Magellan Midstream Partners (MMP) 10-Q 5 May 15 2015 Q1 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	3 Months Ended
	Mar. 31, 2015	4-May-15
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Entity Registrant Name	MAGELLAN MIDSTREAM PARTNERS LP
Entity Central Index Key	1126975
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		227,426,329

Consolidated_Statements_Of_Inc

Consolidated Statements Of Income (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Transportation and terminals revenue	$345,600	$317,637
Product sales revenue	173,127	296,063
Affiliate management fee revenue	3,363	4,906
Total revenue	522,090	618,606
Costs and expenses:
Operating	98,495	73,497
Cost of product sales	136,179	198,040
Depreciation and amortization	41,697	37,511
General and administrative	35,498	34,935
Total costs and expenses	311,869	343,983
Earnings of non-controlled entities	9,590	466
Operating profit	219,811	275,089
Interest expense	36,607	36,416
Interest income	-349	-391
Interest capitalized	-2,107	-5,310
Debt placement fee amortization expense	587	599
Other expense	279	0
Income before provision for income taxes	184,794	243,775
Provision for income taxes	1,158	1,221
Net income	$183,636	$242,554
Basic and diluted net income per limited partner unit	$0.81	$1.07
Weighted average number of limited partner units outstanding used for basic and diluted net income per unit calculation	227,525	227,141

Consolidated_Statements_Of_Com

Consolidated Statements Of Comprehensive Income (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Net income	$183,636		$242,554
Other comprehensive income:
Net loss on cash flow hedges(1)	-15,465	[1]	-3,613	[1]
Reclassification of net loss (gain) on cash flow hedges to income(1)	200	[1]	-26	[1]
Amortization of prior service credit(2)	-928	[2]	-895	[2]
Amortization of actuarial loss(2)	1,572	[2]	824	[2]
Total other comprehensive loss	-14,621		-3,710
Comprehensive income	$169,015		$238,844
[1]	See Note 8–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]	See Note 6–Employee Benefit Plans for details of the changes in employee benefit plan assets and benefit obligations recognized in AOCL.

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
ASSETS
Cash and cash equivalents	$52,813	$17,063
Trade accounts receivable (less allowance for doubtful accounts of $0 and $20 at December 31, 2014 and March 31, 2015, respectively)	96,700	84,465
Other accounts receivable	15,744	15,711
Inventory	160,949	157,762
Energy commodity derivatives contracts, net	36,725	87,151
Energy commodity derivatives deposits	1,100	6,184
Other current assets	31,619	34,331
Total current assets	395,650	402,667
Property, plant and equipment	5,642,904	5,533,935
Less: Accumulated depreciation	1,243,310	1,204,601
Net property, plant and equipment	4,399,594	4,329,334
Investments in non-controlled entities	636,618	613,867
Long-term receivables	27,116	28,611
Goodwill	53,260	53,260
Other intangibles (less accumulated amortization of $11,526 and $12,206 at December 31, 2014 and March 31, 2015, respectively)	3,893	4,573
Debt placement costs (less accumulated amortization of $8,952 and $9,539 at December 31, 2014 and March 31, 2015, respectively)	22,158	18,084
Tank bottoms and linefill	38,361	42,585
Other noncurrent assets	28,467	24,304
Total assets	5,605,117	5,517,285
LIABILITIES AND PARTNERS' CAPITAL
Accounts payable	91,022	97,131
Accrued payroll and benefits	31,719	48,298
Accrued interest payable	45,800	45,973
Accrued taxes other than income	42,087	47,888
Environmental liabilities	11,926	10,564
Deferred revenue	75,920	71,142
Accrued product purchases	37,953	44,355
Energy commodity derivatives contracts, net	814	5,413
Energy commodity derivatives deposits	31,512	84,463
Other current liabilities	50,134	80,928
Total current liabilities	418,887	536,155
Long-term debt	3,183,750	2,982,895
Long-term pension and benefits	80,741	75,155
Other noncurrent liabilities	23,427	29,069
Environmental liabilities	24,431	25,778
Commitments and contingencies
Partners’ capital:
Limited partner unitholders (227,068 units and 227,426 units outstanding at December 31, 2014 and March 31, 2015, respectively)	1,970,042	1,949,773
Accumulated other comprehensive loss	-96,161	-81,540
Total partners’ capital	1,873,881	1,868,233
Total liabilities and partners' capital	$5,605,117	$5,517,285

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, except Share data, unless otherwise specified
Allowance for Doubtful Accounts Receivable, Current	$20	$0
Other intangibles, accumulated amortization	12,206	11,526
Debt placement costs, accumulated amortization	$9,539	$8,952
Limited partner unitholders, units outstanding	227,426,329	227,068,257

Consolidated_Statements_Of_Cas

Consolidated Statements Of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Operating Activities:
Net income	$183,636	$242,554
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	41,697	37,511
Debt placement fee amortization expense	587	599
Loss on sale and retirement of assets	-3	1,205
Earnings of non-controlled entities	-9,590	-466
Distributions from investments in non-controlled entities	9,229	384
Equity-based incentive compensation expense	4,751	5,088
Amortization of prior service credit and actuarial loss	644	-71
Changes in operating assets and liabilities:
Trade accounts receivable and other accounts receivable	-12,194	15,022
Inventory	-3,187	-23,011
Energy commodity derivatives contracts, net of derivatives deposits	-5,804	-529
Accounts payable	-4,351	2,960
Accrued payroll and benefits	-16,579	-14,552
Accrued interest payable	-173	5,194
Accrued taxes other than income	-5,801	-7,479
Accrued product purchases	-6,402	-19,978
Deferred revenue	4,778	1,448
Current and noncurrent environmental liabilities	15	-1,393
Other current and noncurrent assets and liabilities	9,830	25,588
Net cash provided by operating activities	191,083	270,074
Investing Activities:
Additions to property, plant and equipment	-128,517	-75,514
Proceeds from sale and disposition of assets	3,089	42
Investments in non-controlled entities	-13,751	-127,698
Distributions in excess of earnings of non-controlled entities	4,613	687
Net cash used by investing activities	-134,566	-202,483
Financing Activities:
Distributions paid	-158,061	-132,835
Net commercial paper repayments	-296,942	0
Borrowings under long-term notes	499,589	257,713
Debt placement costs	-4,661	-2,648
Net payment on financial derivatives	-42,908	-3,613
Settlement of tax withholdings on long-term incentive compensation	-17,784	-14,813
Net cash provided (used) by financing activities	-20,767	103,804
Change in cash and cash equivalents	35,750	171,395
Cash and cash equivalents at beginning of period	17,063	25,235
Cash and cash equivalents at end of period	52,813	196,630
Supplemental non-cash financing activities:
Contribution of Property	13,252	0
Issuance of limited partner units in settlement of equity-based incentive plan awards	8,045	7,315
Additions to property, plant and equipment	-127,709	-70,295
Increase (Decrease) in Other Accounts Payable	-808	-5,219
Additions to property, plant and equipment	($128,517)	($75,514)

Organization_Description_of_Bu

Organization, Description of Business And Basis Of Presentation	3 Months Ended
	Mar. 31, 2015
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 March 31, 2015, our asset portfolio, including the assets of our joint ventures, consisted of:
	•	our refined products segment, comprised of our 9,500-mile refined products pipeline system with 52 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 1,600 miles of crude oil pipelines and storage facilities with an aggregate storage capacity of approximately 21 million barrels, of which 12 million barrels are 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 26 million barrels.
	Products transported, stored and distributed through our pipelines and terminals include:
	•	refined products 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 are produced as by-products of the crude oil refining process and in connection with natural gas production. LPGs include butane and propane;
	•	blendstocks 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 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 are used as feedstocks by refineries and petrochemical facilities;
	•	biofuels, such as ethanol and biodiesel, are increasingly required by government mandates; and
	•	ammonia 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, 2014 which is derived from our audited financial statements, include all normal and recurring adjustments necessary to present fairly our financial position as of March 31, 2015, the results of operations for the three months ended March 31, 2014 and 2015 and cash flows for the three months ended March 31, 2014 and 2015. The results of operations for the three months ended March 31, 2015 are not necessarily indicative of the results to be expected for the full year ending December 31, 2015 as profits from our blending activities are realized largely during the first and fourth quarters of each year. Additionally, gasoline demand, which drives transportation volumes and revenues on our pipeline systems, generally trends higher during the summer driving months. Further, the volatility of commodity prices impact the profits from our commodity activities and, to a lesser extent, the volume of petroleum products we ship on our pipelines.
	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, 2014.

