.15%	'	'
Notes At Price	103.10%	'	'
After Underwriting Discounts	255,000,000	'	'
Debt placement costs	-2,700,000	'	'
Senior Notes [Member] | 6.45% Notes Due 2014 [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Debt Instrument, Face Amount	250,000,000	'	'
Debt Instrument, Interest Rate, Stated Percentage	6.45%	'	'
Revolving Credit Facility [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Borrowing capacity	1,000,000,000	'	'
Unused commitment fee	0.13%	'	'
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	1.00%	'	'
Unused commitment fee	0.10%	'	'
Revolving Credit Facility [Member] | Maximum [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Debt Instrument, Basis Spread on Variable Rate	1.75%	'	'
Unused commitment fee	0.28%	'	'
Commercial Paper [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Borrowing capacity	$1,000,000,000	'	'
Commercial Paper [Member] | Maximum [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Debt Instrument, Term	'397 days	'	'

Derivative_Financial_Instrumen2

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

3 Months Ended

6 Months Ended

3 Months Ended

12 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2012

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Fair Value Hedging [Member]

Fair Value Hedging [Member]

Fair Value Hedging [Member]

Fair Value Hedging [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

bbl

NYMEX Commodity Contracts [Member]

NYMEX Commodity Contracts [Member]

NYMEX Commodity Contracts [Member]

bbl

Other Noncurrent Assets [Member]

Other Current Assets [Member]

Derivative [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Notional Amount

'

'

'

'

'

'

$200,000,000

'

'

'

'

'

Debt Instrument, Face Amount

2,900,000,000

'

2,900,000,000

'

2,700,000,000

'

250,000,000

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

'

5.15%

'

'

'

'

'

Net loss on cash flow hedges(1)

0

[1]

0

[1]

-3,613,000

[1]

-4,560,000

[1]

'

'

-3,613,000

11,000,000

'

'

'

'

Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net

'

'

'

'

'

183,000

'

'

'

'

'

'

Energy commodity derivatives deposits

29,070,000

'

29,070,000

'

14,782,000

'

'

'

'

'

'

'

Derivative, Nonmonetary Notional Amount

'

'

'

'

'

'

'

'

700,000

700,000

'

'

Unrealized Gain (Loss) From Fair Value Hedge Agreements

'

'

'

'

'

'

'

'

'

-14,900,000

-14,700,000

-200,000

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

'

'

($300,000)

'

'

'

'

'

'

'

'

'

[1]

See Note 9–Derivative Financial Instruments for details of the amount of gain/loss recognized in accumulated other comprehensive loss ("AOCL") on derivatives and the amount of gain/loss reclassified from AOCL into income.

Derivative_Financial_Instrumen3

Derivative Financial Instruments (Schedule Of Forward Purchase And Sales Contracts) (Details) (Forward Contracts [Member], USD $)	Jun. 30, 2014
In Millions, unless otherwise specified	bbl
Forward Contracts [Member]	'
Derivative [Line Items]	'
Forward purchase contracts, Amount	$137.70
Forward purchase contracts, Barrels	2,400,000
Forward sale contracts, Amount	$8.80
Forward sale contracts, Barrels	100,000

Derivative_Financial_Instrumen4

Derivative Financial Instruments (Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements) (Details)	Jun. 30, 2014
	bbl
Fair Value Hedging [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	700,000
Economic Hedges [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	3,400,000
Economic Hedges Futures [Member]	'
Derivative [Line Items]	'
Derivative, Nonmonetary Notional Amount	900,000

Derivative_Financial_Instrumen5

Derivative Financial Instruments Schedule of Derivative Offset Amounts (Details) (Exchange Traded [Member], USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivative [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	($16,577)	($7,167)
Derivative Asset, Fair Value, Gross Asset	1,920	2,665
Derivative Liability Amount Not Offset	-14,657	-4,502
Derivative Liability, Fair Value of Collateral	29,070	14,782
Margin Deposit Net of Commodity Contract	14,413	10,280
Other Current Liabilities [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability Amount Not Offset	-11,140	-6,737
Other Noncurrent Liabilities [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability Amount Not Offset	-3,517	'
Other Noncurrent Assets [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability Amount Not Offset	'	$2,235

