Magellan Midstream Partners (MMP) 10-K 20 Feb 15 2014 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2014	Feb. 19, 2015	Jun. 30, 2014
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
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
Entity Public Float			$19,041,935,144
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Well-known Seasoned Issuer	Yes

Consolidated_Statements_Of_Inc

Consolidated Statements Of Income (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Statement [Abstract]
Transportation and terminals revenue	$1,402,638	$1,138,328	$970,744
Product sales revenue	878,974	744,669	799,382
Affiliate management fee revenue	22,111	14,609	1,948
Total revenue	2,303,723	1,897,606	1,772,074
Costs and expenses:
Operating	444,272	346,070	328,454
Cost of product sales	594,585	578,029	657,108
Depreciation and amortization	161,741	142,230	128,012
General and administrative	148,288	132,496	109,403
Total costs and expenses	1,348,886	1,198,825	1,222,977
Earnings of non-controlled entities	19,394	6,275	2,961
Operating profit	974,231	705,056	552,058
Interest expense	143,529	130,463	117,981
Interest income	-1,540	-342	-107
Interest capitalized	-22,803	-14,339	-6,195
Debt placement fee amortization expense	2,333	2,424	2,087
Other expense	8,573	0	0
Income before provision for income taxes	844,139	586,850	438,292
Provision for income taxes	4,620	4,613	2,622
Net income	$839,519	$582,237	$435,670
Basic net income per limited partner unit (in dollars per unit)	$3.69	$2.57	$1.92
Diluted net income per limited partner unit (in dollars per unit)	$3.69	$2.56	$1.92
Weighted average number of limited partner units outstanding used for basic net income per unit calculation (in units)	227,260	226,829	226,369
Weighted average number of limited partner units outstanding used for diluted net income per unit calculation (in units)	227,626	227,094	226,608

Consolidated_Statements_Of_Com

Consolidated Statements Of Comprehensive Income (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Net income	$252,085	$198,620	$146,260	$242,554	$190,007	$125,623	$153,640	$112,967	$839,519		$582,237		$435,670
Other comprehensive income:
Net gain (loss) on cash flow hedges(1)									-30,090	[1]	-4,744	[1]	13,889	[1]
Reclassification of net loss (gain) on cash flow hedges to income(1)									-124	[1]	4,245	[1]	-2,924	[1]
Net actuarial (loss) gain(2)									-33,937	[2]	14,089	[2]	-17,804	[2]
Plan amendment(2)											0	[2]	16,020	[2]
Amortization of prior service credit(2)									-3,680	[2]	-3,405	[2]	-1,664	[2]
Amortization of actuarial loss(2)									3,986	[2]	5,369	[2]	4,626	[2]
Settlement cost(2)									1,809	[2]	0	[2]	0	[2]
Total other comprehensive income (loss)									-62,036		15,554		12,143
Comprehensive income									$777,483		$597,791		$447,813
[1]	See Note 13–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 10–Employee Benefit Plans for additional detail of the changes in employee benefit plan assets and benefit obligations that are recognized in other comprehensive income (loss).

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:
Cash and cash equivalents	$17,063	$25,235
Trade accounts receivable	84,465	116,295
Other accounts receivable	15,711	6,462
Inventory	157,762	187,224
Energy commodity derivatives contracts, net	87,151	0
Energy commodity derivatives deposits	6,184	14,782
Other current assets	34,331	46,735
Total current assets	402,667	396,733
Property, plant and equipment	5,533,935	4,986,750
Less: accumulated depreciation	1,204,601	1,070,492
Net property, plant and equipment	4,329,334	3,916,258
Investments in non-controlled entities	613,867	360,852
Long-term receivables	28,611	2,730
Goodwill	53,260	53,260
Other intangibles (less accumulated amortization of $8,809 and $11,526 at December 31, 2013 and 2014, respectively)	4,573	7,290
Debt placement costs (less accumulated amortization of $9,113 and $8,952 at December 31, 2013 and 2014, respectively)	18,084	17,505
Tank bottoms and linefill	42,585	61,915
Other noncurrent assets	24,304	4,269
Total assets	5,517,285	4,820,812
Current liabilities:
Accounts payable	97,131	76,326
Accrued payroll and benefits	48,298	42,243
Accrued interest payable	45,973	44,935
Accrued taxes other than income	47,888	38,574
Environmental liabilities	10,564	12,147
Deferred revenue	71,142	63,164
Accrued product purchases	44,355	63,033
Energy commodity derivatives contracts, net	5,413	6,737
Deposit Liability, Current	84,463	0
Current portion of long-term debt	0	249,971
Other current liabilities	80,928	41,146
Total current liabilities	536,155	638,276
Long-term debt	2,982,895	2,435,316
Long-term pension and benefits	75,155	51,637
Other noncurrent liabilities	29,069	21,802
Environmental liabilities	25,778	26,339
Commitments and contingencies
Partners' capital:
Limited partner unitholders (226,679 units and 227,068 units outstanding at December 31, 2013 and 2014, respectively)	1,949,773	1,666,946
Accumulated other comprehensive loss	-81,540	-19,504
Total partners’ capital	1,868,233	1,647,442
Total liabilities and partners' capital	$5,517,285	$4,820,812

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, except Share data, unless otherwise specified
Statement of Financial Position [Abstract]
Other intangibles, accumulated amortization	$11,526	$8,809
Debt placement costs, accumulated amortization	$8,952	$9,113
Limited partner unitholders, units outstanding	227,068,257	226,679,438

Consolidated_Statments_of_Cash

Consolidated Statments of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Statement of Cash Flows [Abstract]
Net income	$839,519	$582,237	$435,670
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	161,741	142,230	128,012
Debt placement fee amortization expense	2,333	2,424	2,087
Loss on sale and retirement of assets	7,223	7,835	12,625
Earnings of non-controlled entities	-19,394	-6,275	-2,961
Distributions from investments in non-controlled entities	3,086	2,494	2,961
Equity-based incentive compensation expense	27,284	24,083	21,036
Settlement cost, amortization of prior service credit and actuarial loss	2,115	1,964	2,962
Changes in components of operating assets and liabilities (Note 3)	83,394	16,084	44,063
Net cash provided by operating activities	1,107,301	773,076	646,455
Property, plant and equipment:
Additions to property, plant and equipment	-366,445	-383,757	-354,168
Proceeds from sale and disposition of assets	10,780	3,610	1,056
Increase (decrease) in accounts payable related to capital expenditures	3,195	-37,678	55,133
Acquisition of assets	-75,000	-22,506	0
Acquisition of business	0	-192,000	0
Investments in non-controlled entities	-408,001	-250,495	-74,934
Distributions in excess of earnings of non-controlled entities	5,487	780	4,832
Net cash used by investing activities	-829,984	-882,046	-368,081
Financing Activities:
Distributions paid	-568,806	-475,461	-403,485
Net commercial paper borrowings	296,942	0	0
Borrowings under long-term notes	257,713	298,680	248,345
Payments on notes	-250,000	0	0
Debt placement costs	-2,912	-4,849	-2,552
Net receipt (payment) on financial derivatives	-3,613	-184	10,977
Settlement of tax withholdings on equity-based incentive compensation	-14,813	-12,259	-13,001
Net cash used by financing activities	-285,489	-194,073	-159,716
Change in cash and cash equivalents	-8,172	-303,043	118,658
Cash and cash equivalents at beginning of period	25,235	328,278	209,620
Cash and cash equivalents at end of period	17,063	25,235	328,278
Noncash Investing and Financing Items [Abstract]
Issuance of limited partner units in settlement of equity-based incentive plan awards	$7,315	$6,404	$7,295

Consolidated_Statement_Of_Part

Consolidated Statement Of Partners' Capital (USD $)	Total	Limited Partner [Member]	Accumulated Other Comprehensive Loss [Member]
In Thousands, unless otherwise specified
Balance at Dec. 31, 2011	$1,463,403	$1,510,604	($47,201)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	435,670	435,670
Total other comprehensive income	12,143		12,143
Total comprehensive income (loss)	447,813	435,670	12,143
Distributions	-403,485	-403,485
Equity method incentive compensation expense	14,118	14,118
Issuance of limited partner units in settlement of equity-based incentive plan awards	7,295	7,295
Settlement of tax withholdings on equity-based incentive compensation	-13,001	-13,001
Other	-441	-441
Balance at Dec. 31, 2012	1,515,702	1,550,760	-35,058
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	582,237	582,237
Total other comprehensive income	15,554		15,554
Total comprehensive income (loss)	597,791	582,237	15,554
Distributions	-475,461	-475,461
Equity method incentive compensation expense	15,532	15,532
Issuance of limited partner units in settlement of equity-based incentive plan awards	6,404	6,404
Settlement of tax withholdings on equity-based incentive compensation	-12,259	-12,259
Other	-267	-267
Balance at Dec. 31, 2013	1,647,442	1,666,946	-19,504
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	839,519	839,519
Total other comprehensive income	-62,036		-62,036
Total comprehensive income (loss)	777,483	839,519	-62,036
Distributions	-568,806	-568,806
Equity method incentive compensation expense	19,963	19,963
Issuance of limited partner units in settlement of equity-based incentive plan awards	7,315	7,315
Settlement of tax withholdings on equity-based incentive compensation	-14,813	-14,813
Other	-351	-351
Balance at Dec. 31, 2014	$1,868,233	$1,949,773	($81,540)

Organization_And_Description_O

Organization And Description Of Business	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization And Description Of Business	Organization and Description of Business
	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 trade 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.
	We operate and report in three business segments: refined products, crude oil and marine storage. Our reportable segments offer different products and services and are managed separately because each requires different marketing strategies and business knowledge.
	Description of Business
	Refined Products. Our refined products segment includes the operations of our refined products pipeline system, independent terminals and ammonia pipeline as well as blending and fractionation activities, each of which is briefly described below:
	•	Our refined products pipeline system consists of approximately 9,500 miles of pipeline and 53 terminals that provide transportation, storage and distribution services. Our refined products pipeline system covers a 15-state area from the Gulf Coast across the central U.S. The products transported on our pipeline system are primarily gasoline, distillates, aviation fuels and liquefied petroleum gases. Product originates on our pipeline system from direct connections to refineries, at our terminals and through interconnections with other interstate pipelines for transportation and ultimate distribution to retail gasoline stations, truck stops, railroads, airports and other end users. Our refined products pipeline system also generates fees from ancillary services including ethanol and biodiesel loading and unloading, additive injection, custom blending, terminalling, laboratory testing and data services. Our blending activities involve purchasing liquefied petroleum gases and blending them into gasoline, which creates gasoline available for us to sell. Our fractionation activities include three fractionators along our pipeline system that separate transmix, an unusable mixture of various petroleum products, into gasoline and diesel fuel. We generate transmix from the commingling of products between different product batches during the transportation process on our pipelines. We also purchase transmix from third parties;
	•	Our 27 independent terminals are part of a distribution network located principally throughout the southeastern U.S. We earn revenue at our independent terminals primarily from fees we charge based on the volumes of refined products distributed from these locations and from ancillary services such as additive injections and ethanol blending; and
	•	Our ammonia pipeline consists of 1,100 miles of pipeline that transports and distributes ammonia from production facilities in Texas and Oklahoma to various distribution points in the Midwest for use as an agricultural fertilizer. We generate revenue principally from volume-based fees for the transportation of ammonia on our pipeline system.
	Crude Oil. Our crude oil segment includes approximately 1,600 miles of pipeline and 12 million barrels of crude oil storage used for leased storage. Our 450-mile Longhorn pipeline, which began crude oil service operations in early 2013, originates in Crane, Texas for deliveries to Houston-area refineries and pipelines. Our Houston-area crude oil distribution system originates at our East Houston, Texas terminal and other points in the Houston area for delivery to nearby refineries and pipelines. We also own approximately 300 miles of pipeline in Kansas and Oklahoma currently used for crude oil service. Revenues on our crude oil pipelines are generated primarily through transportation tariffs for crude oil shipped, as well as from leasing pipeline capacity to third parties.
	Our terminal in Cushing, Oklahoma consists of approximately 10 million barrels of crude oil storage used for leased storage and is located in one of the largest crude oil trading hubs in the U.S. Our terminals at East Houston and Corpus Christi, Texas each include approximately one million barrels of crude oil storage used for leased storage. These facilities earn revenues primarily through leased storage and throughput fees.
	Our crude oil segment also includes ownership interests in the following joint ventures:
	•	a 50% interest in Osage Pipe Line Company, LLC (“Osage”), which owns a 135-mile pipeline that transports crude oil from Cushing, Oklahoma to refineries in El Dorado, Kansas;
	•	a 50% interest in Double Eagle Pipeline LLC (“Double Eagle”), which transports condensate from the Eagle Ford shale formation in South Texas via a 195-mile pipeline to our terminal in Corpus Christi; and
	•	a 50% interest in BridgeTex Pipeline Company, LLC (“BridgeTex”), which owns a 400-mile pipeline to transport crude oil from Colorado City, Texas for delivery to the Houston Gulf Coast area. The BridgeTex pipeline began commercial service to the Houston Gulf Coast area during September 2014.
	Marine Storage. Our marine storage segment is comprised of storage terminals, which primarily store and distribute refined products. Our storage terminals are comprised of five facilities that have marine access in New Haven, Connecticut, Wilmington, Delaware, Marrero, Louisiana, and Corpus Christi and Galena Park, Texas which are located near major refining hubs along the U.S. Gulf and East Coasts. Our marine storage terminals have an aggregate storage capacity of approximately 26 million barrels. We earn revenue through storage and ancillary fees, including product heating, blending, mixing and additive injection for refiners and other large end users of refined products. We have a 50% interest in a refined products storage company, Texas Frontera, LLC ("Texas Frontera"), which owns approximately one million barrels of storage located at our terminal in Galena Park, Texas included in our aggregate storage capacity.