Product_Sales_Revenues

Product Sales Revenues	3 Months Ended
	Mar. 31, 2015
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. See Note 8 – Derivative Financial Instruments for a discussion of our commodity hedging strategies and how our NYMEX contracts impact product sales revenues.
	For the three months ended March 31, 2014 and 2015, product sales revenue included the following (in thousands):
		Three Months Ended
		March 31,
		2014		2015
	Physical sale of petroleum products	$	293,240	$	169,247
	NYMEX contract adjustments:
	Change in value of NYMEX contracts that were not designated as hedging instruments associated with our butane blending and fractionation activities(1)	2,823		3,880
	Total product sales revenue	$	296,063	$	173,127
	(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	3 Months Ended
	Mar. 31, 2015
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.
	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 March 31, 2014
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	210,236	$	67,903		$	39,498		$	—		$	317,637
	Product sales revenue	293,710		—			2,353			—			296,063
	Affiliate management fee revenue	—		4,595			311			—			4,906
	Total revenue	503,946		72,498			42,162			—			618,606
	Operating expenses	51,157		9,058			14,086			(804		)	73,497
	Cost of product sales	197,756		—			284			—			198,040
	Losses (earnings) of non-controlled entities	—		180			(646		)	—			(466		)
	Operating margin	255,033		63,260			28,438			804			347,535
	Depreciation and amortization expense	23,172		6,463			7,072			804			37,511
	G&A expenses	23,019		5,994			5,922			—			34,935
	Operating profit	$	208,842	$	50,803		$	15,444		$	—		$	275,089
		Three Months Ended March 31, 2015
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	216,777	$	86,560		$	42,263		$	—		$	345,600
	Product sales revenue	172,639		—			488			—			173,127
	Affiliate management fee revenue	—		3,027			336			—			3,363
	Total revenue	389,416		89,587			43,087			—			522,090
	Operating expenses	70,306		13,861			15,335			(1,007		)	98,495
	Cost of product sales	135,634		—			545			—			136,179
	Losses (earnings) of non-controlled entities	55		(8,924		)	(721		)	—			(9,590		)
	Operating margin	183,421		84,650			27,928			1,007			297,006
	Depreciation and amortization expense	23,447		8,229			9,014			1,007			41,697
	G&A expenses	22,599		8,086			4,813			—			35,498
	Operating profit	$	137,375	$	68,335		$	14,101		$	—		$	219,811

Investments_in_NonControlled_E

Investments in Non-Controlled Entities (Notes)	3 Months Ended
	Mar. 31, 2015
Equity Method Investments and Joint Ventures [Abstract]
Investments in Non-Controlled Entities	Investments in Non-Controlled Entities
	Recently-Formed Companies
	Saddlehorn Pipeline Company, LLC ("Saddlehorn"), which was formed during first quarter 2015, will own an approximate 550-mile pipeline to deliver various grades of crude oil from the DJ Basin, and potentially the broader Rocky Mountain production area, to Cushing, Oklahoma. We have a 40% equity ownership interest in Saddlehorn, with Plains All American Pipeline, L.P. and Anadarko Petroleum Corporation having 40% and 20% equity ownership interests, respectively. We will serve as construction manager and operator of the Saddlehorn system. Subject to receipt of necessary permits and regulatory approvals, the Saddlehorn pipeline is expected to be operational during mid-2016.
	Powder Springs Logistics, LLC ("Powder Springs") was recently formed to construct and develop a butane blending system, including 120,000 barrels of butane storage, near Atlanta, Georgia. We have a 50% equity ownership interest in Powder Springs, with an affiliate of Colonial Pipeline Company having the other 50% equity ownership interest. We will serve as construction manager and operator of the Powder Springs facility. This facility is expected to be operational in early 2017.
	Our investments in non-controlled entities at March 31, 2015 are comprised of:
	Entity	Ownership Interest
	BridgeTex Pipeline Company, LLC ("BridgeTex")	50%
	Double Eagle Pipeline LLC ("Double Eagle")	50%
	Osage Pipe Line Company, LLC ("Osage")	50%
	Powder Springs Logistics, LLC	50%
	Saddlehorn Pipeline Company, LLC	40%
	Texas Frontera, LLC ("Texas Frontera")	50%
	The management fees we receive from Texas Frontera, Powder Springs, Saddlehorn and BridgeTex are reported as affiliate management fee revenue on our consolidated statements of income.  For the three months ended March 31, 2014 and 2015, we received throughput revenue from Double Eagle of $0.5 million and $0.9 million, respectively, which we recognized as transportation and terminals revenue.  At December 31, 2014, we recognized a $0.3 million trade accounts receivable from Double Eagle and at December 31, 2014 and March 31, 2015, we had recognized liabilities of $2.2 million and $1.5 million, respectively, to BridgeTex for pre-paid construction management fees.
	In November 2014, we entered into a long-term agreement with BridgeTex for capacity on our Houston area crude oil distribution system. We recognized $8.4 million of revenue from this agreement in first quarter 2015, which we included in transportation and terminals revenue on our consolidated statements of income. We recognized a $2.6 million receivable from BridgeTex at December 31, 2014 associated with this agreement.
	The financial results from Texas Frontera are included in our marine storage segment, the financial results from Osage, Double Eagle, BridgeTex and Saddlehorn are included in our crude oil segment and the financial results from Powder Springs are included in our refined products segment as earnings/losses of non-controlled entities.
	A summary of our investments in non-controlled entities follows (in thousands):
		BridgeTex			All Others			Consolidated
	Investments at December 31, 2014	$	489,348		$	124,519		$	613,867
	Additional investment	7,358			19,645			27,003
	Earnings of non-controlled entities:
	Proportionate share of earnings	9,019			1,269			10,288
	Amortization of excess investment and capitalized interest	(510		)	(188		)	(698		)
	Earnings of non-controlled entities	8,509			1,081			9,590
	Less:
	Distributions of earnings from investments in non-controlled entities	8,509			720			9,229
	Distributions in excess of earnings of non-controlled entities	4,565			48			4,613
	Investments at March 31, 2015	$	492,141		$	144,477		$	636,618
	Summarized financial information of our non-controlled entities as of and for the three months ended March 31, 2015 follows (in thousands):
		BridgeTex			All Others			Consolidated
	Current assets	$	50,901		$	21,535		$	72,436
	Noncurrent assets	822,132			252,542			1,074,674
	Total assets	$	873,033		$	274,077		$	1,147,110
	Current liabilities	$	49,618		$	11,019		$	60,637
	Noncurrent liabilities	236			1,785			2,021
	Total liabilities	$	49,854		$	12,804		$	62,658
	Equity	$	823,179		$	261,273		$	1,084,452
	Revenue	$	37,136		$	9,520		$	46,656
	Net income	$	18,037		$	2,581		$	20,618

Inventory

Inventory	3 Months Ended
	Mar. 31, 2015
Inventory Disclosure [Abstract]
Inventory	Inventory
	Inventory at December 31, 2014 and March 31, 2015 was as follows (in thousands):
		December 31, 2014		March 31,
				2015
	Refined products	$	67,055	$	68,279
	Liquefied petroleum gases	37,642		38,772
	Transmix	36,867		33,721
	Crude oil	10,015		14,068
	Additives	6,183		6,109
	Total inventory	$	157,762	$	160,949

Employee_Benefit_Plans

Employee Benefit Plans	3 Months Ended
	Mar. 31, 2015
Compensation and Retirement Disclosure [Abstract]
Employee Benefit Plans	Employee Benefit Plans
	We sponsor two pension plans for certain union employees and a pension plan primarily for non-union 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 months ended March 31, 2014 and 2015 (in thousands):
		Three Months Ended								Three Months Ended
		31-Mar-14								March 31, 2015
		Pension				Other  Post-				Pension				Other  Post-
		Benefits				Retirement				Benefits				Retirement
						Benefits								Benefits
	Components of net periodic benefit costs:
	Service cost	$	3,352			$	67			$	4,470			$	66
	Interest cost	1,659				114				1,869				110
	Expected return on plan assets	(1,697		)		—				(1,896		)		—
	Amortization of prior service cost (credit)	33				(928		)		—				(928		)
	Amortization of actuarial loss	629				195				1,347				225
	Net periodic benefit cost (credit)	$	3,976			$	(552	)		$	5,790			$	(527	)
	Contributions estimated to be paid into the plans in 2015 are $21.1 million and $1.1 million for the pension and postretirement benefit plans, respectively.
	We match our employee's qualifying contributions to our defined contribution plan, resulting in expense to us. Expenses related to the defined contribution plan were $2.6 million and $2.8 million for the three months ended March 31, 2014 and 2015, respectively.
	Amounts Included in AOCL
	The changes in AOCL related to employee benefit plan assets and benefit obligations for the three months ended March 31, 2014 and 2015 were as follows:
			Three Months Ended								Three Months Ended
			31-Mar-14								31-Mar-15
	Gains (Losses) Included in AOCL		Pension Benefits				Other Postretirement Benefits				Pension Benefits				Other Postretirement Benefits
	Beginning balance		$	(36,184	)		$	3,053			$	(63,257	)		$	(1,696	)
	Amortization of prior service credit		33				(928		)		—				(928		)
	Amortization of actuarial loss		629				195				1,347				225
	Ending balance		$	(35,522	)		$	2,320			$	(61,910	)		$	(2,399	)

Debt

Debt	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Debt	Debt
	Consolidated debt at December 31, 2014 and March 31, 2015 was as follows (in thousands, except as otherwise noted):
			December 31, 2014		March 31,		Weighted-Average
					2015		Interest Rate for the Three Months Ended March 31, 2015 (1)
	Commercial paper(2)		$	296,942	$	—	0.50%
	$250.0 million of 5.65% Notes due 2016		250,758		250,652		5.70%
	$250.0 million of 6.40% Notes due 2018		257,280		256,764		5.40%
	$550.0 million of 6.55% Notes due 2019		567,868		566,939		5.70%
	$550.0 million of 4.25% Notes due 2021		556,304		556,071		4.00%
	$250.0 million of 3.20% Notes due 2025(2)		—		249,680		3.20%
	$250.0 million of 6.40% Notes due 2037		249,017		249,021		6.40%
	$250.0 million of 4.20% Notes due 2042		248,406		248,414		4.20%
	$550.0 million of 5.15% Notes due 2043		556,320		556,296		5.10%
	$250.0 million of 4.20% Notes due 2045(2)		—		249,913		4.60%
	Total debt		$	2,982,895	$	3,183,750	4.70%
	-1	Weighted-average interest rate includes the amortization/accretion of discounts, premiums and gains/losses realized on historical cash flow and fair value hedges recognized as interest expense.
	-2	These borrowings were outstanding for only a portion of the three month period ending March 31, 2015. 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, 2014 and March 31, 2015 was $2.9 billion and $3.2 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.
	2015 Debt Offerings
	In March 2015, we issued $250.0 million of our 3.20% notes due 2025 in an underwritten public offering. The notes were issued at 99.871% of par. Net proceeds from this offering were approximately $247.6 million, after underwriting discounts and offering expenses of $2.1 million.
	Also in March 2015, we issued $250.0 million of our 4.20% notes due 2045 in an underwritten public offering. The notes were issued at 99.965% of par. Net proceeds from this offering were approximately $247.3 million, after underwriting discounts and offering expenses of $2.6 million.
	The net proceeds from these offerings were used to repay borrowings outstanding under our commercial paper program 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 March 31, 2015. Borrowings under this facility may be used for general partnership purposes, including capital expenditures. As of March 31, 2015, 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. The maturities of our 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 and is, therefore, classified as long-term debt. As of March 31, 2015, there were no commercial paper borrowings outstanding.