Derivative_Financial_Instrumen6

Derivative Financial Instruments (Derivative Gains Included In Accumulated Other Comprehensive Loss (AOCL) (Details) (USD $)	3 Months Ended				6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013
Derivative Gains Included in AOCI [Roll Forward]	'		'		'		'
Beginning balance	$9,988		$13,933		$13,627		$14,126
Net gain (loss) on cash flow hedges	0	[1]	0	[1]	-3,613	[1]	-4,560	[1]
Reclassification of net loss (gain) on cash flow hedges to income	-153	[1]	-41	[1]	-179	[1]	4,326	[1]
Ending balance	$9,835		$13,892		$9,835		$13,892
[1]	See Note 9–Derivative Financial Instruments for details of the amount of gain/loss recognized in accumulated other comprehensive loss ("AOCL") on derivatives and the amount of gain/loss reclassified from AOCL into income.

Derivative_Financial_Instrumen7

Derivative Financial Instruments (Derivatives And Hedging-Cash Flow Hedges) (Details) (USD $)

3 Months Ended

6 Months Ended

3 Months Ended

12 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

In Thousands, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2012

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2013

Jun. 30, 2013

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Designated as Hedging Instrument [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

NYMEX Commodity Contracts [Member]

NYMEX Commodity Contracts [Member]

Interest Expense [Member]

Interest Expense [Member]

Interest Expense [Member]

Interest Expense [Member]

Sales [Member]

Derivative Instruments, Gain (Loss) [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net gain (loss) on cash flow hedges

$0

[1]

$0

[1]

($3,613)

[1]

($4,560)

[1]

'

($3,613)

$11,000

($4,560)

$0

$0

($3,613)

$0

'

'

'

'

($4,560)

'

Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net

'

'

'

'

'

'

'

-4,326

'

'

'

'

-30

41

-4

82

'

-4,408

Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net

'

'

'

'

$183

'

'

$0

'

'

'

'

$183

$0

$183

$0

'

$0

[1]

See Note 9–Derivative Financial Instruments for details of the amount of gain/loss recognized in accumulated other comprehensive loss ("AOCL") on derivatives and the amount of gain/loss reclassified from AOCL into income.

Derivative_Financial_Instrumen8

Derivative Financial Instruments (Derivatives And Hedging-Overall-Subsequent Measurement) (Details) (Not Designated as Hedging Instrument [Member], USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Gain (Loss) on Derivative, Net	($20,289)	$15,710	($16,957)	$11,282
NYMEX Commodity Contracts [Member] | Sales [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Gain (Loss) on Derivative, Net	-16,653	12,342	-13,830	10,581
NYMEX Commodity Contracts [Member] | Operating Expenses [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Gain (Loss) on Derivative, Net	-4,268	3,348	-3,903	1,462
Butane Futures Agreements [Member] | Cost of Sales [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Derivative, Gain (Loss) on Derivative, Net	$632	$20	$776	($761)

Derivative_Financial_Instrumen9

Derivative Financial Instruments (Derivatives And Hedging-Designated) (Details) (Designated as Hedging Instrument [Member], USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$34	$2,235
Derivative Liability, Fair Value, Gross Liability	3,517	146
NYMEX Commodity Contracts [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	34	0
NYMEX Commodity Contracts [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	0	146
NYMEX Commodity Contracts [Member] | Other Noncurrent Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	0	2,235
NYMEX Commodity Contracts [Member] | Other Noncurrent Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	$3,517	$0

Recovered_Sheet1

Derivative Financial Instruments (Derivatives And Hedging-Nondesignated) (Details) (Not Designated as Hedging Instrument [Member], USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$1,886	$430
Derivative Liability, Fair Value, Gross Liability	13,060	7,021
NYMEX Commodity Contracts [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	1,184	48
NYMEX Commodity Contracts [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	12,971	7,021
Butane Futures Agreements [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	702	382
Butane Futures Agreements [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	$89	$0