Summary_Of_Significant_Account

Summary Of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Summary Of Significant Accounting Policies	Summary of Significant Accounting Policies
	Basis of Presentation. Our consolidated financial statements include our refined products, crude oil and marine storage segments. We consolidated all entities in which we have a controlling ownership interest. We apply the equity method of accounting for entities where our ownership interest is greater than 20% but we do not control and which we have determined are not variable interest entities. We have eliminated all intercompany transactions.
	Use of Estimates. The preparation of our consolidated financial statements in conformity with generally accepted accounting principles in the U.S. ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities that exist at the date of our consolidated financial statements, as well as their impact on the reported amounts of revenue and expense during the reporting periods. Actual results could differ from those estimates.
	Cash Equivalents. Cash and cash equivalents include demand and time deposits and funds that own highly marketable securities with original maturities of three months or less when acquired. We periodically assess the financial condition of the institutions where we hold these funds, and, at December 31, 2013 and 2014, we believed our credit risk relative to these funds was minimal.
	Accounts Receivable and Allowance for Doubtful Accounts. Accounts receivable represent valid claims against customers. We recognize accounts receivable when we sell products or render services and collection of the receivable is probable. We extend credit terms to certain customers based on historical dealings and to other customers after a review of various credit indicators. We establish an allowance for doubtful accounts for all or any portion of an account where we consider collections to be at risk and evaluate reserves no less than quarterly to determine their adequacy. Judgments relative to at-risk accounts include the customers' current financial condition, the customers' historical relationship with us and current and projected economic conditions. We write off accounts receivable when we deem the account uncollectible.
	Inventory Valuation. Inventory is comprised primarily of refined products, liquefied petroleum gases, transmix and crude oil, which are stated and relieved at the lower of average cost or market. During 2014, we recorded a lower-of-average-cost-or-market adjustment of $39.3 million to our fractionation and butane blending inventories.
	Property, Plant and Equipment. Property, plant and equipment consist primarily of pipeline, pipeline-related equipment, storage tanks and processing equipment. We state property, plant and equipment at cost except for certain acquired assets recorded at fair value on their respective acquisition dates and impaired assets. We record impaired assets at fair value on the last impairment evaluation date for which an adjustment was required.
	We assign asset lives based on reasonable estimates when we place an asset into service. Subsequent events could cause us to change our estimates, which would affect the future calculation of depreciation expense. The range of depreciable lives by asset category is detailed in Note 8—Property, Plant and Equipment.
	When we sell or retire property, plant and equipment, we remove its carrying value and the related accumulated depreciation from our accounts and record any associated gains or losses on our income statement in the period of sale or disposition.
	We capitalize expenditures to replace existing assets and retire the replaced assets. We capitalize expenditures when they extend the useful life, increase the productivity or capacity or improve the safety or efficiency of the asset. We capitalize direct project costs such as labor and materials as incurred. Indirect project costs, such as overhead, are capitalized based on a percentage of direct labor charged to the respective capital project. We charge expenditures for maintenance, repairs and minor replacements to operating expense in the period incurred.
	Investments in Non-Controlled Entities. We account for investments greater than 20% in affiliates that we do not control using the equity method of accounting. Under this method, an investment is recorded at our acquisition cost or capital contributions, as adjusted by contractual terms, plus equity in earnings or losses since acquisition or formation, plus interest capitalized, less distributions received and amortization of interest capitalized and excess net investment. Excess net investment is the amount by which our investment in a non-controlled entity exceeded our proportionate share of the book value of the net assets of that investment. We amortize excess net investment over the weighted-average depreciable asset lives of the equity investee. Our unamortized excess net investment was $15.1 million and $79.0 million at December 31, 2013 and 2014, respectively. The increase in the amount of unamortized excess investment during 2014 was due primarily to our investment in BridgeTex. We evaluate equity method investments for impairment whenever events or circumstances indicate that there is an other-than-temporary loss in value of the investment. In the event that we determine that the loss in value of an investment is other-than-temporary, we would record a charge to earnings to adjust the carrying value to fair value. We recognized no equity investment impairments during 2012, 2013 or 2014.
	Goodwill and Other Intangible Assets. We do not amortize goodwill, which represents the excess of fair value of the business acquired over the fair value of assets acquired and liabilities assumed. We evaluate goodwill for impairment annually as of October 1st and when events or changes in circumstances indicate that the fair value of a reporting unit with goodwill has been reduced below carrying value. Goodwill was $53.3 million at both December 31, 2013 and 2014. Our reported goodwill at December 31, 2014 included $38.4 million allocated to our refined products segment, $12.1 million allocated to our crude oil segment and $2.8 million allocated to our marine storage segment.
	For 2014, we performed a qualitative assessment to determine whether the fair value of our reporting units was more likely than not less than their respective carrying amounts.  Our evaluation consisted of assessing the general impact of how a number of different elements would affect the fair value of our reporting units; including, the current and projected future earnings of our reporting units, our capitalization, our current slate of capital projects, the growth in the distributions we pay to our unitholders, current and future interest rates and the impact of lower crude oil prices on our earnings and the acquisition markets.  As of October 1, 2014, our qualitative assessment indicated that there was no need to conduct further quantitative testing nor did our analysis reflect any reporting units at risk.  If, based on the results of our qualitative assessment, we believed it was more likely than not the fair value of our reporting units were less than the carrying amount, we would have performed step one of the two-step goodwill impairment test. The first step of the goodwill impairment test determines whether an impairment exists by comparing the fair value of a reporting unit with its carrying amount, including goodwill.  If the estimated fair value of the reporting unit exceeds its carrying amount, no impairment is indicated. If the carrying amount of a reporting unit exceeds its estimated fair value, an impairment is indicated and the second step of the test is performed to measure the amount of impairment by comparing the implied fair value of the reporting unit goodwill to the carrying amount of that goodwill.  For periods prior to 2014, our October 1st goodwill assessment was based on a quantitative assessment of the fair value of our reporting units.
	We amortize other intangible assets over their estimated useful lives of 5 years up to 25 years. The weighted-average asset life of our other intangible assets at December 31, 2014 was approximately 6 years. We adjust the useful lives of our other intangible assets if events or circumstances indicate there has been a change in the remaining useful lives. We eliminate from our balance sheets the gross carrying amount and the related accumulated amortization for any fully amortized intangibles in the year they are fully amortized. We review our other intangible assets for impairment whenever events or changes in circumstances indicate we should assess the recoverability of the carrying amount of the intangible asset. We recognized no impairments for other intangible assets in 2012, 2013 and 2014. Amortization of other intangible assets was $1.9 million, $6.0 million and $2.7 million in 2012, 2013 and 2014, respectively, of which $0.6 million and $0.2 million was charged against transportation and terminals revenue in each year during 2012 and 2013, respectively.
	Tank Bottoms and Linefill. A contract we have with a customer at our crude oil terminal in Cushing, Oklahoma requires us to maintain a minimum volume of crude oil in the tanks they utilize at that facility. Because of this contractual requirement, the crude oil we own at that facility is not sold in the normal course of our business; therefore, we classify these crude oil barrels as a long-term asset carried at cost adjusted for gains or losses on certain derivative contracts classified as fair value hedges. At December 31, 2014, our tank bottoms and linefill consisted of 0.7 million barrels of crude oil with a carrying value of $42.6 million. We have entered into New York Mercantile Exchange ("NYMEX") contracts representing 0.7 million barrels of crude oil, which we have designated as fair value hedges against price changes in our tank bottoms and linefill. The cumulative gains (losses) of these derivative agreements as of December 31, 2013 and 2014 were $(8.7) million and $13.3 million, respectively, which were recorded as decreases (increases) to the tank bottoms and linefill.
	Impairment of Long-Lived Assets. We evaluate our long-lived assets of identifiable business activities, other than those held for sale, for impairment when events or changes in circumstances indicate, in management's judgment, that the carrying value of such assets may not be recoverable. We base the determination of whether impairment has occurred on management's estimate of undiscounted future cash flows attributable to the assets as compared to the carrying value of the assets. We calculate the amount of the impairment recognized as the excess of the carrying amount of the asset over the fair value of the assets, as determined either through reference to similar asset sales or by estimating the fair value using a discounted cash flow approach.
	Judgments and assumptions are inherent in management's estimate of undiscounted future cash flows used to determine recoverability of an asset and the estimate of an asset's fair value used to calculate the amount of impairment to recognize. The use of alternate judgments and assumptions could result in the recognition of different levels of impairment charges in the financial statements.
	Impairments we recognized in 2012 and 2013 were not material. In 2014, based on an impairment analysis we performed, we accelerated the depreciation of a certain terminal and related assets in our Refined Products segment (that we subsequently sold in 2014) by $9.4 million.
	Debt Placement Costs. We capitalize costs incurred for debt borrowings when paid and amortize those costs over the life of the associated debt instrument using the effective interest method. When debt is retired before its scheduled maturity date, we write off any remaining placement costs associated with that debt.
	Interest Capitalized. During construction, we capitalize interest on all construction projects requiring a completion period of three months or longer and total project costs exceeding $0.5 million. The interest we capitalize is based on the weighted-average interest rate of our debt. The weighted average rates used to capitalize interest on borrowed funds was 5.3%, 5.2% and 4.9% for the years ended December 31, 2012, 2013 and 2014, respectively.
	Pension and Postretirement Medical and Life Benefit Obligations. We sponsor three pension plans that cover substantially all of our employees, a postretirement medical and life benefit plan for certain employees and a defined contribution plan. Our pension and postretirement benefit liabilities represent the funded status of the present value of benefit obligations of these plans.
	We develop pension, postretirement medical and life benefits costs from actuarial valuations. We establish actuarial assumptions to anticipate future events and use those assumptions when calculating the expense and liabilities related to these plans. These factors include assumptions management makes concerning interest rates, expected investment return on plan assets, health care costs trend rates, turnover rates and rates of future compensation increases, among others. In addition, we use subjective factors such as withdrawal and mortality rates to develop actuarial valuations. Management reviews and updates these assumptions on an annual basis. The actuarial assumptions that we use may differ from actual results due to changing market rates or other factors. These differences could affect the amount of pension and postretirement medical and life benefit expense we will recognize in future periods.
	Derivative Financial Instruments. We use derivative instruments to manage market price risks associated with inventories, interest rates, our tank bottom and linefill assets and certain forecasted transactions. Our policies prohibit us from engaging in speculative trading activities. For certain physical forward commodity derivative contracts, accounting guidance provides for and we apply the normal purchase/normal sale exception, whereby changes in the mark-to-market values of such contracts are not recognized in income, rather the revenues and expenses associated with such transactions are recognized during the period when commodities are physically delivered or received. Physical forward commodity contracts subject to this exception are evaluated for the probability of future delivery and are periodically back-tested once the forecasted period has passed to determine whether similar forward contracts are probable of physical delivery in the future. For all other derivative contracts, we record the agreements on our balance sheets at fair value.
	For those instruments that qualify for hedge accounting, the accounting treatment depends on their intended use and their designation. We divide derivative financial instruments qualifying for hedge accounting treatment into two categories: (1) cash flow hedges and (2) fair value hedges. We execute cash flow hedges to hedge against the variability in cash flows related to a forecasted transaction and execute fair value hedges to hedge against the changes in the value of a recognized asset or liability. At the inception of a hedged transaction, we document the relationship between the hedging instrument and the hedged item, the risk management objectives and the methods used for assessing and testing correlation and hedge effectiveness. We also assess, both at the inception of the hedge and on an on-going basis, whether the derivatives that are used in our hedging transactions are highly effective in offsetting changes in cash flows or fair value of the hedged item. If we determine that a derivative originally designated as a cash flow or fair value hedge is no longer highly effective, we discontinue hedge accounting prospectively and record the change in the fair value of the derivative in current earnings. The change in fair value of derivative financial instruments that are not designated as a hedging instrument is included in current earnings.
	As part of our risk management process, we assess the creditworthiness of the financial and other institutions with which we execute financial derivatives. Such financial instruments involve the risk of non-performance by the counterparty, which could result in material losses to us.
	We have entered into NYMEX commodity based futures contracts to hedge against price changes on a portion of the refined products we expect to sell in the future and changes in the fair value of our tank bottoms and linefill. Some of these contracts have qualified as cash flow or fair value hedges under Accounting Standards Codification ("ASC") No. 815, Derivatives and Hedging, while others have not. We record the effective portion of the gains or losses for those contracts that qualify for and are designated as cash flow hedges in other comprehensive income and the ineffective portion in product sales revenue. We reclassify gains and losses from contracts that qualify as cash flow hedges from other comprehensive income to product sales revenue when the hedged transaction occurs and we terminate the derivative agreement. 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. We recognize the change in fair value of those agreements that are not designated as hedges in product sales revenue, except for those undesignated agreements that economically hedge the inventories associated with our pipeline system overages. We record the change in fair value of those agreements in operating expenses.
	In addition, we have entered into Chicago Mercantile Exchange ("CME")-traded butane futures agreements to hedge against changes in the price of butane we expect to purchase in the future. We account for all of these agreements as economic hedges, with period changes in the fair value of these agreements recorded as adjustments to cost of product sales.
	We use interest rate derivatives to help manage interest rate risk. We record any ineffectiveness on derivatives designated as hedging instruments to interest expense and the change in fair value of interest rate derivatives that we do not designate as hedging instruments to other income or expense in our results of operations. For the effective portion of interest rate cash flow hedges, we record the noncurrent portion of unrealized gains or losses as an adjustment to other comprehensive income with the current portion recorded as an adjustment to interest expense. For the effective portion of fair value hedges on long-term debt, we record the noncurrent portion of gains or losses as an adjustment to long-term debt with the current portion recorded as an adjustment to interest expense.
	See Comprehensive Income in this Note 2 for details of the derivative gains and losses included in accumulated other comprehensive loss.
	Revenue Recognition. We recognize pipeline transportation revenue for crude oil shipments when our customers take possession of their product from our system. For ammonia shipments and shipments of refined products under published tariffs that combine transportation and terminalling services, we recognize revenue when our customers take possession of their product from our system through tanker trucks, railcars or third-party pipelines. For all other shipments, where terminalling services are not included in the tariff, we recognize revenue when our customers' product arrives at the customer-designated delivery point. We have certain agreements that require counterparties to ship a minimum volume over an agreed-upon period. Revenue pursuant to such agreements is recognized at the earlier of when the volume is shipped or when the counterparty’s ability to meet the minimum volume commitment has expired.