Derivative_Financial_Instrumen

Derivative Financial Instruments

3 Months Ended

Mar. 31, 2015

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 2015, we entered into a $50.0 million forward-starting interest rate swap agreement to hedge against the risk of variability of future interest payments on a portion of debt we anticipate issuing in 2016. The fair value of this contract at March 31, 2015 was recorded on our balance sheet as an other noncurrent asset of $1.0 million. We account for this agreement as a cash flow hedge.

In third and fourth quarter of 2014, we entered into $250.0 million of forward-starting interest rate swap agreements to hedge against the risk of variability of future interest payments on a portion of debt we anticipated issuing in 2015. We accounted for these agreements as cash flow hedges. When we issued the $250.0 million of 4.20% notes due 2045 in first quarter 2015, we settled the associated interest rate swap agreements for a loss of $42.9 million. The loss was recorded to other comprehensive income ($26.5 million and $16.4 million recorded in 2014 and 2015, respectively) and will be 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 interest payments on an anticipated debt issuance, which was completed during first quarter 2015. The effective portion of this gain in the amount of $10.6 million at March 31, 2015 will be recognized into earnings as an adjustment to our periodic interest expense over the life of the $250.0 million of 4.20% notes due 2045 that were issued in first quarter 2015.

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 Chicago Mercantile Exchange ("CME") butane futures agreements to help manage commodity price changes, which is intended to mitigate the risk of decline in the product margin realized from our butane blending activities that we choose to hedge. Further, certain of our other commercial operations generate petroleum products. We use NYMEX contracts to hedge against future price changes for some of these commodities.

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 March 31, 2015, we had commitments under these forward purchase and sale contracts as follows (in millions):

Notional Value

Barrels

Forward purchase contracts

$

72.8

1.8

Forward sale contracts

$

4.5

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 Accounting Standards Codification ("ASC") 815, Derivatives and Hedging.

Changes in the fair value of these agreements are recognized currently in earnings.

During the three months ended March 31, 2014 and 2015, none of the commodity hedging contracts we entered into qualified for or were designated as cash flow hedges.

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 as discussed 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 CME-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.

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.

Additionally, we hold crude oil barrels that we use for operational purposes which we classify as long-term assets on our balance sheet and which are reported as tank bottom and linefill assets. We use NYMEX contracts to hedge against changes in the price of these crude oil barrels. We record the effective portion of the gains or losses for those contracts that qualify as fair value hedges as adjustments to the assets being hedged and the ineffective portions as well as amounts excluded from the assessment of hedge effectiveness as adjustments to other income or expense.

As outlined in the table below, our open NYMEX contracts and CME butane futures agreements at March 31, 2015 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 December 2015 and November 2016

NYMEX - Economic Hedges(1)

3.2 million barrels of refined products and crude oil

Between April 2015 and January 2016

CME Butane Futures Agreements - Economic Hedges

0.3 million barrels of butane

Between April and December 2015

(1) Of the 3.2 million barrels of products we have economically hedged at March 31, 2015, we had open agreements which swap the pricing on 0.1 million of those barrels from New York harbor to Platts Group 3 or Platts Gulf Coast, which are the geographic locations where these barrels will be sold.

Energy Commodity Derivatives Contracts and Deposits Offsets

At March 31, 2015, we had received margin deposits of $31.5 million for our NYMEX and CME contracts with one of our counterparties, which were recorded as a current liability under energy commodity derivatives deposits on our consolidated balance sheet. Additionally, we made margin deposits of $1.1 million for our CME contracts with a second counterparty, 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 CME butane futures agreements against our margin deposits under a master netting arrangement for each counterparty; however, we have elected to present the combined fair values of our open NYMEX and CME 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 CME 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, 2014 and March 31, 2015 (in thousands):

31-Dec-14

Description

Gross Amounts of Recognized Assets

Gross Amounts of Liabilities Offset in the Consolidated Balance Sheet

Net Amounts of Assets Presented in the Consolidated Balance Sheet(1)

Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet

Net Asset Amount(3)

Energy commodity derivatives

$

106,764

$

(10,622

)

$

96,142

$

(78,279

)

$

17,863

31-Mar-15

Description

Gross Amounts of Recognized Assets

Gross Amounts of Liabilities Offset in the Consolidated Balance Sheet

Net Amounts of Assets Presented in the Consolidated Balance Sheet(2)

Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet

Net Asset Amount(3)

Energy commodity derivatives

$

55,770

$

(1,691

)

$

54,079

$

(30,412

)

$

23,667

-1

Net amount includes energy commodity derivative contracts classified as current assets, net, of $87,151, current liabilities of $5,413 and noncurrent assets of $14,404.

-2

Net amount includes energy commodity derivative contracts classified as current assets, net, of $36,725, current liabilities of $814 and noncurrent assets of $18,168.

-3

This represents the maximum amount of loss we would incur if our counterparties failed to perform on their derivative contracts.

Impact of Derivatives on Our Financial Statements

Comprehensive Income

The changes in derivative activity included in AOCL for the three months ended March 31, 2014 and 2015 were as follows (in thousands):

Three Months Ended March 31,

Derivative Gains (Losses) Included in AOCL

2014

2015

Beginning balance

$

13,627

$

(16,587

)

Net loss on interest rate contract cash flow hedges

(3,613

)

(15,465

)

Reclassification of net loss (gain) on cash flow hedges to income

(26

)

200

Ending balance

$

9,988

$

(31,852

)

The following tables provide a summary of the effect on our consolidated statements of income for the three months ended March 31, 2014 and 2015 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 March 31, 2014

Amount of Loss 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

$

(3,613

)

Interest expense

$

26

$

—

Three Months Ended March 31, 2015

Amount of Loss Recognized in AOCL on Derivative

Location of Loss Reclassified from AOCL into  Income

Amount of Loss Reclassified from AOCL into Income

Derivative Instrument

Effective Portion

Ineffective Portion

Interest rate contracts

$

(15,465

)

Interest expense

$

(200

)

$

—

As of March 31, 2015, the net loss estimated to be classified to interest expense over the next twelve months from AOCL is approximately $1.5 million.

Income Statement

The following table provides a summary of the effect on our consolidated statements of income for the three months ended March 31, 2014 and 2015 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

Three Months Ended

Location of Gain (Loss)

March 31,

Derivative Instrument

Recognized on Derivative

2014

2015

NYMEX commodity contracts

Product sales revenue

$

2,823

$

3,880

NYMEX commodity contracts

Operating expenses

365

1,303

CME butane futures agreements

Cost of product sales

144

(1,224

)

Total

$

3,332

$

3,959

The impact of the derivatives in the above table was reflected as cash from operations on our consolidated statements of cash flows.

During 2014 and 2015, we had open NYMEX contracts on 0.7 million barrels of crude oil that were designated as fair value hedges. Because there was no ineffectiveness recognized on these hedges, the cumulative gains at December 31, 2014 and March 31, 2015 of $13.3 million and $17.5 million, respectively, from the agreements were offset by a cumulative decrease to tank bottoms and linefill. We exclude the differential between the current spot price and forward price from our assessment of hedge effectiveness for these fair value hedges. For the three months ended March 31, 2015, we recognized a loss of $0.3 million for the amounts we excluded from the assessment of effectiveness of these fair value hedges, which we reported as other expense on our consolidated statements of income.

Balance Sheet

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, 2014 and March 31, 2015 (in thousands):

December 31, 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

$

360

Energy commodity derivatives contracts, net

$

—

NYMEX commodity contracts

Other noncurrent assets

14,404

Other noncurrent liabilities

—

Interest rate contracts

Other current assets

—

Other current liabilities

26,478

Total

$

14,764

Total

$

26,478

March 31, 2015

Asset Derivatives

Liability Derivatives

Derivative Instrument

Balance Sheet Location

Fair Value

Balance Sheet Location

Fair Value

NYMEX commodity contracts

Energy commodity derivatives contracts, net

$

541

Energy commodity derivatives contracts, net

$

—

NYMEX commodity contracts

Other noncurrent assets

18,168

Other noncurrent liabilities

—

Interest rate contracts

Other noncurrent assets

965

Other noncurrent liabilities

—

Total

$

19,674

Total

$

—

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, 2014 and March 31, 2015 (in thousands):

December 31, 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

$

92,000

Energy commodity derivatives contracts, net

$

—

CME butane futures agreements

Energy commodity derivatives contracts, net

—

Energy commodity derivatives contracts, net

10,622

Total

$

92,000

Total

$

10,622

March 31, 2015

Asset Derivatives

Liability Derivatives

Derivative Instrument

Balance Sheet Location

Fair Value

Balance Sheet Location

Fair Value

NYMEX commodity contracts

Energy commodity derivatives contracts, net

$

37,061

Energy commodity derivatives contracts, net

$

13

CME butane futures agreements

Energy commodity derivatives contracts, net

—

Energy commodity derivatives contracts, net

1,678

Total

$

37,061

Total

$

1,691

Commitments_And_Contingencies

Commitments And Contingencies	3 Months Ended
	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies
	Environmental Liabilities
	Liabilities recognized for estimated environmental costs were $36.3 million and $36.4 million at December 31, 2014 and March 31, 2015, 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 months ended March 31, 2014 and 2015 were $0.3 million and $1.4 million, respectively.
	Environmental Receivables
	Receivables from insurance carriers and other third parties related to environmental matters at December 31, 2014 were $5.1 million, of which $1.3 million and $3.8 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 March 31, 2015 were $5.0 million, of which $1.2 million and $3.8 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheet.
	Other
	We are a party to various other claims, legal actions and complaints arising in the ordinary course of business, including without limitation those disclosed in Item 1, Legal Proceedings of Part II of this report on Form 10-Q. While the results cannot be predicted with certainty, management believes the ultimate resolution of these claims, legal actions and complaints after consideration of amounts accrued, insurance coverage or other indemnification arrangements will not have a material adverse effect on our results of operations, financial position or cash flows.