Commitments_And_Contingencies_

Commitments And Contingencies (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Loss Contingencies [Line Items]	'	'	'	'	'
Liabilities recognized for estimated environmental costs	$34,666,000	'	$34,666,000	'	$38,486,000
Estimated environmental liabilities, years	'	'	'10 years	'	'
Environmental expenses	100,000	-9,400,000	400,000	-8,700,000	'
Receivables from insurance carriers related to environmental matters	4,600,000	'	4,600,000	'	4,800,000
Accounts Receivable [Member]	'	'	'	'	'
Loss Contingencies [Line Items]	'	'	'	'	'
Receivables from insurance carriers related to environmental matters	2,100,000	'	2,100,000	'	2,100,000
Other Noncurrent Assets [Member]	'	'	'	'	'
Loss Contingencies [Line Items]	'	'	'	'	'
Receivables from insurance carriers related to environmental matters	2,500,000	'	2,500,000	'	2,700,000
Clean Air Act Section 185 [Member]	'	'	'	'	'
Loss Contingencies [Line Items]	'	'	'	'	'
Loss Contingency, Loss in Period	'	'	'	-10,600,000	'
Texas and New Mexico [Member]	'	'	'	'	'
Loss Contingencies [Line Items]	'	'	'	'	'
Pipeline Length	36	'	36	'	'
Net Investment in Direct Financing and Sales Type Leases	$36,400,000	'	$36,400,000	'	'

LongTerm_Incentive_Plan_Narrat

Long-Term Incentive Plan (Narrative) (Details)	6 Months Ended
	Jun. 30, 2014
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'
Limited partners' capital account, units authorized for issuance	9,400,000
Limited partner unitholders, units remaining available	1,800,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	178,184
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	'3 years
Partners' Capital Account, Units, Unit-based Compensation	388,819
Management [Member]	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'
Partners' Capital Account, Units, Unit-based Compensation	387,216
Director [Member]	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'
Partners' Capital Account, Units, Unit-based Compensation	1,603

LongTerm_Incentive_Plan_Equity

Long-Term Incentive Plan (Equity-Based Incentive Compensation Expense) (Details) (Management [Member], USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	$7,665	$5,426	$12,753	$10,282
G&A Expense [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	7,486	5,317	12,460	9,802
Operating Expenses [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	179	109	293	480
Equity Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	4,743	3,782	8,359	6,618
Liability Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	2,922	1,644	4,394	3,664
Performance Based Awards [Member] | Two Thousand Ten Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	'	0	'	194
Performance Based Awards [Member] | Two Thousand Ten Awards [Member] | Equity Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	'	0	'	121
Performance Based Awards [Member] | Two Thousand Ten Awards [Member] | Liability Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	'	0	'	73
Performance Based Awards [Member] | Two Thousand Eleven Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	'	3,196	'	5,326
Performance Based Awards [Member] | Two Thousand Eleven Awards [Member] | Equity Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	'	2,120	'	3,103
Performance Based Awards [Member] | Two Thousand Eleven Awards [Member] | Liability Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	'	1,076	'	2,223
Performance Based Awards [Member] | Two Thousand Twelve Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	2,639	1,196	4,585	2,688
Performance Based Awards [Member] | Two Thousand Twelve Awards [Member] | Equity Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	1,022	826	2,044	1,707
Performance Based Awards [Member] | Two Thousand Twelve Awards [Member] | Liability Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	1,617	370	2,541	981
Performance Based Awards [Member] | Two Thousand Thirteen Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	3,500	931	5,229	1,846
Performance Based Awards [Member] | Two Thousand Thirteen Awards [Member] | Equity Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	2,195	733	3,376	1,459
Performance Based Awards [Member] | Two Thousand Thirteen Awards [Member] | Liability Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	1,305	198	1,853	387
Performance Based Awards [Member] | Two Thousand Fourteen Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	1,228	'	2,132	'
Performance Based Awards [Member] | Two Thousand Fourteen Awards [Member] | Equity Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	1,228	'	2,132	'
Performance Based Awards [Member] | Two Thousand Fourteen Awards [Member] | Liability Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	0	'	0	'
Retention Awards [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	298	103	807	228
Retention Awards [Member] | Equity Method [Member]	'	'	'	'
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]	'	'	'	'
Allocation of LTIP expense on consolidated statements of income	298	103	807	228
Retention Awards [Member] | Liability Method [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						6 Months Ended		12 Months Ended	0 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	15-May-14	Feb. 14, 2014	Nov. 14, 2013	Aug. 14, 2013	15-May-13	Feb. 14, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013	Aug. 14, 2014		Sep. 30, 2014
										Scenario, Forecast		Scenario, Forecast
Per Unit Cash Distribution Amount	$0.61	$0.59	$0.56	$0.53	$0.51	$0.50	$1.20	$1.01	$2.10	$0.64	[1]	$1.84
Total Cash Distribution to Limited Partners	$139,079	$132,835	$126,374	$120,707	$115,040	$113,340	$271,914	$228,380	$475,461	$145,324	[1]	$417,238
[1]	Our general partner's board of directors declared this cash distribution on July 24, 2014 to be paid on August 14, 2014 to unitholders of record at the close of business on August 4, 2014.