	We recognize injection service fees associated with additives upon injection to the customer's product, which occurs at the time we deliver the product to our customers. We recognize leased tank storage, pipeline capacity leases, terminalling, throughput, ethanol loading and unloading services, laboratory testing, data services, pipeline operation fees and other miscellaneous service-related revenue upon completion of contract services. We recognize product sales upon delivery of the product to the customer. See Derivative Financial Instruments above for a discussion of how these agreements impact product sales. We record back-to-back purchases and sales of refined products where we are acting as an agent to facilitate refined product sales between a supplier and a customer on a net basis.
	Deferred Transportation Revenue and Costs. Generally, we invoice customers on our refined products pipeline for transportation services when their product enters our system. At each period end, we record all invoiced amounts associated with products that have not yet been delivered (in-transit products) as a deferred liability. The value of this liability is calculated as the total of the volume of each product type, for each pipeline region, multiplied by the average tariff rate for that product type for the most recent month invoiced to our customers. We use the most recent month's average tariff rate because the product in our pipeline system generally turns over every month. Additionally, at each period end, we defer the direct costs we have incurred associated with these in-transit products, until delivery occurs, as a deferred asset. These direct costs are estimated based on our average per-barrel direct delivery cost for the current year multiplied by the total in-transit barrels in our system at the end of the period multiplied by 50% to reflect the average transportation costs incurred for all products across all our pipeline systems. We use 50% of the in-transit barrels because that best represents the average delivery point of all barrels in our pipeline system. These deferred revenues and costs are determined using judgments and assumptions that management considers reasonable.
	Pipeline Over/Short Product. The tariffs we charge for our pipeline transportation systems are primarily regulated by the Federal Energy Regulatory Commission (“FERC”); however, certain tariffs are regulated by the Surface Transportation Board or state regulatory authorities. Our tariffs include provisions which allow us to deduct from our customer's inventory a small percentage of the products our customers transport on our pipeline systems. We refer to these product quantities as tender deductions. The purpose of these tender deductions is to help offset the product losses we sustain as a result of shrinkage, evaporation, protection of product quality and product measurement inaccuracies. We record these tender deductions as an increase of pipeline over/short product inventory and a reduction of operating expense. Each period end, we measure the volume of each type of product in our pipeline system, which is compared to the volumes of our customers' inventories (as adjusted for tender deductions).  To the extent that the product volumes in our pipeline system exceeds the volumes of our customers' book inventories, we increase our product inventories and recognize a gain; however, to the extent the product in our pipeline system is less than our customers' book inventories, we record a liability (for product owed to our customers) and recognize a loss.  The product gains and losses we recognize are recorded based on period-end product market prices, and we include those gains or losses in operating expenses on our consolidated statements of income.
	Excise Taxes Charged to Customers. Revenues are recorded net of all amounts charged to our customers for excise taxes.
	Equity-Based Incentive Compensation. The compensation committee of our general partner (the “compensation committee") has approved incentive awards of phantom units representing limited partner interests in us to certain employees. The awards granted include performance-based awards and retention awards, both of which include distribution equivalent rights. Further, the compensation committee has issued phantom units with distribution equivalent rights to our independent directors who have deferred the receipt of board fees into the director deferred compensation plan.
	Under ASC 718, Compensation-Stock Compensation, we classify unit awards as either equity or liabilities. Fair value for award grants classified as equity is determined on the grant date of the award, and we recognize this value as compensation expense ratably over the requisite service period, which is the vesting period of each unit award. Because all of our unit awards contain full distribution equivalent rights, the per-unit fair value of our equity awards is the closing price of our limited partner units on the grant date. However, the per-unit fair value of the equity awards we issued in 2014 also includes the fair value of the market-based component of those awards. Compensation expense for awards classified as equity is calculated as the number of unit awards classified as equity less estimated forfeitures, multiplied by the per unit grant date fair value of those awards, multiplied by the percentage of the requisite service period completed at each period end, multiplied by the expected payout percentage, less previously-recognized compensation expense. We re-measure unit awards classified as liabilities at fair value on the close of business at each reporting period end until settlement date. Fair value at each re-measurement date is the closing price of our limited partner units at each period end. Compensation expense for unit awards classified as liabilities is the number of unit awards classified as liabilities less estimated forfeitures, multiplied by the re-measured per-unit fair value of the awards, multiplied by the percentage of the requisite service period completed at each period end, multiplied by the expected payout percentage, less previously-recognized compensation expense.
	Performance-based awards include provisions that can result in payouts to the recipients of the 2013 awards of from 0% up to 250% of the targeted amount of the award and, to the recipients of the 2014 awards of from 0% to 200% of the targeted amount of the award. Additionally, the 2014 awards are subject to a market performance metric, which could increase or decrease the payout of the award by as much as 50%. Judgments and assumptions of the final award payouts are inherent in the accruals recorded for equity-based incentive compensation costs. The use of alternate judgments and assumptions could result in the recognition of different levels of equity-based incentive compensation costs.
	Payouts related to retention awards are based solely on the completion of the requisite service period by the employee. Retention awards contain no provisions which would provide for a payout to the employee of anything other than the original number of units awarded and the associated distribution equivalents.
	The vesting period for both the performance-based and retention awards is generally three years; however, certain awards have been issued with shorter vesting periods while others have vesting periods of up to four years. We settle vested non-director award grants by issuing new common units, except for the associated statutory minimum tax withholding, which we settle by paying with cash on hand. Phantom units issued to our directors are settled in cash in January of the year following their death or resignation from the board of directors of our general partner.
	Contingencies and Environmental. Certain conditions may exist as of the date our consolidated financial statements are issued that could result in a loss to us, but which will only be resolved when one or more future events occur or fail to occur. Our management assesses such contingent liabilities, which inherently involves significant judgment. In assessing loss contingencies related to legal proceedings that are pending against us or for unasserted claims that may result in proceedings, our management, with input from legal counsel, evaluates the perceived merits of any legal proceedings or unasserted claims as well as the perceived merits of the amount of relief sought or expected to be sought therein.
	Environmental expenditures are charged to operating expense or capitalized based on the nature of the expenditures. Environmental expenditures that meet the capitalization criteria for property, plant and equipment, as well as costs that mitigate or prevent environmental contamination that has yet to occur, are capitalized. We expense expenditures that relate to an existing condition caused by past operations. We record environmental liabilities assumed in a business combination at fair value, otherwise, we record environmental liabilities on an undiscounted basis. We recognize liabilities for other commitments and contingencies when, after analyzing the available information, we determine it is probable that an asset has been impaired, or that a liability has been incurred and the amount of impairment or loss can be reasonably estimated. When we can estimate a range of probable loss, we accrue the most likely amount within that range, or if no amount is more likely than another, we accrue the minimum of the range of probable loss. We expense legal costs associated with loss contingencies as incurred.
	We record environmental liabilities independently of any potential claim for recovery. Accruals related to environmental matters are generally determined based on site-specific plans for remediation, taking into account currently available facts, existing technologies and presently enacted laws and regulations. Accruals for environmental matters reflect our prior remediation experience and include an estimate for costs such as fees paid to contractors, outside engineering and consulting firms. Accruals for estimated losses from environmental remediation obligations generally are recognized no later than completion of the remediation feasibility study. Such accruals are adjusted as further information develops or circumstances change.
	We maintain selective insurance coverage, which may cover all or portions of certain environmental expenditures less a deductible. We recognize receivables in cases where we consider the realization of reimbursements of remediation costs as probable. We would sustain losses to the extent of amounts we have recognized as environmental receivables if the counterparties to those transactions were unable to perform their obligations to us.
	The determination of the accrual amounts recorded for environmental liabilities includes significant judgments and assumptions made by management. The use of alternate judgments and assumptions could result in the recognition of different levels of environmental remediation costs.
	Income Taxes. We are a partnership for income tax purposes and, therefore, have not been subject to federal or state income taxes for most of the states in which we operate. The tax on our net income is borne by the individual partners through the allocation of taxable income. Net income for financial statement purposes may differ significantly from taxable income of unitholders because of differences between the tax basis and financial reporting basis of assets and liabilities and the taxable income allocation requirements under our partnership agreement. The aggregate difference in the basis of our net assets for financial and tax reporting purposes cannot be readily determined because information regarding each partner's tax attributes is not available to us.
	As a publicly traded limited partnership, we are subject to a statutory requirement that our "qualifying income" (as defined by the Internal Revenue Code, related Treasury Regulations, and Internal Revenue Service pronouncements) exceed 90% of our total gross income, determined on a calendar year basis. If our qualifying income does not meet this statutory requirement, we could be taxed as a corporation for federal and state income tax purposes. For the years ended December 31, 2012, 2013 and 2014, our qualifying income met the statutory requirement.
	The amounts recognized as provision for income taxes in our consolidated statements of income reflect a partnership-level tax levied by the state of Texas. This tax is based on revenues less direct costs of sale for our assets apportioned to the state of Texas.
	Net Income Per Unit. We calculate basic net income per limited partner unit for each period by dividing net income by the weighted-average number of limited partner units outstanding. Diluted net income per limited partner unit for each period is the same calculation as basic net income per limited partner unit, except the weighted-average limited partner units outstanding includes the dilutive effect of phantom unit grants associated with our long-term incentive plan in periods where contingent performance metrics have been met.
	Comprehensive Income. We account for comprehensive income in accordance with ASC 220, Comprehensive Income. Comprehensive income was determined based on our net income adjusted for changes in other comprehensive income (loss) from unrealized gains or losses from derivative hedging transactions, reclassification of derivative gain and losses to net income and adjustments to record the periodic and settlement costs of our pension and postretirement benefit plans and our pension and postretirement benefit obligation liabilities at the funded status of the present value of the benefit obligations.
	Amounts included in accumulated other comprehensive loss ("AOCL") are as follows (in thousands):
		Derivative			Pension and			Accumulated
		Gains			Postretirement			Other
		(Losses)			Liabilities			Comprehensive
								Loss
	Balance, January 1, 2012	$	3,161		$	(50,362	)	$	(47,201	)
	Derivative activity:
	Net gain on cash flow hedges(1)	13,889			—			13,889
	Reclassification of net gain on cash flow hedges to income(1)	(2,924		)	—			(2,924		)
	Changes in employee benefit plan assets and benefit obligations recognized in other comprehensive income:
	Net actuarial loss(2)	—			(17,804		)	(17,804		)
	Plan amendment(2)	—			16,020			16,020
	Amortization of prior service credit(2)	—			(1,664		)	(1,664		)
	Amortization of actuarial loss(2)	—			4,626			4,626
	Balance, December 31, 2012	14,126			(49,184		)	(35,058		)
Derivative activity:
Net loss on cash flow hedges(1)	(4,744		)	—			(4,744		)
Reclassification of net loss on cash flow hedges to income(1)	4,245			—			4,245
Changes in employee benefit plan assets and benefit obligations recognized in other comprehensive income:
Net actuarial gain(2)	—			14,089			14,089
Amortization of prior service credit(2)	—			(3,405		)	(3,405		)
Amortization of actuarial loss(2)	—			5,369			5,369
Balance, December 31, 2013	13,627			(33,131		)	(19,504		)
Derivative activity:
Net loss on cash flow hedges(1)	(30,090		)	—			(30,090		)
Reclassification of net gain on cash flow hedges to income(1)	(124		)	—			(124		)
Changes in employee benefit plan assets and benefit obligations recognized in other comprehensive income:
Net actuarial loss(2)	—			(33,937		)	(33,937		)
Amortization of prior service credit(2)	—			(3,680		)	(3,680		)
Amortization of actuarial loss(2)	—			3,986			3,986
Settlement cost(2)	—			1,809			1,809
Balance, December 31, 2014	$	(16,587	)	$	(64,953	)	$	(81,540	)
(1) See Note 13–Derivative Financial Instruments for additional detail of the amount of gain (loss) recognized in AOCL on derivatives and the amount of (gain) loss reclassified from AOCL into income.
(2) See Note 10–Employee Benefit Plans for additional detail of the changes in employee benefit plan assets and benefit obligations that are recognized in other comprehensive income (loss).
New Accounting Pronouncements
In January 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update (“ASU”) 2015-01, Income Statement–Extraordinary and Unusual Items. This standard eliminates the concept of extraordinary and unusual items from U.S. GAAP. The new standard is effective for annual and interim periods after December 15, 2015.  Early adoption is permitted. We adopted this standard on January 1, 2015. Our adoption of this ASU did not have a material impact on our results of operations, financial position or cash flows.
In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements–Going Concern (Subtopic 205-40): Disclosure of Uncertainties About an Entity’s Ability to Continue as a Going Concern. This standard requires management to assess an entity’s ability to continue as a going concern, and to provide related footnote disclosures in certain circumstances. Before this standard, no accounting guidance existed for management on when and how to assess or disclose going concern uncertainties. The amendments are effective for annual periods ending after December 15, 2016, and interim periods within annual periods beginning after December 15, 2016. Early application is permitted. We adopted this standard on January 1, 2015. Our adoption of this ASU did not have a material impact on our results of operations, financial position or cash flows.
In June 2014, the FASB issued ASU 2014-12, Compensation–Stock Compensation (Topic 718):  Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period. This ASU finalizes the Emerging Issues Task Force’s Proposed ASU No. EITF-13D of the same name and seeks to resolve the diversity in practice that exists when accounting for share-based payments.  This ASU requires that a performance target that affects vesting and can be achieved after the requisite service period to be accounted for as a performance condition.  The new standard is effective for annual and interim periods after December 15, 2015.  Early adoption is permitted. We adopted this standard on January 1, 2015. Our adoption of this ASU did not have a material impact on our results of operations, financial position or cash flows.
In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers, which eliminates the industry-specific guidance in U.S. GAAP and produces a single, principles-based method for companies to report revenue in their financial statements. This standard requires companies to make more estimates and use more judgment than under current guidance. In addition, all companies must compile more extensive footnote disclosures about how the revenue numbers were derived. This ASU is effective for periods beginning January 1, 2017 and requires either a full retrospective or modified retrospective adoption. We have not yet determined which adoption method we will employ. Early adoption of this standard is not allowed. We are currently in the process of evaluating the impact this new standard will have on our financial statements.
In April 2014, the FASB issued ASU 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. This standard will limit the number of disposals of assets that should be presented as discontinued operations to those disposals that represent a strategic shift in operations and have a major effect on the organization's operations and financial results. Expanded disclosures will be required to provide more information about the assets, liabilities, income and expenses of discontinued operations as well as significant asset disposals that do not meet the criterion for discontinued operations treatment. This ASU will take effect for annual financial statements with fiscal years beginning on or after December 15, 2014. Our adoption of this ASU did not have a material impact on our results of operations, financial position or cash flows.