LongTerm_Incentive_Plan

Long-Term Incentive Plan	3 Months Ended
	Mar. 31, 2015
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 March 31, 2015 total 1.0 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
		March 31, 2014
		Equity		Liability		Total
		Method		Method
	Performance-based awards:
	2012 awards	$	1,022	$	924	$	1,946
	2013 awards	1,181		548		1,729
	2014 awards	904		—		904
	Retention awards	509		—		509
	Total	$	3,616	$	1,472	$	5,088
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense					$	4,974
	Operating expense					114
	Total					$	5,088
		Three Months Ended
		31-Mar-15
		Equity		Liability		Total
		Method		Method
	Performance/market-based awards:
	2013 awards	$	1,519	$	215	$	1,734
	2014 awards	1,623		—		1,623
	2015 awards	1,019		—		1,019
	Retention awards	375		—		375
	Total	$	4,536	$	215	$	4,751
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense					$	4,689
	Operating expense					62
	Total					$	4,751
	In February 2015, 166,189 phantom unit awards were issued pursuant to our LTIP. These grants included both performance-based and retention awards and have a three-year vesting period.
	In January 2015, we issued 358,072 limited partner units, of which 354,529 were issued to settle unit award grants to certain employees that vested on December 31, 2014 and 3,543 were issued to settle the equity-based retainer paid to certain members of our general partner's board of directors.

Distributions

Distributions	3 Months Ended
	Mar. 31, 2015
Distributions Made to Members or Limited Partners [Abstract]
Distributions	Distributions
	Distributions we paid during 2014 and 2015 were as follows (in thousands, except per unit amounts):
	Payment Date	Per Unit Cash			Total Cash Distribution to Limited Partners
		Distribution
		Amount
	2/14/14		$	0.585		$	132,835
	5/15/14		0.6125			139,079
	8/14/14		0.64			145,324
	11/14/14		0.6675			151,568
	Total		$	2.505		$	568,806
	2/13/15		$	0.695		$	158,061
	5/15/2015(1)		0.7175			163,178
	Total		$	1.4125		$	321,239
	(1) Our general partner's board of directors declared this cash distribution on April 23, 2015 to be paid on May 15, 2015 to unitholders of record at the close of business on May 4, 2015.

Fair_Value

Fair Value	3 Months Ended
	Mar. 31, 2015
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 CME exchange-traded butane futures agreements related to petroleum products. These contracts are carried at fair value on our consolidated balance sheets and are valued based on quoted prices in active markets. See Note 8 – Derivative Financial Instruments for further disclosures regarding these contracts.
	•	Interest rate contracts. These include forward-starting interest rate swap agreements to hedge against the risk of variability of interest payments on future debt. These contracts are carried at fair value on our consolidated balance sheets and are valued based on an assumed exchange, at the end of each period, in an orderly transaction with a market participant in the market in which the financial instrument is traded. The exchange value was calculated using present value techniques on estimated future cash flows based on forward interest rate curves. See Note 8 – 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, 2014 and March 31, 2015; 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, 2014 and March 31, 2015, based on the three levels established by ASC 820; Fair Value Measurements and Disclosures (in thousands):
			As of December 31, 2014
	Assets (Liabilities)								Fair Value Measurements using:
			Carrying Amount			Fair Value			Quoted Prices  in Active Markets		Significant			Significant
									for Identical		Other			Unobservable
									Assets		Observable			Inputs
									(Level 1)		Inputs			(Level 3)
											(Level 2)
	Energy commodity derivatives contracts – assets		$	96,142		$	96,142		$	96,142	$	—		$	—
	Interest rate contracts – liabilities		$	(26,478	)	$	(26,478	)	$	—	$	(26,478	)	$	—
	Long-term receivables		$	28,611		$	30,200		$	—	$	—		$	30,200
	Debt		$	(2,982,895	)	$	(3,212,462	)	$	—	$	(3,212,462	)	$	—
			As of March 31, 2015
	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 – assets		$	54,079		$	54,079		$	54,079	$	—		$	—
	Interest rate contracts – assets		$	965		$	965		$	—	$	965		$	—
	Long-term receivables		$	27,116		$	28,820		$	—	$	—		$	28,820
	Debt		$	(3,183,750	)	$	(3,481,995	)	$	—	$	(3,481,995	)	$	—

Related_Party_Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2015
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 the general partner 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 March 31, 2014 and 2015, we made purchases of butane from subsidiaries of Targa of $12.2 million and $8.8 million, respectively. These purchases were based on the then-current index prices. We had recognized payables to Targa of $0.9 million and $1.5 million at December 31, 2014 and March 31, 2015, respectively.
	See Note 4 – Investments in Non-Controlled Entities for a discussion of affiliate joint venture transactions we account for under the equity method.

Subsequent_Events

Subsequent Events	3 Months Ended
	Mar. 31, 2015
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events
	Recognizable events
	No recognizable events occurred subsequent to March 31, 2015.
	Non-recognizable events
	In April 2015, our general partner's board of directors declared a quarterly distribution of $0.7175 per unit to be paid on May 15, 2015 to unitholders of record at the close of business on May 4, 2015. The total cash distributions expected to be paid under this declaration are approximately $163.2 million.

Product_Sales_Revenues_Tables

Product Sales Revenues (Tables)	3 Months Ended
	Mar. 31, 2015
Product Sales Revenue [Abstract]
Components of Product Sales Revenues	For the three months ended March 31, 2014 and 2015, product sales revenue included the following (in thousands):
		Three Months Ended
		March 31,
		2014		2015
	Physical sale of petroleum products	$	293,240	$	169,247
	NYMEX contract adjustments:
	Change in value of NYMEX contracts that were not designated as hedging instruments associated with our butane blending and fractionation activities(1)	2,823		3,880
	Total product sales revenue	$	296,063	$	173,127
	(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)	3 Months Ended
	Mar. 31, 2015
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 March 31, 2014
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	210,236	$	67,903		$	39,498		$	—		$	317,637
	Product sales revenue	293,710		—			2,353			—			296,063
	Affiliate management fee revenue	—		4,595			311			—			4,906
	Total revenue	503,946		72,498			42,162			—			618,606
	Operating expenses	51,157		9,058			14,086			(804		)	73,497
	Cost of product sales	197,756		—			284			—			198,040
	Losses (earnings) of non-controlled entities	—		180			(646		)	—			(466		)
	Operating margin	255,033		63,260			28,438			804			347,535
	Depreciation and amortization expense	23,172		6,463			7,072			804			37,511
	G&A expenses	23,019		5,994			5,922			—			34,935
	Operating profit	$	208,842	$	50,803		$	15,444		$	—		$	275,089
		Three Months Ended March 31, 2015
		(in thousands)
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
	Transportation and terminals revenue	$	216,777	$	86,560		$	42,263		$	—		$	345,600
	Product sales revenue	172,639		—			488			—			173,127
	Affiliate management fee revenue	—		3,027			336			—			3,363
	Total revenue	389,416		89,587			43,087			—			522,090
	Operating expenses	70,306		13,861			15,335			(1,007		)	98,495
	Cost of product sales	135,634		—			545			—			136,179
	Losses (earnings) of non-controlled entities	55		(8,924		)	(721		)	—			(9,590		)
	Operating margin	183,421		84,650			27,928			1,007			297,006
	Depreciation and amortization expense	23,447		8,229			9,014			1,007			41,697
	G&A expenses	22,599		8,086			4,813			—			35,498
	Operating profit	$	137,375	$	68,335		$	14,101		$	—		$	219,811