Fair_Value_Schedule_Of_Carryin

Fair Value (Schedule Of Carrying Amounts And Fair Values Of Financial Assets/Liabilities) (Details) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Certain Pipeline [Member]

Reported Value Measurement [Member]

Reported Value Measurement [Member]

Reported Value Measurement [Member]

Reported Value Measurement [Member]

Reported Value Measurement [Member]

Estimate of Fair Value Measurement [Member]

Estimate of Fair Value Measurement [Member]

Estimate of Fair Value Measurement [Member]

Estimate of Fair Value Measurement [Member]

Estimate of Fair Value Measurement [Member]

Fair Value, Inputs, Level 1 [Member]

Fair Value, Inputs, Level 1 [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Fair Value, Inputs, Level 3 [Member]

Fair Value, Inputs, Level 3 [Member]

Pipelines [Member]

NYMEX Commodity Contracts [Member]

NYMEX Commodity Contracts [Member]

Certain Pipeline [Member]

NYMEX Commodity Contracts [Member]

NYMEX Commodity Contracts [Member]

Certain Pipeline [Member]

NYMEX Commodity Contracts [Member]

NYMEX Commodity Contracts [Member]

Pipelines [Member]

Fair Value, Measurements, Nonrecurring [Member]

Fair Value, Inputs, Level 3 [Member]

Pipelines [Member]

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative liability

($14,657,000)

($4,502,000)

'

'

'

'

'

'

'

($14,657,000)

($4,502,000)

'

'

'

($14,657,000)

($4,502,000)

'

Long-term receivables

'

'

'

'

31,451,000

2,658,000

'

30,028,000

2,730,000

'

'

'

31,451,000

2,658,000

'

'

'

Debt

'

'

-3,175,687,000

-2,815,210,000

'

'

'

-2,910,496,000

-2,685,287,000

'

'

'

-3,175,687,000

-2,815,210,000

'

'

'

Other Asset Impairment Charges

'

'

'

'

'

'

9,400,000

'

'

'

'

'

'

'

'

'

'

Property, Plant, and Equipment, Fair Value Disclosure

'

'

'

'

'

'

'

'

'

'

'

$10,000,000

'

'

'

'

$10,000,000

Related_Party_Transactions_Det

Related Party Transactions (Details) (Targa Resource Partners, L.P., USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Targa Resource Partners, L.P.	'	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'	'
Related Party Transaction, Expenses from Transactions with Related Party	$1,600,000	$400,000	$13,800,000	$14,600,000	'
Accounts Payable, Related Parties	$0	'	$0	'	$0

Subsequent_Events_Details

Subsequent Events (Details) (USD $)

0 Months Ended

6 Months Ended

12 Months Ended

0 Months Ended

9 Months Ended

In Thousands, except Per Share data, unless otherwise specified

15-May-14

Feb. 14, 2014

Nov. 14, 2013

Aug. 14, 2013

15-May-13

Feb. 14, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Aug. 14, 2014

Sep. 30, 2014

Scenario, Forecast

Scenario, Forecast

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Cash distribution per unit

$0.61

$0.59

$0.56

$0.53

$0.51

$0.50

$1.20

$1.01

$2.10

$0.64

[1]

$1.84

Total cash distributions

$139,079

$132,835

$126,374

$120,707

$115,040

$113,340

$271,914

$228,380

$475,461

$145,324

[1]

$417,238

[1]

Our general partner's board of directors declared this cash distribution on July 24, 2014 to be paid on August 14, 2014 to unitholders of record at the close of business on August 4, 2014.