Consolidated_Statements_Of_Cas

Consolidated Statements Of Cash Flows - Supplemental Disclosures	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Consolidated Statements of Cash Flows	Consolidated Statements of Cash Flows
	Changes in the components of operating assets and liabilities are as follows (in thousands):
		Year Ended December 31,
		2012			2013			2014
	Trade accounts receivable and other accounts receivable	$	(10,867	)	$	(19,314	)	$	49,215
	Inventory	36,972			34,664			29,462
	Energy commodity derivatives contracts, net of derivatives deposits	16,097			534			(7,583		)
	Accounts payable	(11,175		)	2,002			(10,918		)
	Accrued payroll and benefits	2,250			9,809			6,055
	Accrued interest payable	1,512			2,876			1,038
	Accrued taxes other than income	5,519			5,485			9,094
	Accrued product purchases	12,249			(9,016		)	(18,678		)
	Deferred revenue	6,388			16,793			7,978
	Current and noncurrent environmental liabilities	(1,372		)	(12,247		)	(2,144		)
	Other current and noncurrent assets and liabilities	(13,510		)	(15,502		)	19,875
	Total	$	44,063		$	16,084		$	83,394
	Other current and noncurrent assets and liabilities above exclude certain non-cash items that were reflected in the consolidated balance sheet but were not reflected in the statement of cash flows. At December 31, 2012, 2013 and 2014, the long-term pension and benefits liability was increased (decreased) by $1.8 million, $(14.1) million and $33.9 million, respectively, resulting in a corresponding increase (decrease) in accumulated other comprehensive loss. Additionally, at December 31, 2014, associated with our interest rate hedges, other current liabilities were increased by $26.5 million resulting in a corresponding increase in accumulated other comprehensive loss.

Investments_in_NonControlled_E

Investments in Non-Controlled Entities Investments in Non-Controlled Entities (Notes)	12 Months Ended
	Dec. 31, 2014
Equity Method Investments and Joint Ventures [Abstract]
Investments in Non-Controlled Entities [Text Block]	Investments in Non-Controlled Entities
	Our investments in non-controlled entities are summarized below:
	Texas Frontera. We own a 50% interest in Texas Frontera, which owns approximately one million barrels of refined products storage at our Galena Park, Texas terminal. The storage capacity owned by this venture is leased to an affiliate of Texas Frontera under a long-term agreement. Texas Frontera began operations in October 2012. We receive management fees from Texas Frontera, which we report as affiliate management fee revenue on our consolidated statements of income.
	Osage. We own a 50% interest in Osage, which owns a 135-mile crude oil pipeline in Oklahoma and Kansas that we operate. We receive management fees from Osage, which we report as affiliate management fee revenue on our consolidated statements of income.
	Double Eagle. We own a 50% interest in Double Eagle, which transports condensate from the Eagle Ford shale formation in South Texas via a 195-mile pipeline to our terminal in Corpus Christi, Texas. Double Eagle began operations in 2013. Double Eagle is operated by an affiliate of the other 50% member of Double Eagle. We receive throughput revenue from Double Eagle that is included in our transportation and terminals revenue on our consolidated statements of income. For the years ended December 31, 2013 and 2014, we received throughput revenue of $1.4 million and $2.7 million, respectively, and recognized a $0.2 million and $0.3 million trade accounts receivable from Double Eagle at December 31, 2013 and 2014, respectively.
	BridgeTex. We own a 50% interest in BridgeTex, which owns a 400-mile pipeline with related infrastructure that transports crude oil to our East Houston terminal for further distribution to refineries in the Gulf Coast region. The BridgeTex pipeline began commercial operations in September 2014. During 2014, we received construction management fees, and in September 2014, we began receiving operating management fees from BridgeTex, which we report as affiliate management fee revenue on our consolidated statements of income. As of December 31, 2014, we had recorded a $2.2 million liability to BridgeTex for construction management fees pre-paid to us.
	In November 2014, we acquired from a subsidiary of Occidental Petroleum Corporation ("Oxy") their ownership in a 40-mile crude oil pipeline in the Houston Gulf Coast area (see Note 5 – Business Combination and Asset Acquisition for further details regarding this transaction). In connection with this transaction, we entered into a long-term lease agreement with BridgeTex for capacity on our Houston area crude oil distribution system. We recognized $2.6 million of capacity lease revenue from this agreement during 2014, which was included in transportation and terminals revenue on our consolidated statements of income. As of December 31, 2014, we had recognized a $2.6 million receivable from BridgeTex associated with this agreement.
	The operating results of Texas Frontera are included in our marine storage segment and the operating results of Osage, Double Eagle and BridgeTex are included in our crude oil segment.
	A summary of our investments in non-controlled entities follows (in thousands):
		BridgeTex			All Others			Consolidated
	Investments at December 31, 2013	$	246,875		$	113,977		$	360,852
	Additional investment	392,812			15,189			408,001
	Adjustment to investment due to the distribution of assets to owners	(165,157		)	—			(165,157		)
	Other adjustment to investment	—			(650		)	(650		)
	Earnings of non-controlled entities:
	Proportionate share of earnings	15,348			5,326			20,674
	Amortization of excess investment and capitalized interest	(530		)	(750		)	(1,280		)
	Earnings of non-controlled entities	14,818			4,576			19,394
	Less:
	Distributions of earnings from investments in non-controlled entities	—			3,086			3,086
	Distributions in excess of earnings of non-controlled entities	—			5,487			5,487
	Investments at December 31, 2014	$	489,348		$	124,519		$	613,867
	Summarized financial information of our non-controlled entities as of and for the year ended December 31, 2014 follows (in thousands):
		BridgeTex			All Others			Consolidated
	Current assets	$	66,409		$	11,032		$	77,441
	Noncurrent assets	821,323			210,587			1,031,910
	Total assets	$	887,732		$	221,619		$	1,109,351
	Current liabilities	$	71,066		$	4,724		$	75,790
	Noncurrent liabilities	94			1,783			1,877
	Total liabilities	$	71,160		$	6,507		$	77,667
	Equity	$	816,572		$	215,112		$	1,031,684
	Revenue	$	49,200		$	34,856		$	84,056
	Net income	$	30,696		$	10,583		$	41,279

Business_Combinations_and_Asse

Business Combinations and Asset Acquisitions (Notes)	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Business Combination Disclosure	Business Combination and Asset Acquisition
	2013 Business Combination. During 2013, we acquired certain refined petroleum products pipelines and terminals from Plains All American Pipeline, L.P. We have accounted for this acquisition as a business combination under the acquisition method of accounting in accordance with ASC 805, Business Combinations. The acquisition was completed in two parts, as follows:
	•	New Mexico/Texas System. In July 2013, we acquired approximately 250-miles of common carrier pipeline that transports refined petroleum products from El Paso, Texas north to Albuquerque, New Mexico and transports products south to the United States–Mexico border for delivery within Mexico via a third-party pipeline for $57.0 million. We funded this acquisition with cash on hand.
	•	Rocky Mountain System. In November 2013, we acquired approximately 550 miles of common carrier pipeline that distributes refined petroleum products in Colorado, South Dakota and Wyoming for $135.0 million. The system includes four terminals with nearly 1.7 million barrels of storage. We funded this acquisition primarily with proceeds from our $300.0 million debt offering we completed in October 2013.
	The final purchase price and assessment of the fair value of the assets acquired and liabilities assumed in the business combination we completed during 2013 were as follows (in thousands):
	Purchase price allocation:	$	192,000
	Fair value of assets acquired (liabilities assumed):
	Property, plant and equipment	$	192,422
	Other current assets	2,048
	Current environmental liabilities	(2,470		)
	Total	$	192,000
	The following amounts from this business combination were included in our operating results for the year ending December 31, 2013 (in thousands):
	Revenue		$	12,661
	Operating profit		$	6,400
	The following summarized pro forma consolidated income statement information assumes that this acquisition of a business during 2013 referred to above occurred as of January 1, 2012. These pro forma results are for comparative purposes only and may not be indicative of the results that would have occurred had this acquisition been completed on January 1, 2012 or the results that will be attained in the future (in thousands).
			Year Ended December 31, 2012				Year Ended December 31, 2013
			As Reported		Pro Forma		As Reported		Pro Forma
	Revenue		$	1,772,074	$	1,812,635	$	1,897,606	$	1,924,316
	Net income		$	435,670	$	442,096	$	582,237	$	591,377
	Significant pro forma adjustments include historical results of the acquired assets and our calculation of G&A expense, depreciation expense and interest expense on borrowings necessary to finance this acquisition. Acquisition and start-up costs related to the assets acquired totaling $2.8 million were recorded to operating expenses during 2013. These costs were reclassified from 2013 to 2012, as the acquisition was assumed to have been completed January 1, 2012 for this presentation.
	2014 Asset Acquisition. In November 2014, in connection with Oxy's sale of its ownership interest in BridgeTex to a third party, we acquired from a subsidiary of Oxy its ownership interest in a 40-mile crude oil pipeline that extends from our East Houston, Texas terminal to Texas City, Texas, and 1.4 million barrels of crude oil tankage and related infrastructure at the East Houston, Texas terminal for $75.0 million. At the time of this acquisition, construction of the crude oil storage tankage was complete; however, only a portion of the pipeline construction from East Houston to Texas City, Texas had been completed. Following this transaction, our ownership in these assets was 100%. Concurrent with this transaction, BridgeTex entered into a long-term lease agreement for capacity on our Houston-area crude oil distribution system.