Investments_in_NonControlled_E1

Investments in Non-Controlled Entities (Tables)	3 Months Ended
	Mar. 31, 2015
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Our investments in non-controlled entities at March 31, 2015 are comprised of:
	Entity	Ownership Interest
	BridgeTex Pipeline Company, LLC ("BridgeTex")	50%
	Double Eagle Pipeline LLC ("Double Eagle")	50%
	Osage Pipe Line Company, LLC ("Osage")	50%
	Powder Springs Logistics, LLC	50%
	Saddlehorn Pipeline Company, LLC	40%
	Texas Frontera, LLC ("Texas Frontera")	50%
	The management fees we receive from Texas Frontera, Powder Springs, Saddlehorn and BridgeTex are reported as affiliate management fee revenue on our consolidated statements of income.  For the three months ended March 31, 2014 and 2015, we received throughput revenue from Double Eagle of $0.5 million and $0.9 million, respectively, which we recognized as transportation and terminals revenue.  At December 31, 2014, we recognized a $0.3 million trade accounts receivable from Double Eagle and at December 31, 2014 and March 31, 2015, we had recognized liabilities of $2.2 million and $1.5 million, respectively, to BridgeTex for pre-paid construction management fees.
	In November 2014, we entered into a long-term agreement with BridgeTex for capacity on our Houston area crude oil distribution system. We recognized $8.4 million of revenue from this agreement in first quarter 2015, which we included in transportation and terminals revenue on our consolidated statements of income. We recognized a $2.6 million receivable from BridgeTex at December 31, 2014 associated with this agreement.
	The financial results from Texas Frontera are included in our marine storage segment, the financial results from Osage, Double Eagle, BridgeTex and Saddlehorn are included in our crude oil segment and the financial results from Powder Springs are included in our refined products segment as earnings/losses of non-controlled entities.
	A summary of our investments in non-controlled entities follows (in thousands):
		BridgeTex			All Others			Consolidated
	Investments at December 31, 2014	$	489,348		$	124,519		$	613,867
	Additional investment	7,358			19,645			27,003
	Earnings of non-controlled entities:
	Proportionate share of earnings	9,019			1,269			10,288
	Amortization of excess investment and capitalized interest	(510		)	(188		)	(698		)
	Earnings of non-controlled entities	8,509			1,081			9,590
	Less:
	Distributions of earnings from investments in non-controlled entities	8,509			720			9,229
	Distributions in excess of earnings of non-controlled entities	4,565			48			4,613
	Investments at March 31, 2015	$	492,141		$	144,477		$	636,618
	Summarized financial information of our non-controlled entities as of and for the three months ended March 31, 2015 follows (in thousands):
		BridgeTex			All Others			Consolidated
	Current assets	$	50,901		$	21,535		$	72,436
	Noncurrent assets	822,132			252,542			1,074,674
	Total assets	$	873,033		$	274,077		$	1,147,110
	Current liabilities	$	49,618		$	11,019		$	60,637
	Noncurrent liabilities	236			1,785			2,021
	Total liabilities	$	49,854		$	12,804		$	62,658
	Equity	$	823,179		$	261,273		$	1,084,452
	Revenue	$	37,136		$	9,520		$	46,656
	Net income	$	18,037		$	2,581		$	20,618

Inventory_Tables

Inventory (Tables)	3 Months Ended
	Mar. 31, 2015
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventory at December 31, 2014 and March 31, 2015 was as follows (in thousands):
		December 31, 2014		March 31,
				2015
	Refined products	$	67,055	$	68,279
	Liquefied petroleum gases	37,642		38,772
	Transmix	36,867		33,721
	Crude oil	10,015		14,068
	Additives	6,183		6,109
	Total inventory	$	157,762	$	160,949

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	3 Months Ended
	Mar. 31, 2015
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 months ended March 31, 2014 and 2015 (in thousands):
		Three Months Ended								Three Months Ended
		31-Mar-14								March 31, 2015
		Pension				Other  Post-				Pension				Other  Post-
		Benefits				Retirement				Benefits				Retirement
						Benefits								Benefits
	Components of net periodic benefit costs:
	Service cost	$	3,352			$	67			$	4,470			$	66
	Interest cost	1,659				114				1,869				110
	Expected return on plan assets	(1,697		)		—				(1,896		)		—
	Amortization of prior service cost (credit)	33				(928		)		—				(928		)
	Amortization of actuarial loss	629				195				1,347				225
	Net periodic benefit cost (credit)	$	3,976			$	(552	)		$	5,790			$	(527	)
Schedule of Amounts Recognized in Other Comprehensive Income (Loss)	The changes in AOCL related to employee benefit plan assets and benefit obligations for the three months ended March 31, 2014 and 2015 were as follows:
			Three Months Ended								Three Months Ended
			31-Mar-14								31-Mar-15
	Gains (Losses) Included in AOCL		Pension Benefits				Other Postretirement Benefits				Pension Benefits				Other Postretirement Benefits
	Beginning balance		$	(36,184	)		$	3,053			$	(63,257	)		$	(1,696	)
	Amortization of prior service credit		33				(928		)		—				(928		)
	Amortization of actuarial loss		629				195				1,347				225
	Ending balance		$	(35,522	)		$	2,320			$	(61,910	)		$	(2,399	)

Debt_Tables

Debt (Tables)	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Consolidated Debt	Consolidated debt at December 31, 2014 and March 31, 2015 was as follows (in thousands, except as otherwise noted):
			December 31, 2014		March 31,		Weighted-Average
					2015		Interest Rate for the Three Months Ended March 31, 2015 (1)
	Commercial paper(2)		$	296,942	$	—	0.50%
	$250.0 million of 5.65% Notes due 2016		250,758		250,652		5.70%
	$250.0 million of 6.40% Notes due 2018		257,280		256,764		5.40%
	$550.0 million of 6.55% Notes due 2019		567,868		566,939		5.70%
	$550.0 million of 4.25% Notes due 2021		556,304		556,071		4.00%
	$250.0 million of 3.20% Notes due 2025(2)		—		249,680		3.20%
	$250.0 million of 6.40% Notes due 2037		249,017		249,021		6.40%
	$250.0 million of 4.20% Notes due 2042		248,406		248,414		4.20%
	$550.0 million of 5.15% Notes due 2043		556,320		556,296		5.10%
	$250.0 million of 4.20% Notes due 2045(2)		—		249,913		4.60%
	Total debt		$	2,982,895	$	3,183,750	4.70%
	-1	Weighted-average interest rate includes the amortization/accretion of discounts, premiums and gains/losses realized on historical cash flow and fair value hedges recognized as interest expense.
	-2	These borrowings were outstanding for only a portion of the three month period ending March 31, 2015. 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)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule Of Forward Purchase And Sales Contracts	As of March 31, 2015, we had commitments under these forward purchase and sale contracts as follows (in millions):
		Notional Value				Barrels
	Forward purchase contracts	$	72.8			1.8
	Forward sale contracts	$	4.5			0.1
Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements	As outlined in the table below, our open NYMEX contracts and CME butane futures agreements at March 31, 2015 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 December 2015 and November 2016
	NYMEX - Economic Hedges(1)		3.2 million barrels of refined products and crude oil		Between April 2015 and January 2016
	CME Butane Futures Agreements - Economic Hedges		0.3 million barrels of butane		Between April and December 2015
	(1) Of the 3.2 million barrels of products we have economically hedged at March 31, 2015, we had open agreements which swap the pricing on 0.1 million of those barrels from New York harbor to Platts Group 3 or Platts Gulf Coast, which are the geographic locations where these barrels will be sold.
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, 2014 and March 31, 2015 (in thousands):
			31-Dec-14
	Description		Gross Amounts of Recognized Assets				Gross Amounts of Liabilities Offset in the Consolidated Balance Sheet				Net Amounts of Assets Presented in the Consolidated Balance Sheet(1)				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet				Net Asset Amount(3)
	Energy commodity derivatives		$	106,764			$	(10,622	)		$	96,142			$	(78,279	)		$	17,863
			31-Mar-15
	Description		Gross Amounts of Recognized Assets				Gross Amounts of Liabilities Offset in the Consolidated Balance Sheet				Net Amounts of Assets Presented in the Consolidated Balance Sheet(2)				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet				Net Asset Amount(3)
	Energy commodity derivatives		$	55,770			$	(1,691	)		$	54,079			$	(30,412	)		$	23,667
	-1	Net amount includes energy commodity derivative contracts classified as current assets, net, of $87,151, current liabilities of $5,413 and noncurrent assets of $14,404.
	-2	Net amount includes energy commodity derivative contracts classified as current assets, net, of $36,725, current liabilities of $814 and noncurrent assets of $18,168.
	-3	This represents the maximum amount of loss we would incur if our counterparties failed to perform on their derivative contracts.
Derivative Gains Included In Accumulated Other Comprehensive Loss (AOCL)	The changes in derivative activity included in AOCL for the three months ended March 31, 2014 and 2015 were as follows (in thousands):
		Three Months Ended March 31,
	Derivative Gains (Losses) Included in AOCL	2014				2015
	Beginning balance	$	13,627			$	(16,587	)
	Net loss on interest rate contract cash flow hedges	(3,613		)		(15,465		)
	Reclassification of net loss (gain) on cash flow hedges to income	(26		)		200
	Ending balance	$	9,988			$	(31,852	)
Derivatives And Hedging-Cash Flow Hedges	The following tables provide a summary of the effect on our consolidated statements of income for the three months ended March 31, 2014 and 2015 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 March 31, 2014
			Amount of Loss 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			$	(3,613	)			Interest expense			$	26					$	—
			Three Months Ended March 31, 2015
			Amount of Loss Recognized in AOCL on Derivative						Location of Loss Reclassified from AOCL into  Income		Amount of Loss Reclassified from AOCL into Income
	Derivative Instrument										Effective Portion						Ineffective Portion
	Interest rate contracts			$	(15,465	)			Interest expense			$	(200	)				$	—
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 March 31, 2014 and 2015 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
					Three Months Ended
			Location of Gain (Loss)		March 31,
	Derivative Instrument		Recognized on Derivative		2014				2015
	NYMEX commodity contracts		Product sales revenue		$	2,823			$	3,880
	NYMEX commodity contracts		Operating expenses		365				1,303
	CME butane futures agreements		Cost of product sales		144				(1,224		)
			Total		$	3,332			$	3,959
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, 2014 and March 31, 2015 (in thousands):
			December 31, 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		$	360			Energy commodity derivatives contracts, net		$	—
	NYMEX commodity contracts		Other noncurrent assets		14,404				Other noncurrent liabilities		—
	Interest rate contracts		Other current assets		—				Other current liabilities		26,478
			Total		$	14,764			Total		$	26,478
			March 31, 2015
			Asset Derivatives						Liability Derivatives
	Derivative Instrument		Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
	NYMEX commodity contracts		Energy commodity derivatives contracts, net		$	541			Energy commodity derivatives contracts, net		$	—
	NYMEX commodity contracts		Other noncurrent assets		18,168				Other noncurrent liabilities		—
	Interest rate contracts		Other noncurrent assets		965				Other noncurrent liabilities		—
			Total		$	19,674			Total		$	—
	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, 2014 and March 31, 2015 (in thousands):
			December 31, 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		$	92,000			Energy commodity derivatives contracts, net		$	—
	CME butane futures agreements		Energy commodity derivatives contracts, net		—				Energy commodity derivatives contracts, net		10,622
			Total		$	92,000			Total		$	10,622
			March 31, 2015
			Asset Derivatives						Liability Derivatives
	Derivative Instrument		Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
	NYMEX commodity contracts		Energy commodity derivatives contracts, net		$	37,061			Energy commodity derivatives contracts, net		$	13
	CME butane futures agreements		Energy commodity derivatives contracts, net		—				Energy commodity derivatives contracts, net		1,678
			Total		$	37,061			Total		$	1,691

LongTerm_Incentive_Plan_Tables

Long-Term Incentive Plan (Tables)	3 Months Ended
	Mar. 31, 2015
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
		March 31, 2014
		Equity		Liability		Total
		Method		Method
	Performance-based awards:
	2012 awards	$	1,022	$	924	$	1,946
	2013 awards	1,181		548		1,729
	2014 awards	904		—		904
	Retention awards	509		—		509
	Total	$	3,616	$	1,472	$	5,088
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense					$	4,974
	Operating expense					114
	Total					$	5,088
		Three Months Ended
		31-Mar-15
		Equity		Liability		Total
		Method		Method
	Performance/market-based awards:
	2013 awards	$	1,519	$	215	$	1,734
	2014 awards	1,623		—		1,623
	2015 awards	1,019		—		1,019
	Retention awards	375		—		375
	Total	$	4,536	$	215	$	4,751
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense					$	4,689
	Operating expense					62
	Total					$	4,751

Distributions_Tables

Distributions (Tables)	3 Months Ended
	Mar. 31, 2015
Distributions Made to Members or Limited Partners [Abstract]
Schedule Of Distributions	Distributions we paid during 2014 and 2015 were as follows (in thousands, except per unit amounts):
	Payment Date	Per Unit Cash			Total Cash Distribution to Limited Partners
		Distribution
		Amount
	2/14/14		$	0.585		$	132,835
	5/15/14		0.6125			139,079
	8/14/14		0.64			145,324
	11/14/14		0.6675			151,568
	Total		$	2.505		$	568,806
	2/13/15		$	0.695		$	158,061
	5/15/2015(1)		0.7175			163,178
	Total		$	1.4125		$	321,239
	(1) Our general partner's board of directors declared this cash distribution on April 23, 2015 to be paid on May 15, 2015 to unitholders of record at the close of business on May 4, 2015.

Fair_Value_Tables

Fair Value (Tables)	3 Months Ended
	Mar. 31, 2015
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, 2014 and March 31, 2015, based on the three levels established by ASC 820; Fair Value Measurements and Disclosures (in thousands):
		As of December 31, 2014
	Assets (Liabilities)							Fair Value Measurements using:
		Carrying Amount			Fair Value			Quoted Prices  in Active Markets		Significant			Significant
								for Identical		Other			Unobservable
								Assets		Observable			Inputs
								(Level 1)		Inputs			(Level 3)
										(Level 2)
	Energy commodity derivatives contracts – assets	$	96,142		$	96,142		$	96,142	$	—		$	—
	Interest rate contracts – liabilities	$	(26,478	)	$	(26,478	)	$	—	$	(26,478	)	$	—
	Long-term receivables	$	28,611		$	30,200		$	—	$	—		$	30,200
	Debt	$	(2,982,895	)	$	(3,212,462	)	$	—	$	(3,212,462	)	$	—
		As of March 31, 2015
	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 – assets	$	54,079		$	54,079		$	54,079	$	—		$	—
	Interest rate contracts – assets	$	965		$	965		$	—	$	965		$	—
	Long-term receivables	$	27,116		$	28,820		$	—	$	—		$	28,820
	Debt	$	(3,183,750	)	$	(3,481,995	)	$	—	$	(3,481,995	)	$	—

Organization_Description_of_Bu1

Organization, Description of Business and Basis of Presentation (Narrative) (Details)	Mar. 31, 2015
	Terminal
Refined Products [Member]
Organization and Description of Business [Line Items]
Number of Pipeline Terminals	52
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	1,600
Storage Capacity	21,000,000
Leaseable Storage Capacity	12,000,000
Marine Storage [Member]
Organization and Description of Business [Line Items]
Number of Independent Terminals	5
Storage Capacity	26,000,000

Product_Sales_Revenues_Compone

Product Sales Revenues (Components Of Product Sales Revenues) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Product Sales Revenue [Abstract]
Physical sale of petroleum products	$169,247		$293,240
NYMEX Adjustments Included in Product Sales	3,880	[1]	2,823	[1]
Total product sales revenue	$173,127		$296,063
[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
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Segment Reporting Information [Line Items]
Transportation and terminals revenue	$345,600	$317,637
Product sales revenue	173,127	296,063
Affiliate management fee revenue	3,363	4,906
Total revenue	522,090	618,606
Operating expenses	98,495	73,497
Cost of product sales	136,179	198,040
Earnings of non-controlled entities	-9,590	-466
Operating margin	297,006	347,535
Depreciation and amortization expense	41,697	37,511
G&A expenses	35,498	34,935
Operating profit	219,811	275,089
Operating Segments [Member] | Refined Products [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue	216,777	210,236
Product sales revenue	172,639	293,710
Affiliate management fee revenue	0	0
Total revenue	389,416	503,946
Operating expenses	70,306	51,157
Cost of product sales	135,634	197,756
Earnings of non-controlled entities	55	0
Operating margin	183,421	255,033
Depreciation and amortization expense	23,447	23,172
G&A expenses	22,599	23,019
Operating profit	137,375	208,842
Operating Segments [Member] | Crude Oil Pipeline and Terminals [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue	86,560	67,903
Product sales revenue	0	0
Affiliate management fee revenue	3,027	4,595
Total revenue	89,587	72,498
Operating expenses	13,861	9,058
Cost of product sales	0	0
Earnings of non-controlled entities	-8,924	180
Operating margin	84,650	63,260
Depreciation and amortization expense	8,229	6,463
G&A expenses	8,086	5,994
Operating profit	68,335	50,803
Operating Segments [Member] | Marine Storage [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue	42,263	39,498
Product sales revenue	488	2,353
Affiliate management fee revenue	336	311
Total revenue	43,087	42,162
Operating expenses	15,335	14,086
Cost of product sales	545	284
Earnings of non-controlled entities	-721	-646
Operating margin	27,928	28,438
Depreciation and amortization expense	9,014	7,072
G&A expenses	4,813	5,922
Operating profit	14,101	15,444
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue	0	0
Product sales revenue	0	0
Affiliate management fee revenue	0	0
Total revenue	0	0
Operating expenses	-1,007	-804
Cost of product sales	0	0
Earnings of non-controlled entities	0	0
Operating margin	1,007	804
Depreciation and amortization expense	1,007	804
G&A expenses	0	0
Operating profit	$0	$0

Investments_in_NonControlled_E2

Investments in Non-Controlled Entities (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2014	$613,867,000
Additional Investment in NonControlled Entities	27,003,000
Proportionate share of earnings	10,288,000
Amortization of excess investment and capitalized interest	-698,000
Earnings of non-controlled entities	9,590,000	466,000
Distributions of earnings from investments in non-controlled entities	9,229,000	384,000
Distributions in excess of earnings of non-controlled entities	4,613,000	687,000
Investments at March 31, 2015	636,618,000
Equity Method Investment, Summarized Financial Information, Current Assets	72,436,000
Equity Method Investment, Summarized Financial Information, Noncurrent Assets	1,074,674,000
Equity Method Investment, Summarized Financial Information, Assets	1,147,110,000
Equity Method Investment, Summarized Financial Information, Current Liabilities	60,637,000
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities	2,021,000
Equity Method Investment, Summarized Financial Information, Liabilities	62,658,000
Equity Method Investment Summarized Financial Information, Equity	1,084,452,000
Equity Method Investment, Summarized Financial Information, Revenue	46,656,000
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	20,618,000
Texas Frontera Llc [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%
Powder Springs Logistics, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%
Joint Venture Partner One, Ownership Interest	50.00%
Storage Capacity in Construction	120,000
Saddlehorn Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Pipeline, Length	550
Interest in equity method investment	40.00%
Joint Venture Partner One, Ownership Interest	40.00%
Joint Venture Partner Two, Ownership Interest	20.00%
Osage Pipeline Co [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%
Double Eagle Pipeline Llc [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%
BridgeTex [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2014	489,348,000
Additional Investment in NonControlled Entities	7,358,000
Proportionate share of earnings	9,019,000
Amortization of excess investment and capitalized interest	-510,000
Earnings of non-controlled entities	8,509,000
Distributions of earnings from investments in non-controlled entities	8,509,000
Distributions in excess of earnings of non-controlled entities	4,565,000
Investments at March 31, 2015	492,141,000
Equity Method Investment, Summarized Financial Information, Current Assets	50,901,000
Equity Method Investment, Summarized Financial Information, Noncurrent Assets	822,132,000
Equity Method Investment, Summarized Financial Information, Assets	873,033,000
Equity Method Investment, Summarized Financial Information, Current Liabilities	49,618,000
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities	236,000
Equity Method Investment, Summarized Financial Information, Liabilities	49,854,000
Equity Method Investment Summarized Financial Information, Equity	823,179,000
Equity Method Investment, Summarized Financial Information, Revenue	37,136,000
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	18,037,000
All Other Equity Investments [Member]
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2014	124,519,000
Additional Investment in NonControlled Entities	19,645,000
Proportionate share of earnings	1,269,000
Amortization of excess investment and capitalized interest	-188,000
Earnings of non-controlled entities	1,081,000
Distributions of earnings from investments in non-controlled entities	720,000
Distributions in excess of earnings of non-controlled entities	48,000
Investments at March 31, 2015	144,477,000
Equity Method Investment, Summarized Financial Information, Current Assets	21,535,000
Equity Method Investment, Summarized Financial Information, Noncurrent Assets	252,542,000
Equity Method Investment, Summarized Financial Information, Assets	274,077,000
Equity Method Investment, Summarized Financial Information, Current Liabilities	11,019,000
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities	1,785,000
Equity Method Investment, Summarized Financial Information, Liabilities	12,804,000
Equity Method Investment Summarized Financial Information, Equity	261,273,000
Equity Method Investment, Summarized Financial Information, Revenue	9,520,000
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	2,581,000
Equity Method Investee [Member] | Double Eagle Pipeline Llc [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party	900,000	500,000
Accounts Receivable, Related Parties, Current			300,000
Equity Method Investee [Member] | BridgeTex [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party	8,400,000
Accounts Receivable, Related Parties, Current			2,600,000
Accounts Payable, Related Parties, Current	$1,500,000		$2,200,000