Inventory

Inventory	12 Months Ended
	Dec. 31, 2014
Inventory Disclosure [Abstract]
Inventory	Inventory
	Inventory at December 31, 2013 and 2014 was as follows (in thousands):
		December 31,
		2013		2014
	Refined products	$	77,144	$	67,055
	Liquefied petroleum gases	23,476		37,642
	Transmix	72,156		36,867
	Crude oil	7,188		10,015
	Additives	7,260		6,183
	Total inventory	$	187,224	$	157,762

Product_Sales_Revenue

Product Sales Revenue	12 Months Ended
	Dec. 31, 2014
Product Sales Revenue [Abstract]
Product Sales Revenue	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 NYMEX contracts. See Note 2 – Summary of Significant Accounting Policies – Derivative Financial Instruments for a discussion of how derivative agreements impact our product sales. Further, see Note 13 – Derivative Financial Instruments for disclosures regarding our NYMEX contracts.
	For the years ended December 31, 2012, 2013 and 2014, product sales revenue included the following (in thousands):
		Year Ended December 31,
		2012			2013			2014
	Physical sale of refined products	$	833,581		$	755,266		$	733,654
	NYMEX contract adjustments:
	Change in value of NYMEX contracts that did not qualify for hedge accounting treatment and the effective portion of gains and losses of matured NYMEX contracts that qualified for hedge accounting treatment associated with our butane blending and fractionation activities(1)	(30,270		)	(10,586		)	145,308
	Change in value of NYMEX contracts that did not qualify for hedge accounting treatment associated with the Houston-to-El Paso pipeline section linefill working inventory(1)	(3,940		)	—			—
	Other	11			(11		)	12
	Total NYMEX contract adjustments	(34,199		)	(10,597		)	145,320
	Total product sales revenue	$	799,382		$	744,669		$	878,974
	(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.

Property_Plant_And_Equipment

Property, Plant And Equipment	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant And Equipment	Property, Plant and Equipment
	Property, plant and equipment consisted of the following (in thousands):
						Estimated  Depreciable Lives
		December 31,
		2013		2014
	Construction work-in-progress	$	165,129	$	314,349
	Land and rights-of-way	78,405		75,219
	Carrier property	2,135,905		2,231,319		7 to 59 years
	Buildings	41,383		45,567		20 to 55 years
	Storage tanks	1,141,271		1,198,758		10 to 40 years
	Pipeline and station equipment	593,396		715,891		3 to 59 years
	Processing equipment	716,103		826,587		3 to 56 years
	Other	115,158		126,245		3 to 48 years
	Property, Plant and Equipment, Gross	$	4,986,750	$	5,533,935
	Carrier property is defined as pipeline assets regulated by the FERC. Other includes total interest capitalized as of December 31, 2013 and 2014 of $33.2 million and $35.8 million, respectively. Depreciation expense for the years ended December 31, 2012, 2013 and 2014 was $126.7 million, $136.4 million and $159.0 million, respectively.

Major_Customers_and_Concentrat

Major Customers and Concentration Of Risks	12 Months Ended
	Dec. 31, 2014
Major Customers and Concentration Of Risks [Abstract]
Major Customers and Concentration Of Risks	Major Customers and Concentration of Risks
	Major Customers. One customer accounted for 14%, 8% and 12% of our consolidated total revenue in 2012, 2013 and 2014, respectively. No other customer accounted for more than 10% of our consolidated revenues during these years. The majority of revenue from this customer resulted from sale of refined products that were generated in connection with our butane blending and fractionation activities, which are activities conducted by our refined products segment. We believe that other companies would purchase the petroleum products from us if this customer were unable or unwilling to do so.
	Concentration of Risks. We transport, store and distribute refined products for refiners, marketers, traders and end users of those products. We derive the major concentration of our revenue and trade receivables from activities conducted in the central U.S. We generally secure transportation and storage revenue with warehouseman's liens. We periodically evaluate the financial condition and creditworthiness of our customers and require additional security as we deem necessary. These concentrations of customers may affect our overall credit risk as our customers may be similarly affected by changes in economic, regulatory or other factors.
	As of December 31, 2014, we had 1,565 employees, 880 of which were assigned to our refined products segment and concentrated in the central U.S.  Approximately 26% of the 880 employees are represented by the United Steel Workers (“USW”) and were covered by a collective bargaining agreement that expired January 31, 2015 (see Note 22 – Subsequent Events for additional information regarding the renegotiation of this agreement). At December 31, 2014, 88 of our employees were assigned to our crude oil segment and were concentrated in the central U.S., and none of these employees were covered by a collective bargaining agreement.  The labor force of 169 employees assigned to our marine storage segment at December 31, 2014 was primarily located in the Gulf and East Coast regions of the U.S.  Approximately 17% of these employees were represented by the International Union of Operating Engineers (“IUOE”) and covered by a collective bargaining agreement that expires October 31, 2016.