Inventory_Details

Inventory (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Inventory Disclosure [Abstract]
Refined products	$68,279	$67,055
Liquefied petroleum gases	38,772	37,642
Transmix	33,721	36,867
Crude oil	14,068	10,015
Additives	6,109	6,183
Total inventory	$160,949	$157,762

Schedule_Of_Consolidated_Net_P

Schedule Of Consolidated Net Periodic Benefit Costs (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
	pension_plan
Defined Benefit Plan Disclosure [Line Items]
Number of Union Pension Plans	2
Defined Contribution Plan, Cost Recognized	$2,800,000	$2,600,000
Pension Plan [Member]
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	4,470,000	3,352,000
Interest cost	1,869,000	1,659,000
Expected return on plan assets	-1,896,000	-1,697,000
Amortization of prior service cost (credit)	0	33,000
Amortization of actuarial loss	1,347,000	629,000
Net periodic benefit cost (credit)	5,790,000	3,976,000
Other Postretirement Benefit Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year	1,100,000
Components of net periodic benefit costs:
Service cost	66,000	67,000
Interest cost	110,000	114,000
Expected return on plan assets	0	0
Amortization of prior service cost (credit)	-928,000	-928,000
Amortization of actuarial loss	225,000	195,000
Net periodic benefit cost (credit)	($527,000)	($552,000)

Employee_Benefit_Plans_Schedul

Employee Benefit Plans Schedule of Amounts Recognized in Other Comprehensive Income (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Changes in AOCL [Roll Forward]
Accumulated other comprehensive loss (Beginning Bal)	($81,540)
Amortization of prior service credit	-928	[1]	-895	[1]
Amortization of actuarial loss	-1,572	[1]	-824	[1]
Accumulated other comprehensive loss (Ending Bal)	-96,161
Pension Plan [Member]
Changes in AOCL [Roll Forward]
Accumulated other comprehensive loss (Beginning Bal)	-63,257		-36,184
Amortization of prior service credit	0		33
Amortization of actuarial loss	1,347		629
Accumulated other comprehensive loss (Ending Bal)	-61,910		-35,522
Other Postretirement Benefit Plan [Member]
Changes in AOCL [Roll Forward]
Accumulated other comprehensive loss (Beginning Bal)	-1,696		3,053
Amortization of prior service credit	-928		-928
Amortization of actuarial loss	225		195
Accumulated other comprehensive loss (Ending Bal)	($2,399)		$2,320
[1]	See Note 6–Employee Benefit Plans for details of the changes in employee benefit plan assets and benefit obligations recognized in AOCL.

Debt_Consolidated_Debt_Details

Debt (Consolidated Debt) (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
Debt Instrument [Line Items]
Total debt	$3,183,750,000		$2,982,895,000
Weighted-Average Interest Rate	4.70%	[1]
Debt Instrument, Face Amount	3,200,000,000		2,900,000,000
Commercial Paper [Member]
Debt Instrument [Line Items]
Total debt	0		296,942,000
Weighted-Average Interest Rate	0.50%	[1],[2]
Senior Notes [Member] | 5.65% Notes Due 2016 [Member]
Debt Instrument [Line Items]
Total debt	250,652,000		250,758,000
Weighted-Average Interest Rate	5.70%	[1]
Debt Instrument, Face Amount	250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.65%		5.65%
Senior Notes [Member] | 6.40% Notes Due 2018 [Member]
Debt Instrument [Line Items]
Total debt	256,764,000		257,280,000
Weighted-Average Interest Rate	5.40%	[1]
Debt Instrument, Face Amount	250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.40%		6.40%
Senior Notes [Member] | 6.55% Notes Due 2019 [Member]
Debt Instrument [Line Items]
Total debt	566,939,000		567,868,000
Weighted-Average Interest Rate	5.70%	[1]
Debt Instrument, Face Amount	550,000,000		550,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.55%		6.55%
Senior Notes [Member] | 4.25% Notes Due 2021 [Member]
Debt Instrument [Line Items]
Total debt	556,071,000		556,304,000
Weighted-Average Interest Rate	4.00%	[1]
Debt Instrument, Face Amount	550,000,000		550,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.25%		4.25%
Senior Notes [Member] | 3.20% Notes Due 2025 [Member]
Debt Instrument [Line Items]
Total debt	249,680,000		0
Weighted-Average Interest Rate	3.20%	[1],[2]
Debt Instrument, Face Amount	250,000,000		0
Debt Instrument, Interest Rate, Stated Percentage	3.20%		0.00%
Senior Notes [Member] | 6.40% Notes Due 2037 [Member]
Debt Instrument [Line Items]
Total debt	249,021,000		249,017,000
Weighted-Average Interest Rate	6.40%	[1]
Debt Instrument, Face Amount	250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.40%		6.40%
Senior Notes [Member] | 4.20% Notes Due 2042 [Member]
Debt Instrument [Line Items]
Total debt	248,414,000		248,406,000
Weighted-Average Interest Rate	4.20%	[1]
Debt Instrument, Face Amount	250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.20%		4.20%
Senior Notes [Member] | 5.15% Notes Due 2043 [Member]
Debt Instrument [Line Items]
Total debt	556,296,000		556,320,000
Weighted-Average Interest Rate	5.10%	[1]
Debt Instrument, Face Amount	550,000,000		550,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.15%		5.15%
Senior Notes [Member] | 4.20% Notes Due 2045 [Member]
Debt Instrument [Line Items]
Total debt	249,913,000		0
Weighted-Average Interest Rate	4.60%	[1],[2]
Debt Instrument, Face Amount	$250,000,000		$0
Debt Instrument, Interest Rate, Stated Percentage	4.20%		0.00%
[1]	Weighted-average interest rate includes the amortization/accretion of discounts, premiums and gains/losses realized on historical cash flow and fair value hedges recognized as interest expense.
[2]	These borrowings were outstanding for only a portion of the three month period ending March 31, 2015. 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 $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$3,200,000,000		$2,900,000,000
Debt placement costs	4,661,000	2,648,000
Long-term Debt	3,183,750,000		2,982,895,000
Commercial Paper [Member]
Debt Instrument [Line Items]
Borrowing capacity	1,000,000,000
Long-term Debt	0		296,942,000
Commercial Paper [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Term	397 days
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Borrowing capacity	1,000,000,000
Unused commitment fee	0.13%
Long-term Debt	0
Obligation for letters of credit	5,600,000
Revolving Credit Facility [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	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%
Senior Notes [Member] | 3.20% Notes Due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	250,000,000		0
Debt Instrument, Interest Rate, Stated Percentage	3.20%		0.00%
Notes At Price	99.87%
After Underwriting Discounts	247,600,000
Debt placement costs	2,100,000
Long-term Debt	249,680,000		0
Senior Notes [Member] | 4.20% Notes Due 2045 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	250,000,000		0
Debt Instrument, Interest Rate, Stated Percentage	4.20%		0.00%
Notes At Price	99.97%
After Underwriting Discounts	247,300,000
Debt placement costs	2,600,000
Long-term Debt	$249,913,000		$0

Derivative_Financial_Instrumen2

Derivative Financial Instruments (Narrative) (Details) (USD $)	3 Months Ended				12 Months Ended
	Mar. 31, 2015		Mar. 31, 2014		Dec. 31, 2014		Dec. 31, 2012	Dec. 31, 2013
Derivative [Line Items]
Debt Instrument, Face Amount	$3,200,000,000				$2,900,000,000
Net payment on financial derivatives	42,908,000		3,613,000
Net loss on cash flow hedges(1)	-15,465,000	[1]	-3,613,000	[1]
Accumulated Other Comprehensive Income (Loss) Cash Flow Hedge Gain (Loss) Effective Portion	-31,852,000		9,988,000		-16,587,000			13,627,000
Energy commodity derivatives deposits (liability)	31,512,000				84,463,000
Energy commodity derivatives deposits (asset)	1,100,000				6,184,000
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	-1,500,000
Tank bottoms and linefill	38,361,000				42,585,000
Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	700,000
Fair Value Hedging [Member] | NYMEX Commodity Contracts [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	700,000				700,000
Tank bottoms and linefill	-17,500,000				-13,300,000
Gain (Loss) from Components Excluded from Assessment of Fair Value Hedge Effectiveness, Net	-300,000
Two Thousand Fifteen Interest Rate Swaps [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Notional Amount	50,000,000
Derivative Asset, Fair Value, Gross Asset	1,000,000
Two Thousand Fourteen Interest Rate Swaps [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Notional Amount					250,000,000
Net payment on financial derivatives	-42,908,000
Net loss on cash flow hedges(1)	-16,400,000	[1]			-26,500,000	[1]
Two Thousand Twelve Interest Rate Swaps [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Net payment on financial derivatives							11,000,000
Accumulated Other Comprehensive Income (Loss) Cash Flow Hedge Gain (Loss) Effective Portion	10,600,000
Senior Notes [Member] | 4.20% Notes Due 2045 [Member]
Derivative [Line Items]
Debt Instrument, Face Amount	$250,000,000				$0
Debt Instrument, Interest Rate, Stated Percentage	4.20%				0.00%
[1]	See Note 8–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 $)	Mar. 31, 2015
In Millions, unless otherwise specified	bbl
Forward Contracts [Member]
Derivative [Line Items]
Forward purchase contracts, Amount	$72.80
Forward purchase contracts, Barrels	1,800,000
Forward sale contracts, Amount	$4.50
Forward sale contracts, Barrels	100,000

Derivative_Financial_Instrumen4

Derivative Financial Instruments (Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements) (Details)	Mar. 31, 2015
	bbl
Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	700,000
Economic Hedges [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	3,200,000	[1]
Economic Hedges Futures [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	300,000
Basis Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	100,000
[1]	Of the 3.2 million barrels of products we have economically hedged at March 31, 2015, we had open agreements which swap the pricing on 0.1 million of those barrels from New York harbor to Platts Group 3 or Platts Gulf Coast, which are the geographic locations where these barrels will be sold.

Derivative_Financial_Instrumen5

Derivative Financial Instruments Schedule of Derivative Offset Amounts (Details) (Exchange Traded [Member], USD $)	Mar. 31, 2015		Dec. 31, 2014
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset	$55,770,000		$106,764,000
Derivative Liability, Fair Value, Gross Liability	-1,691,000		-10,622,000
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	54,079,000	[1]	96,142,000	[2]
Derivative Liability, Fair Value of Collateral	-30,412,000		-78,279,000
Amount After Offset	23,667,000	[3]	17,863,000	[3]
Other Current Liabilities [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	-814,000		-5,413,000
Other Noncurrent Assets [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	18,168,000		14,404,000
Other Current Assets [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	$36,725,000		$87,151,000
[1]	Net amount includes energy commodity derivative contracts classified as current assets, net, of $36,725, current liabilities of $814 and noncurrent assets of $18,168.
[2]	Net amount includes energy commodity derivative contracts classified as current assets, net, of $87,151, current liabilities of $5,413 and noncurrent assets of $14,404.
[3]	This represents the maximum amount of loss we would incur if our counterparties failed to perform on their derivative contracts.

Derivative_Financial_Instrumen6

Derivative Financial Instruments (Derivative Gains Included In Accumulated Other Comprehensive Loss (AOCL) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Derivative Gains Included in AOCI [Roll Forward]
Beginning balance	($16,587)		$13,627
Net gain (loss) on cash flow hedges	-15,465	[1]	-3,613	[1]
Reclassification of net loss (gain) on cash flow hedges to income	200	[1]	-26	[1]
Ending balance	($31,852)		$9,988
[1]	See Note 8–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
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on cash flow hedges	($15,465)	[1]	($3,613)	[1]
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on cash flow hedges	-15,465		-3,613
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	-200		26
Derivative Instruments, Gain (Loss) Recognized in Income, Ineffective Portion and Amount Excluded from Effectiveness Testing, Net	$0		$0
[1]	See Note 8–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
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$3,959	$3,332
NYMEX Commodity Contracts [Member] | Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	3,880	2,823
NYMEX Commodity Contracts [Member] | Operating Expenses [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	1,303	365
Butane Futures Agreements [Member] | Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	($1,224)	$144

Derivative_Financial_Instrumen9

Derivative Financial Instruments (Derivatives and Hedging - Designated) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$19,674	$14,764
Derivative Liability, Fair Value, Gross Liability	0	26,478
Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	541	360
Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	0	0
Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	18,168	14,404
Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	0	0
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		0
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability		26,478
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	965
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	0
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	37,061	92,000
Derivative Liability, Fair Value, Gross Liability	1,691	10,622
Not Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	37,061	92,000
Not Designated as Hedging Instrument [Member] | NYMEX Commodity Contracts [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	13	0
Not Designated as Hedging Instrument [Member] | Butane Futures Agreements [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	0
Not Designated as Hedging Instrument [Member] | Butane Futures Agreements [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	$1,678	$10,622

Commitments_And_Contingencies_

Commitments And Contingencies (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Loss Contingencies [Line Items]
Liabilities recognized for estimated environmental costs	$36.40		$36.30
Estimated environmental liabilities, years	10 years
Environmental expenses	1.4	0.3
Receivables from insurance carriers related to environmental matters	5		5.1
Accounts Receivable [Member]
Loss Contingencies [Line Items]
Receivables from insurance carriers related to environmental matters	1.2		1.3
Other Noncurrent Assets [Member]
Loss Contingencies [Line Items]
Receivables from insurance carriers related to environmental matters	$3.80		$3.80

LongTerm_Incentive_Plan_Narrat

Long-Term Incentive Plan (Narrative) (Details)	1 Months Ended
	Feb. 28, 2015	Jan. 31, 2015	Mar. 31, 2015
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			1,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	166,189
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Partners' Capital Account, Units, Unit-based Compensation		358,072
Management [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Partners' Capital Account, Units, Unit-based Compensation		354,529
Director [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Partners' Capital Account, Units, Unit-based Compensation		3,543

LongTerm_Incentive_Plan_Equity

Long-Term Incentive Plan (Equity-Based Incentive Compensation Expense) (Details) (Management [Member], USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	$4,751	$5,088
G&A Expense [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	4,689	4,974
Operating Expenses [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	62	114
Equity Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	4,536	3,616
Liability Method [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	215	1,472
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		1,946
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
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		924
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	1,734	1,729
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	1,519	1,181
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	215	548
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	1,623	904
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	1,623	904
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
Performance Based Awards [Member] | Two Thousand Fifteen Awards [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	1,019
Performance Based Awards [Member] | Two Thousand Fifteen 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	1,019
Performance Based Awards [Member] | Two Thousand Fifteen 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
Retention Awards [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	375	509
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	375	509
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

Distributions_Schedule_Of_Dist

Distributions (Schedule Of Distributions) (Details) (USD $)	0 Months Ended					12 Months Ended	0 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Feb. 13, 2015	Nov. 14, 2014	Aug. 14, 2014	15-May-14	Feb. 14, 2014	Dec. 31, 2014	15-May-15		Jun. 30, 2015
Per Unit Cash Distribution Amount	$0.70	$0.67	$0.64	$0.61	$0.59	$2.50
Total Cash Distribution to Limited Partners	$158,061	$151,568	$145,324	$139,079	$132,835	$568,806
Scenario, Forecast
Per Unit Cash Distribution Amount							$0.72	[1]	$1.41
Total Cash Distribution to Limited Partners							$163,178	[1]	$321,239
[1]	Our general partner's board of directors declared this cash distribution on April 23, 2015 to be paid on May 15, 2015 to unitholders of record at the close of business on May 4, 2015.

Fair_Value_Schedule_Of_Carryin

Fair Value (Schedule Of Carrying Amounts And Fair Values Of Financial Assets/Liabilities) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | NYMEX Commodity Contracts [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	$54,079	$96,142
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt	-3,481,995	-3,212,462
Fair Value, Measurements, Recurring [Member] | Significant Other Observable Inputs (Level 2) [Member] | Interest Rate Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	965
Derivative liability		-26,478
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivables	28,820	30,200
Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivables	28,820	30,200
Debt	-3,481,995	-3,212,462
Estimate of Fair Value Measurement [Member] | NYMEX Commodity Contracts [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	54,079	96,142
Estimate of Fair Value Measurement [Member] | Interest Rate Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	965
Derivative liability		-26,478
Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivables	27,116	28,611
Debt	-3,183,750	-2,982,895
Reported Value Measurement [Member] | NYMEX Commodity Contracts [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	54,079	96,142
Reported Value Measurement [Member] | Interest Rate Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	965
Derivative liability		($26,478)

Related_Party_Transactions_Det

Related Party Transactions (Details) (Director [Member], Targa Resource Partners L P [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Director [Member] | Targa Resource Partners L P [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$8.80	$12.20
Accounts Payable, Related Parties	$1.50		$0.90

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	0 Months Ended					12 Months Ended	0 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Feb. 13, 2015	Nov. 14, 2014	Aug. 14, 2014	15-May-14	Feb. 14, 2014	Dec. 31, 2014	15-May-15		Jun. 30, 2015
Subsequent Event [Line Items]
Cash distribution per unit	$0.70	$0.67	$0.64	$0.61	$0.59	$2.50
Total cash distributions	$158,061	$151,568	$145,324	$139,079	$132,835	$568,806
Scenario, Forecast
Subsequent Event [Line Items]
Cash distribution per unit							$0.72	[1]	$1.41
Total cash distributions							$163,178	[1]	$321,239
[1]	Our general partner's board of directors declared this cash distribution on April 23, 2015 to be paid on May 15, 2015 to unitholders of record at the close of business on May 4, 2015.