Employee_Benefit_Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
Employee Benefit Plans	Employee Benefit Plans
	We sponsor two union pension plans that cover certain union employees (“USW plan” and “IUOE plan,” collectively, the "Union plans") and a pension plan for all non-union employees (“Salaried plan”), a postretirement benefit plan for certain employees and a defined contribution plan.
	The annual measurement date of these plans is December 31. The following table presents the changes in benefit obligations and plan assets for pension benefits and other postretirement benefits for the years ended December 31, 2013 and 2014 (in thousands):
			Pension Benefits							Other Postretirement Benefits
			2013				2014			2013				2014
	Change in benefit obligation:
	Benefit obligation at beginning of year		$	142,703			$	142,310		$	13,195			$	10,418
	Service cost		13,901				13,400			288				227
	Interest cost		5,368				6,675			412				506
	Plan participants’ contributions		—				—			248				210
	Actuarial loss (gain)		(14,121		)		37,934			(2,675		)		1,951
	Benefits paid		(5,541		)		(4,196		)	(1,050		)		(866		)
	Settlement payments		—				(5,460		)	—				—
	Benefit obligation at end of year		142,310				190,663			10,418				12,446
	Change in plan assets:
	Fair value of plan assets at beginning of year		87,106				100,556			—				—
	Employer contributions		15,470				24,056			802				656
	Plan participants’ contributions		—				—			248				210
	Actual return on plan assets		3,521				12,311			—				—
	Benefits paid		(5,541		)		(4,196		)	(1,050		)		(866		)
	Settlement payments		—				(5,460		)	—				—
	Fair value of plan assets at end of year		100,556				127,267			—				—
	Funded status at end of year		$	(41,754	)		$	(63,396	)	$	(10,418	)		$	(12,446	)
	Accumulated benefit obligation		$	103,466			$	137,851
	The amounts included in pension benefits in the previous table combine the Union plans with the Salaried plan. At December 31, 2013, the Union plans had a combined projected benefit obligation of $47.7 million and a combined accumulated benefit obligation of $41.1 million, which exceeded the combined fair value of plan assets of $36.6 million. At December 31, 2014, the fair value of each of the pension plans' assets was less than the fair values of the respective accumulated benefit obligations.
	The 2013 actuarial gain of $14.1 million for our pension plans was due primarily to the impact of increases in the discount rate used to calculate the benefit obligation. The 2014 actuarial loss of $37.9 million was due primarily to the impact of decreases in the discount rate used to calculate the benefit obligation, combined with a change to the mortality rates using RP-2014 mortality tables.
	Amounts recognized in the consolidated balance sheets included in these financial statements were as follows (in thousands):
			Pension Benefits							Other Postretirement Benefits
			2013				2014			2013				2014
	Amounts recognized in consolidated balance sheets:
	Current accrued benefit cost		$	—			$	—		$	(535	)		$	(687	)
	Long-term pension and benefit cost		(41,754		)		(63,396		)	(9,883		)		(11,759		)
			(41,754		)		(63,396		)	(10,418		)		(12,446		)
	Accumulated other comprehensive loss:
	Net actuarial loss		36,151				63,257			7,708				8,744
	Prior service cost (credit)		33				—			(10,761		)		(7,048		)
			36,184				63,257			(3,053		)		1,696
	Net amount recognized in consolidated balance sheets		$	(5,570	)		$	(139	)	$	(13,471	)		$	(10,750	)
	Net periodic benefit expense for the years ended December 31, 2012, 2013 and 2014 were as follows (in thousands):
			Pension Benefits											Other  Postretirement Benefits
			2012				2013			2014				2012			2013			2014
	Components of net periodic pension and postretirement benefit expense:
	Service cost		$	12,222			$	13,901		$	13,400			$	396		$	288		$	227
	Interest cost		4,862				5,368			6,675				821			412			506
	Expected return on plan assets		(5,066		)		(6,228		)	(6,363		)		—			—			—
	Amortization of prior service cost (credit)		307				307			33				(1,971		)	(3,712		)	(3,713		)
	Amortization of actuarial loss		3,605				4,334			3,071				1,021			1,035			915
	Settlement cost(1)		—				—			1,809				—			—			—
	Net periodic expense (credit)		$	15,930			$	17,682		$	18,625			$	267		$	(1,977	)	$	(2,065	)
	(1) Eleven participants took a lump sum distribution from the USW plan in 2014, resulting in a pension settlement cost of $1.8 million.
	Other changes in plan assets and benefit obligations recognized in other comprehensive loss during 2013 and 2014 were as follows (in thousands):
			Pension Benefits							Other Postretirement Benefits
			2013				2014			2013				2014
	Other changes in plan assets and benefit obligations recognized in other comprehensive loss:
	Net actuarial loss (gain)		$	(11,414	)		$	31,986		$	(2,675	)		$	1,951
	Amortization of prior service credit (cost)		(307		)		(33		)	3,712				3,713
	Amortization of actuarial loss		(4,334		)		(3,071		)	(1,035		)		(915		)
	Settlement cost		—				(1,809		)	—				—
	Total recognized in other comprehensive loss		(16,055		)		27,073			2				4,749
	Net periodic expense (credit)		17,682				18,625			(1,977		)		(2,065		)
	Total recognized in net periodic benefit cost and other comprehensive loss		$	1,627			$	45,698		$	(1,975	)		$	2,684
	We match our employees' qualifying contributions to our defined contribution plan, resulting in expense to us. Expenses related to the defined contribution plan were $6.5 million, $7.1 million and $8.3 million in 2012, 2013 and 2014, respectively.
	Actuarial gains and losses are amortized over the average future service period of current active plan participants expected to receive benefits. The corridor approach is used to determine when actuarial gains and losses are to be amortized and is equal to 10 percent of the greater of the projected benefit obligation or the market related value of plan assets. The amount of gain or loss in excess of the calculated corridor is subject to amortization. The estimated net actuarial loss for the defined benefit pension plans that will be amortized from AOCL into net periodic benefit cost in 2015 is $5.4 million. The estimated net actuarial loss and prior service credit for the other defined benefit postretirement plan that will be amortized from AOCL into net periodic benefit cost in 2015 are $0.9 million and $(3.7) million, respectively.
	The weighted-average rate assumptions used to determine benefit obligations as of December 31, 2013 and 2014 were as follows:
		Pension Benefits				Other
						Postretirement Benefits
		2013		2014		2013		2014
Discount rate—Salaried plan		4.89%		3.91%		n/a		n/a
Discount rate—USW plan		4.26%		3.56%		n/a		n/a
Discount rate—IUOE plan		4.89%		3.93%		n/a		n/a
Discount rate—Other Postretirement Benefits		n/a		n/a		4.52%		3.66%
Rate of compensation increase—Salaried plan		5.00%		5.00%		n/a		n/a
Rate of compensation increase—USW plan		3.50%		3.50%		n/a		n/a
Rate of compensation increase—IUOE plan		5.00%		5.00%		n/a		n/a
The weighted-average rate assumptions used to determine net pension and other postretirement benefit expense for the years ended December 31, 2012, 2013 and 2014 were as follows:
		Pension Benefits						Other
								Postretirement Benefits
		2012		2013		2014		2012	2013			2014
Discount rate—Salaried plan		4.39%		4.00%		4.89%		n/a	n/a			n/a
Discount rate—USW plan		4.00%		3.39%		4.07%		n/a	n/a			n/a
Discount rate—IUOE plan		4.37%		3.99%		4.89%		n/a	n/a			n/a
Discount rate—Other Postretirement Benefits		n/a		n/a		n/a		3.75%	3.58	%		4.52	%
Rate of compensation increase—Salaried plan		5.00%		5.00%		5.00%		n/a	n/a			n/a
Rate of compensation increase—USW plan		3.50%		3.50%		3.50%		n/a	n/a			n/a
Rate of compensation increase—IUOE plan		5.00%		5.00%		5.00%		n/a	n/a			n/a
Expected rate of return on plan assets—Salaried plan		6.80%		6.80%		6.00%		n/a	n/a			n/a
Expected rate of return on plan assets—USW plan		6.80%		6.80%		6.00%		n/a	n/a			n/a
Expected rate of return on plan assets—IUOE plan		6.80%		6.80%		6.00%		n/a	n/a			n/a
The 2014 discount rate for the USW plan reflects a combination of the rates prior to and after the lump sum settlement payments made during 2014.
The non-pension postretirement benefit plans provide for retiree contributions and contain other cost-sharing features such as deductibles and coinsurance. The accounting for these plans anticipates future cost sharing that is consistent with management's expressed intent to increase the retiree contribution rate generally in line with health care cost increases.
The annual assumed rate of increase in the health care cost trend rate for 2015 is 5.8% decreasing systematically to 4.6% by 2083 for pre-65 year-old participants. The health care cost trend rate assumption has a significant effect on the amounts reported. As of December 31, 2014, a 1.0% change in assumed health care cost trend rates would have the following effect (in thousands):
		1%				1%
		Increase				Decrease
Change in total of service and interest cost components		$	31			$	28
Change in postretirement benefit obligation		$	566			$	519
The fair value of the pension plan assets at December 31, 2013 were as follows (in thousands):
Asset Category		Total				Quoted Prices in Active  Markets for			Significant				Significant
						Identical Assets			Observable				Unobservable
						(Level 1)			Inputs				Inputs
									(Level 2)				(Level 3)
Domestic Equity Securities(a):
Small-cap fund		$	2,480			$	2,480		$	—			$	—
Mid-cap fund		2,465				2,465			—				—
Large-cap fund		18,642				18,642			—				—
International equity fund		11,793				11,793			—				—
Fixed Income Securities(a):
Short-term bond funds		3,243				3,243			—				—
Intermediate-term bond funds		12,492				12,492			—				—
Long-term investment grade bond fund		45,900				45,900			—				—
Other:
Short-term investment funds		3,244				3,244			—				—
Group annuity contract		297				—			—				297
Fair value of plan assets		$	100,556			$	100,259		$	—			$	297
(a) We hold equity and fixed income securities through investments in mutual funds, which are dedicated to each category as indicated.
The fair value of the pension plan assets at December 31, 2014 were as follows (in thousands):
Asset Category		Total				Quoted Prices in Active  Markets for			Significant				Significant
						Identical Assets			Observable				Unobservable
						(Level 1)			Inputs				Inputs
									(Level 2)				(Level 3)
Domestic Equity Securities(a):
Small-cap fund		$	3,050			$	3,050		$	—			$	—
Mid-cap fund		3,025				3,025			—				—
Large-cap fund		22,760				22,760			—				—
International equity fund		13,990				13,990			—				—
Fixed Income Securities(a):
Short-term bond funds		3,485				3,485			—				—
Intermediate-term bond funds		19,713				19,713			—				—
Long-term investment grade bond funds		56,361				56,361			—				—
Other:
Short-term investment funds		4,603				4,603			—				—
Group annuity contract		280				—			—				280
Fair value of plan assets		$	127,267			$	126,987		$	—			$	280
(a) We hold equity and fixed income securities through investments in mutual funds, which are dedicated to each category as indicated.
The group annuity contract is valued at contract value, which approximates fair value as determined by the contract provider. The balance at the end of the year represents total contributions plus interest earned less benefit payments and expenses paid. The group annuity contract is guaranteed a specified return, by the Metropolitan Life Insurance Company, based on the Barclay's Capital Aggregate Bond Fund return. The fair value measurements for the group annuity contract which used significant unobservable inputs (Level 3) for the years ended December 31, 2013 and 2014 were as follows (in thousands):
	2013				2014
Beginning balance	$	358			$	297
Actual return on plan assets:
Relating to assets still held at the reporting date	(7		)		17
Purchases, issuances, sales and settlements:
Settlements	(54		)		(34		)
Ending balance	$	297			$	280
The investment strategies for the various funds held as pension plan assets by asset category are as follows:
Asset Category		Fund’s Investment Strategy
Domestic Equity Securities:
Small-cap fund		Seeks to track performance of the Center for Research in Security Prices ("CRSP") US Small Cap Index
Mid-cap fund		Seeks to track performance of the CRSP US Mid Cap Index
Large-cap fund		Seeks to track performance of the Standard & Poor’s 500 Index
International equity fund		Seeks long-term growth of capital by investing 65% or more of assets in international equities
Fixed Income Securities:
Short-term bond funds		Seeks current income with limited price volatility through investment in primarily high quality bonds
Intermediate-term bond funds		Seeks moderate and sustainable level of current income by investing primarily in high quality fixed income securities with maturities from five to ten years
Long-term investment grade bond funds		Seeks high and sustainable current income through investment primarily in long-term high grade bonds
Other:
Short-term investment funds		Invests primarily in high quality commercial paper and government securities
Group annuity contract		Guarantees a specified return based on a specified index
The expected long-term rate of return on plan assets was determined by combining a review of projected returns, historical returns of portfolios with assets similar to the current portfolios of the union and non-union pension plans and target weightings of each asset classification. Our investment objective for the assets within the pension plans is to earn a return that meets or exceeds the growth of its obligations that result from interest and changes in the discount rate, while avoiding excessive risk. Defined diversification goals are set in order to reduce the risk of wide swings in the market value from year to year, or of incurring large losses that may result from concentrated positions. As a result, our plan assets have no significant concentrations of credit risk. Additionally, liquidity risks are minimized because all of the funds that the plans have invested in are publicly traded. We evaluate risks based on the potential impact of the predictability of contribution requirements, probability of under-funding, expected risk-adjusted returns and investment return volatility. Funds are invested with multiple investment managers. Our segment liabilities are calculated using rates defined by the Pension Protection Act of 2006. Investments are made so as to match the durations of the short and intermediate term liabilities. Additional investments are made to bring the overall investment allocation to 70% debt securities and 30% equity securities.
The target allocation and actual weighted-average asset allocation percentages at December 31, 2013 and 2014 were as follows:
		2013				2014
		Actual(a)		Target		Actual(a)		Target
Equity securities		35%		30%		34%		30%
Debt securities		62%		67%		62%		67%
Other		3%		3%		4%		3%
(a)	Cash contributions of $15.5 million and $24.1 million were made to the pension plans during 2013 and 2014, respectively. Amounts contributed in 2013 and 2014 in excess of benefit payments made were to be invested in debt and equity securities over a twelve-month period, with the amounts that remained uninvested as of December 31, 2013 and 2014 scheduled for investment in accordance with the target. Excluding these uninvested cash amounts, the actual allocation percentages at December 31, 2013 would have been 36% equity securities and 64% debt securities and at December 31, 2014, would have been 35% equity securities and 65% debt securities. In 2015, we will invest these uninvested cash amounts to bring the total asset allocation in line with the target allocation.
As of December 31, 2014, the benefit amounts we expect to pay through December 31, 2024 were as follows (in thousands):
		Pension				Other
		Benefits				Postretirement
						Benefits
2015		$	5,994			$	687
2016		$	6,653			$	631
2017		$	10,170			$	655
2018		$	10,185			$	681
2019		$	10,597			$	756
2020 through 2024		$	72,278			$	4,497
Contributions estimated to be paid into the plans in 2015 are $21.1 million and $0.7 million for the pension and other postretirement benefit plans, respectively.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions
	Barry R. Pearl is an independent member of our general partner's board of directors and is also a director of Targa Resources Partners, L.P. ("Targa"). In the normal course of business, we purchase butane from subsidiaries of Targa. For the years ended December 31, 2012, 2013 and 2014, we made purchases of butane from subsidiaries of Targa of $27.4 million, $30.4 million and $28.2 million, respectively. These purchases were made on the same terms as comparable third-party transactions. We had recognized payables to Targa of $1.0 million and $0.9 million at December 31, 2013 and 2014, respectively.
	See Note 4 – Investments in Non-Controlled Entities for a discussion of affiliate joint venture transactions we account for under the equity method.

Debt

Debt	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt	Debt
	Debt at December 31, 2013 and 2014 was as follows (in thousands):
							Weighted-Average Interest Rate at December 31, 2014 (1)
			December 31,
			2013		2014
	Commercial paper(2)		$	—	$	296,942	0.30%
	Revolving credit facility(2)		—		—		1.30%
	$250.0 million of 6.45% Notes due 2014(2)		249,971		—		6.30%
	$250.0 million of 5.65% Notes due 2016		251,183		250,758		5.70%
	$250.0 million of 6.40% Notes due 2018		259,346		257,280		5.40%
	$550.0 million of 6.55% Notes due 2019		571,515		567,868		5.70%
	$550.0 million of 4.25% Notes due 2021		557,213		556,304		4.00%
	$250.0 million of 6.40% Notes due 2037		248,998		249,017		6.40%
	$250.0 million of 4.20% Notes due 2042		248,377		248,406		4.20%
	$550.0 million ($300.0 million at December 31, 2013) of 5.15% Notes due 2043(2)		298,684		556,320		5.10%
	Total debt		$	2,685,287	$	2,982,895	4.90%
	-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 year ending December 31, 2014 (borrowings on our revolving credit facility and senior notes due 2014 were repaid before year end). 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 outstanding debt at December 31, 2013 and 2014 was $2.7 billion and $2.9 billion, respectively. The difference between the face value and carrying value of the debt outstanding is the unamortized portion of terminated fair value hedges and the unamortized discounts and premiums on debt issuances. Realized gains and losses on fair value hedges and note discounts and premiums are being amortized or accreted to the applicable notes over the respective lives of those notes. At December 31, 2014, maturities of our debt were as follows: $0 in 2015; $250.0 million in 2016; $0 in 2017; $546.9 million in 2018 (includes $296.9 million outstanding under our commercial paper program consistent with the maturity date of our revolving credit facility); $550.0 million in 2019; and $1.6 billion thereafter.
	2014 Debt Offering
	In March 2014, we issued $250.0 million of our 5.15% notes due October 15, 2043 in an underwritten public offering. The notes were issued at 103.1% of par. We used the net proceeds from this offering of approximately $255.0 million, after underwriting discounts and offering expenses of $2.7 million, to repay borrowings outstanding under our revolving credit facility and for general partnership purposes, including expansion capital.
	Other Debt
	Revolving Credit Facility. The total borrowing capacity under our revolving credit facility, which matures in November 2018, is $1.0 billion. Borrowings outstanding under the facility are classified as long-term debt on our consolidated balance sheets. Borrowings under the facility are unsecured and bear interest at LIBOR plus a spread ranging from 1.0% to 1.75% based on our credit ratings. Additionally, an unused commitment fee is assessed at a rate from 0.10% to 0.28%, depending on our credit ratings, which was 0.125% at December 31, 2014. Borrowings under this facility may be used for general purposes, including capital expenditures. As of December 31, 2014, there were no borrowings outstanding under this facility with $5.6 million 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.
	Our revolving credit facility requires us to maintain a specified ratio of consolidated debt to EBITDA (as defined in the credit agreement) of no greater than 5.0 to 1.0. In addition, the revolving credit facility and the indentures under which our senior notes were issued contain covenants that limit our ability to, among other things, incur indebtedness secured by certain liens or encumber our assets, engage in certain sale-leaseback transactions and consolidate, merge or dispose of all or substantially all of our assets. We were in compliance with these covenants as of and during the year ended December 31, 2014.
	Commercial Paper Program. In April 2014, we initiated a commercial paper program. The maturities of the commercial paper notes vary, but may not exceed 397 days from the date of issuance. The commercial paper notes are sold under customary terms in the commercial paper market and are issued at a discount from par, or alternatively, are sold at par and bear varying interest rates on a fixed or floating basis. The commercial paper we can issue is limited by the amounts available under our revolving credit facility up to an aggregate principal amount of $1.0 billion. We have the ability and intent to refinance all of our commercial paper obligations on a long-term basis; therefore, we have elected to classify our commercial paper borrowings outstanding as long-term debt on our consolidated balance sheets. In second quarter 2014, proceeds from commercial paper borrowings were used to repay our $250.0 million of 6.45% senior notes that were due June 1, 2014. Additional commercial paper borrowings have been used for general partnership purposes, including expansion capital.
	During the years ending December 31, 2012, 2013 and 2014, total cash payments for interest on all indebtedness, excluding the impact of related interest rate swap agreements, were $123.3 million, $134.6 million and $149.5 million, respectively.

Derivative_Financial_Instrumen

Derivative Financial Instruments	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	Derivative Financial Instruments
	Interest Rate Derivatives
	We periodically enter into interest rate derivatives to economically hedge debt, interest or expected debt issuances, and we have historically designated these derivatives as cash flow or fair value hedges for accounting purposes. Adjustments resulting from discontinued hedges continue to be recognized in accordance with their historic hedging relationships.
	Interest Rate Derivatives Activity During 2014. In third and fourth quarter 2014, we entered into $250.0 million of forward-starting interest rate swap agreements to hedge against the risk of variability of 60 semi-annual future interest payments on a portion of debt we anticipate issuing in the next year. The fair value of these contracts at December 31, 2014 was a liability of $26.5 million. We account for these agreements as cash flow hedges.
	In first quarter 2014, we entered into $200.0 million of interest rate swap agreements to hedge against the variability of future interest payments on an anticipated debt issuance. We accounted for these agreements as cash flow hedges. When we issued $250.0 million of 5.15% notes due 2043 later in the first quarter of 2014, we settled the associated interest rate swap agreements for a loss of $3.6 million. The loss was recorded to other comprehensive income and is being recognized into earnings as an adjustment to our periodic interest expense accruals over the life of the associated notes. This loss was also reported as net payment on financial derivatives in the financing activities of our consolidated statements of cash flows.
	Interest Rate Derivatives Activity During 2013. In September 2013, we entered into $150.0 million of Treasury lock contracts to hedge against the risk of variability of future interest payments on a portion of the debt we issued in early October 2013. We accounted for these contracts as cash flow hedges. These contracts were settled on October 3, 2013 for a loss of $0.2 million. The loss was recorded to other comprehensive income and will be recognized into earnings as an adjustment to our periodic interest accruals over the next 30 years to coincide with interest payments on the underlying debt.
	Interest Rate Derivatives Activity During 2012. During 2012, we entered into a total of $250.0 million of forward-starting interest rate swap agreements to hedge against the variability of 60 semi-annual future interest payments on debt that we anticipated issuing to refinance our $250.0 million of 6.45% notes due June 1, 2014. These forward-starting interest rate swap agreements were accounted for as cash flow hedges. In November 2012, we terminated and settled these agreements and realized a gain of $11.0 million, which was recorded to other comprehensive income as a deferred cash flow hedging gain. We recognized ineffectiveness in earnings on this deferred hedging gain of $0.4 million for the year ended December 31, 2014 due to timing of our debt refinancing.
	Commodity Derivatives
	Hedging Strategies
	Our butane blending activities produce gasoline products, and we can reasonably estimate the timing and quantities of sales of these products. We use a combination of forward purchase and sale contracts, NYMEX contracts and CME butane futures agreements to help manage commodity price changes, which has the effect of locking in most of the product margin realized from our butane blending activities that we choose to hedge.
	We account for the forward physical purchase and sale contracts we use in our butane blending and fractionation activities as normal purchases and sales. Forward contracts that qualify for and are elected as normal purchases and sales are accounted for using traditional accrual accounting. As of December 31, 2014, we had commitments under these forward purchase and sale contracts as follows (in millions):
		Notional Value				Barrels
	Forward purchase contracts	$	108.2			2.8
	Forward sale contracts	$	0.5			—
	We use NYMEX contracts to hedge against changes in the price of refined products we expect to sell in future periods. Our NYMEX contracts fall into one of three hedge types:
	Hedge Type		Hedge Purpose		Accounting Treatment
	Qualifies for Hedge Accounting Treatment
	Cash Flow Hedge		To hedge the variability in cash flows related to a forecasted transaction.		The effective portion of changes in the value of the hedge is recorded to accumulated other comprehensive income/loss and reclassified to earnings when the forecasted transaction occurs. Any ineffectiveness is recognized currently in earnings.
	Fair Value Hedge		To hedge against changes in the fair value of a recognized asset or liability.		The effective portion of changes in the value of the hedge is recorded as adjustments to the asset or liability being hedged. Any ineffectiveness is recognized currently in earnings.
	Does not Qualify For Hedge Accounting Treatment
	Economic Hedge		To effectively serve as either a fair value or a cash flow hedge; however, the derivative agreement does not qualify for hedge accounting treatment under ASC 815, Derivatives and Hedging.		Changes in the value of these agreements are recognized currently in earnings.
	Period changes in the fair value of NYMEX agreements that are accounted for as economic hedges, other than those economic hedges of our pipeline product overages (see discussion of these below), the effective portion of changes in the fair value of cash flow hedges that are reclassified from accumulated other comprehensive income/loss and any ineffectiveness associated with hedges related to our commodity activities are recognized currently in earnings as adjustments to product sales.
	We also use 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 December 31, 2014 were as follows:
	Type of Contract/Accounting Methodology		Product Represented by the Contract and Associated Barrels		Maturity Dates
	NYMEX - Fair Value Hedges		0.7 million barrels of crude oil		Between December 2015 and November 2016
	NYMEX - Economic Hedges		3.5 million barrels of refined products and crude oil		Between January and October 2015
	CME Butane Futures Agreements - Economic Hedges		0.4 million barrels of butane		Between January and April 2015
	Energy Commodity Derivatives Contracts and Deposits Offsets
	At December 31, 2014, we had received margin deposits of $84.5 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 $6.2 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 disclose 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, 2013 and 2014 (in thousands):
			31-Dec-13
	Description		Gross Amounts of Recognized Liabilities				Gross Amounts of Assets				Net Amounts of Liabilities Presented in the Consolidated Balance Sheet(1)				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet				Net Asset Amount(3)
	Energy commodity derivatives		$	(7,167	)		$	2,665			$	(4,502	)		$	14,782			$	10,280
			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(2)				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
	(1) Net amount includes energy commodity derivative contracts classified as current liabilities, net, of $6,737 and noncurrent assets of $2,235.
	(2) Net amount includes energy commodity derivative contracts classified as current 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.
	Impact of Derivatives on Income Statement, Balance Sheets and AOCL
	During 2013 and 2014, we had open NYMEX contracts on 0.7 million barrels of crude oil that were designated as fair value hedges. During 2013 and 2014, because there was no ineffectiveness recognized on these hedges, the cumulative gains (losses) of $(8.7) million and $13.3 million, respectively, from the agreements were offset by a cumulative decrease (increase) to tank bottoms and linefill. We exclude the differential between the current spot price and forward price from the assessment of hedge effectiveness for these fair value hedges. During 2014, we recognized a loss of $8.6 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.
	The following is a summary of the effect on our consolidated statements of income and statements of comprehensive income for the years ended December 31, 2012, 2013 and 2014 of derivatives accounted for under ASC 815-30, Derivatives and Hedging—Cash Flow Hedges, that were designated as hedging instruments (in thousands). See Note 7 - Product Sales Revenue for further details regarding the impact of our NYMEX agreements on product sales.
			Year Ended December 31, 2012
	Derivative Instrument		Amount of Gain Recognized in AOCL on  Derivative						Location of Gain Reclassified from AOCL into Income		Amount of Gain Reclassified from AOCL into Income
											Effective Portion						Ineffective Portion
	Interest rate contracts			$	10,977				Interest expense			$	164					$	—
	NYMEX commodity contracts			2,912					Product sales revenue			2,760						—
	Total cash flow hedges			$	13,889				Total			$	2,924					$	—
			Year Ended December 31, 2013
	Derivative Instrument		Amount of Loss Recognized in AOCL on  Derivative						Location of Gain (Loss) Reclassified from AOCL into Income		Amount of Gain (Loss) Reclassified from AOCL into Income
											Effective Portion						Ineffective Portion
	Interest rate contracts			$	(184	)			Interest expense			$	163					$	—
	NYMEX commodity contracts			(4,560		)			Product sales revenue			(4,408		)				—
	Total cash flow hedges			$	(4,744	)			Total			$	(4,245	)				$	—
			Year Ended December 31, 2014
	Derivative Instrument		Amount of Loss Recognized in AOCL on  Derivative						Location of Loss Reclassified from AOCL into Income		Amount of Gain (Loss) Reclassified from AOCL into Income
											Effective Portion						Ineffective Portion
	Interest rate contracts			$	(30,090	)			Interest expense			$	(242	)				$	366
	See Comprehensive Income in Note 2—Summary of Significant Accounting Policies for a roll-forward of the derivative gains included in AOCL for the years ended December 31, 2012, 2013 and 2014. As of December 31, 2014, the net loss estimated to be classified to interest expense over the next twelve months from AOCL is approximately $0.1 million. This amount relates to the amortization of the hedged losses on the interest rate swap contracts over the life of the related debt instruments.
	The following table provides a summary of the effect on our consolidated statements of income for the years ended December 31, 2012, 2013 and 2014 of derivatives accounted for under ASC 815-10-35; Derivatives and Hedging—Overall—Subsequent Measurement, that were not designated as hedging instruments (in thousands):
					Amount of Gain (Loss)
					Recognized on Derivative
				Year Ended December 31,
Derivative Instrument		Location of Gain (Loss)		2012				2013				2014
		Recognized on Derivative
NYMEX commodity contracts		Product sales revenue		$	(36,959	)		$	(6,189	)		$	145,320
NYMEX commodity contracts		Operating expenses		(2,055		)		(3,770		)		17,818
Butane futures agreements		Cost of product sales		1,203				2,682				(17,141		)
		Total		$	(37,811	)		$	(7,277	)		$	145,997
The following tables provide a summary of the amounts included on our consolidated balance sheets of the fair value of derivatives accounted for under ASC 815, Derivatives and Hedging, that were designated as hedging instruments as of December 31, 2013 and 2014 (in thousands):
		December 31, 2013
		Asset Derivatives						Liability Derivatives
Derivative Instrument		Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
NYMEX commodity contracts		Energy commodity derivatives contracts, net		$	—			Energy commodity derivatives contracts, net		$	146
NYMEX commodity contracts		Other noncurrent assets		2,235				Other noncurrent liabilities		—
		Total		$	2,235			Total		$	146
		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
The following tables provide a summary of the amounts included on our consolidated balance sheets of the fair value of derivatives accounted for under ASC 815, Derivatives and Hedging, that were not designated as hedging instruments as of December 31, 2013 and 2014 (in thousands):
		December 31, 2013
		Asset Derivatives						Liability Derivatives
Derivative Instrument		Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
NYMEX commodity contracts		Energy commodity derivatives contracts, net		$	48			Energy commodity derivatives contracts, net		$	7,021
Butane futures agreements		Energy commodity derivatives contracts, net		382				Energy commodity derivatives contracts, net		—
		Total		$	430			Total		$	7,021
		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		$	—
Butane futures agreements		Energy commodity derivatives contracts, net		—				Energy commodity derivatives contracts, net		10,622
		Total		$	92,000			Total		$	10,622

Leases

Leases	12 Months Ended
	Dec. 31, 2014
Leases [Abstract]
Leases	Leases
	Leases—Lessee. We lease land, office buildings and terminal equipment at various locations to conduct our business operations. We have also entered into contracts to lease pipeline capacity, primarily to accommodate the additional barrels from our Longhorn crude oil pipeline. Several of the agreements provide for negotiated renewal options and cancellation penalties, some of which include the requirement to remove our pipeline from the property for non-performance. Management expects that we will generally renew our expiring leases.  Leases are evaluated at inception or at any subsequent material modification and, depending on the lease terms, are classified as either capital or operating leases, as appropriate under ASC 840, Leases.   We recognize rent expense on a straight-line basis over the life of the lease.  Total rent expense was $4.8 million, $12.0 million and $21.0 million for the years ended December 31, 2012, 2013 and 2014, respectively. Future minimum annual rentals under non-cancellable operating leases with initial or remaining terms greater than one year as of December 31, 2014, were as follows (in millions):
	2015	$	26.5
	2016	23.9
	2017	23.3
	2018	18.6
	2019	8
	Thereafter	82.5
	Total	$	182.8
	Leases—Lessor. We have entered into capacity and storage leases with our customers with remaining terms from one to 20 years that are accounted for as operating-type leases. All of the agreements provide for negotiated extensions. Future minimum payments receivable under these arrangements as of December 31, 2014, were as follows (in millions):
	2015	$	249.7
	2016	229
	2017	158.3
	2018	110.4
	2019	83.3
	Thereafter	266.1
	Total	$	1,096.80
	Direct Financing Lease. In January 2014, we placed into operation an approximate 40-mile pipeline we constructed in Texas and New Mexico. We entered into a long-term throughput and deficiency agreement with a customer on this pipeline, which contains minimum volume/payment commitments. This agreement is being accounted for as a direct financing lease. The net investment under direct financing leasing arrangements as of December 31, 2014 was as follows (in millions):
			December 31, 2014
	Total minimum lease payments receivable		$	37.9
	Less: Unearned income		7
	Recorded net investment in direct financing lease		$	30.9
	The net investment in direct financing leases was classified in the consolidated balance sheets as follows (in millions):
			31-Dec-14
	Current accounts receivable		$	6.1
	Non-current accounts receivable		24.8
	Total		$	30.9
	Future minimum payments receivable under this direct financing lease for the next five years are: 2015 – $7.4 million; 2016 – $7.4 million; 2017 – $4.1 million; 2018 – $1.7 million; and 2019 – $1.7 million.

LongTerm_Incentive_Plan

Long-Term Incentive Plan	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Long-Term Incentive Plan	Long-Term Incentive Plan
	Plan Description
	We have a long-term incentive plan (“LTIP”) covering certain of our employees and directors of our general partner. The LTIP primarily consists of phantom units and permits the grant of awards covering an aggregate of 9.4 million of our limited partner units. The remaining units available under the LTIP at December 31, 2014 total approximately 1.3 million. The compensation committee of our general partner's board of directors administers our LTIP.
	Under our LTIP, the compensation committee has granted performance-based awards and retention awards.  Retention awards are subject to forfeiture by a participant if their employment is terminated for any reason other than death or disability prior to the vesting date.  Performance-based awards are subject to forfeiture by a participant if their employment is terminated for any reason other than retirement, death or disability prior to the vesting date or for a termination within two years of a change-in-control that occurs on an involuntary basis without cause or on a voluntary basis for good cause.  If a performance-based award recipient retires, dies or becomes disabled prior to the end of the vesting period, the recipient's award will be prorated based upon the completed months of employment during the vesting period, and the award will be settled shortly after the end of the vesting period. Our agreement with the award participants requires these awards to be paid in our limited partner units. Award grants under our LTIP do not have an early vesting feature except for the performance-based awards which can vest early under certain circumstances following a change in control of our general partner.
	For performance-based awards issued prior to 2014, we base the payout calculation for 80% of the award solely on the attainment of a financial metric established by the compensation committee. We account for this portion of these award grants as equity. The payout calculation for the remaining 20% of the unit awards is based on both the attainment of a financial metric and the individual employee's personal performance as determined by the compensation committee. We account for this portion of these award grants as a liability.
	The payout for the performance-based awards issued in 2014 is subject to the attainment of a financial metric and a market performance metric, with no individual employee personal performance component. The payout of the performance-based awards is based on our actual distributable cash flow excluding commodity-related activities for the last year of the 3-year vesting period as compared against established threshold, target and stretch metrics. The payouts for the performance-related component of the award can range from 0%, for below threshold results, up to 200% for actual results at stretch or above. The market performance component of the awards is based on our total unitholder return over the 3-year vesting period of the award in relation to the total unitholder returns of eleven peer entities and can increase or decrease the calculated performance-based payout of the award by as much as 50%. We account for these awards as equity.
	The payout for the retention awards that have been granted by the compensation committee is subject only to the participant's continued employment with us. We account for these award grants as equity.
	Non-Vested Unit Awards
	The following table includes the changes during the current fiscal year in the number of non-vested units that have been granted by the compensation committee. The amounts below include no adjustments for above-target or below-target performance and forfeitures are actual amounts through December 31, 2014.
			Equity Method															Liability Method Performance-Based Awards
			Performance-Based Awards								Retention Awards													Total Awards
			Number of Unit				Weighted-Average Grant Date Fair Value				Number of Unit			Weighted-Average Grant Date Fair Value				Number of Unit			Weighted-Average Fair Value			Number of Unit			Weighted-Average Fair Value
			Awards								Awards							Awards						Awards
	Non-vested units - 1/1/2014		389,410				$	41.9			75,211			$	32.87			97,355			$	63.27		561,976			$	44.4
	Units granted during 2014		187,371				$	72.77			33,903			$	82.86			—			$	—		221,274			$	74.32
	Units vested during 2014		(187,388	)			$	33.61			(60,514	)		$	34.35			(46,847	)		$	82.66		(294,749	)		$	41.56
	Units forfeited during 2014		(39,076	)			$	41.88			(1,932	)		$	31.66			(9,630	)		$	82.66		(50,638	)		$	49.24
	Non-vested units - 12/31/14		350,317		—		$	62.85			46,668			$	76.99			40,878			$	82.66		437,863			$	66.21
	The table below summarizes the total non-vested unit awards granted by the compensation committee adjusted for units we estimate will be forfeited by the end of the vesting period and for estimated amounts of above-target financial performance to determine the total number of unit awards included in our total equity-based liability accrual.
	Grant Date	Unit Awards Granted			Estimated Forfeitures			Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results			Total Unit Award Accrual			Vesting Date		Unrecognized Compensation Expense(a)         (in millions)
	Performance-Based Awards:
	2013 Awards	228,498			31,870			245,786			442,414			12/31/15		$	8.5
	2014 Awards	187,371			8,899			89,239			267,711			12/31/16		13
	Retention Awards:
	2015 Vesting Date	444			23			—			421			12/31/15		—			(b)
	2016 Vesting Date	20,757			1,037			—			19,720			12/31/16		0.9
	2017 Vesting Date	25,438			1,272			—			24,166			12/31/17		1.9
	Total	462,508			43,101			335,025			754,432					$	24.3
	(a) Unrecognized compensation expense will be recognized over the remaining vesting period of the awards.
	(b) Less than $0.1 million.
	Weighted-Average Grant Date Fair Values
	The weighted-average grant-date fair value of award grants issued during 2012, 2013 and 2014 were as follows:
			Equity Method
			Performance-Based Awards							Retention Awards							Liability Method Performance-Based Awards
			Number of			Weighted-Average Grant Date Fair Value				Number of Unit			Weighted-Average Grant Date Fair Value				Number of Unit			Weighted-Average Fair Value
			Unit							Awards							Awards
			Awards
	Units granted during 2012		214,232			$	33.57			7,016			$	30.54			53,558			$	33.57
	Units granted during 2013		182,798			$	51.49			22,668			$	53.02			45,700			$	51.49
	Units granted during 2014		187,371			$	72.77			33,903			$	82.86			—			$	—
	Vested Unit Awards
	The table below sets forth the numbers and values of units that vested in each of the three years ended December 31, 2014. The vested limited partner units include adjustments for above-target performance.
	Vesting Date		Vested		Fair Value of Unit Awards on Vesting Date (in millions)		Intrinsic Value of Unit Awards on Vesting Date (in millions)
			Limited
			Partner Units
	12/31/12		751,237		$17.10		$32.50
	12/31/13		572,353		$20.50		$36.20
	12/31/14		528,984		$22.40		$43.70
	Cash Flow Effects of LTIP Settlements
	We settle awards that vest by issuing limited partner units. The difference between the limited partner units issued to the participants and the total units accrued represents the minimum tax withholdings associated with the award settlement, which we pay in cash.
	Settlement Date		Number of Limited Partner Units Issued, Net of Tax Withholdings		Minimum Tax Withholdings		Employer Taxes (in millions)		Total Cash Taxes Paid (in millions)
					(in millions)
	Jan-12		722,766		$13.00		$1.30		$14.30
	Jan-13		476,682		$12.30		$1.10		$13.40
	Jan-14		387,216		$14.80		$1.20		$16.00
	Compensation Expense Summary
	Equity-based incentive compensation expense for 2012, 2013 and 2014 was as follows (in thousands):
		Year Ended December 31, 2012												Year Ended December 31, 2013											Year Ended December 31, 2014
		Equity				Liability				Total				Equity				Liability				Total			Equity				Liability		Total
		Method				Method								Method				Method							Method				Method
	2010 awards	$	4,937			$	3,723			$	8,660			$	121			$	73			$	194		$	—			$	—	$	—
	2011 awards	5,062				2,094				7,156				5,359				4,280				9,639			—				—		—
	2012 awards	3,426				1,101				4,527				4,751				2,747				7,498			4,418				3,896		8,314
	2013 awards	—				—				—				4,726				1,451				6,177			7,427				3,425		10,852
2014 awards	—				—				—				—				—				—			6,494				—		6,494
Retention awards	693				—				693				575				—				575			1,624				—		1,624
Total	$	14,118			$	6,918			$	21,036			$	15,532			$	8,551			$	24,083		$	19,963			$	7,321	$	27,284
Allocation of LTIP expense on our consolidated statements of income:
G&A expense									$	18,587											$	23,264								$	26,700
Operating expense									2,449												819									584
Total									$	21,036											$	24,083								$	27,284

Segment_Disclosures

Segment Disclosures	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Segment Disclosures	Segment Disclosures
	Our reportable segments are strategic business units that offer different products and services. Our segments are managed separately because each segment requires different marketing strategies and business knowledge. Management evaluates performance based on segment operating margin, which includes revenue from affiliates and external customers, operating expenses, cost of product sales and earnings of non-controlled entities. Transactions between our business segments are conducted and recorded on the same basis as transactions with third-party entities.
	We believe that investors benefit from having access to the same financial measures used by management. Operating margin, which is presented in the following tables, is an important measure used by management to evaluate the economic performance of our core operations. Operating margin is not a 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.
		Year Ended December 31, 2012
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
		(in thousands)
	Transportation and terminals revenue	$	723,835	$	92,288		$	154,621		$	—		$	970,744
	Product sales revenue	790,116		—			9,266			—			799,382
	Affiliate management fee revenue	—		1,734			214			—			1,948
	Total revenue	1,513,951		94,022			164,101			—			1,772,074
	Operating expenses	267,694		5,229			58,486			(2,955		)	328,454
	Cost of product sales	653,429		—			3,679			—			657,108
	Earnings of non-controlled entities	—		(2,574		)	(387		)	—			(2,961		)
	Operating margin	592,828		91,367			102,323			2,955			789,473
	Depreciation and amortization expense	86,218		12,228			26,611			2,955			128,012
	G&A expenses	87,309		5,420			16,674			—			109,403
	Operating profit	$	419,301	$	73,719		$	59,038		$	—		$	552,058
	Additions to long-lived assets	$	127,744	$	166,960		$	56,485					$	351,189
		As of December 31, 2012
	Segment assets	$	2,530,770	$	875,005		$	656,855					$	4,062,630
	Corporate assets												357,437
	Total assets												$	4,420,067
	Goodwill	$	38,369	$	12,082		$	2,809					$	53,260
	Investments in non-controlled entities	$	—	$	91,629		$	15,727					$	107,356
		Year Ended December 31, 2013
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
		(in thousands)
	Transportation and terminals revenue	$	801,128	$	178,409		$	158,791		$	—		$	1,138,328
	Product sales revenue	738,271		—			6,398			—			744,669
	Affiliate management fee revenue	—		13,361			1,248			—			14,609
	Total revenue	1,539,399		191,770			166,437			—			1,897,606
	Operating expenses	270,711		19,131			59,407			(3,179		)	346,070
	Cost of product sales	574,703		—			3,326			—			578,029
	Earnings of non-controlled entities	—		(3,781		)	(2,494		)	—			(6,275		)
	Operating margin	693,985		176,420			106,198			3,179			979,782
	Depreciation and amortization expense	86,926		24,119			28,006			3,179			142,230
	G&A expenses	91,658		19,896			20,942			—			132,496
	Operating profit	$	515,401	$	132,405		$	57,250		$	—		$	705,056
	Additions to long-lived assets	$	361,134	$	199,362		$	32,563					$	593,059
		As of December 31, 2013
	Segment assets	$	2,811,398	$	1,252,036		$	648,061					$	4,711,495
	Corporate assets												109,317
	Total assets												$	4,820,812
	Goodwill	$	38,369	$	12,082		$	2,809					$	53,260
	Investments in non-controlled entities	$	—	$	345,904		$	14,948					$	360,852
		Year Ended December 31, 2014
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
		(in thousands)
	Transportation and terminals revenue	$	921,762	$	310,136		$	170,740		$	—		$	1,402,638
	Product sales revenue	872,537		—			6,437			—			878,974
	Affiliate management fee revenue	—		20,790			1,321			—			22,111
	Total revenue	1,794,299		330,926			178,498			—			2,303,723
	Operating expenses	331,207		51,405			65,173			(3,513		)	444,272
	Cost of product sales	592,887		—			1,698			—			594,585
	Earnings of non-controlled entities	—		(16,309		)	(3,085		)	—			(19,394		)
	Operating margin	870,205		295,830			114,712			3,513			1,284,260
	Depreciation and amortization expense	101,642		27,800			28,786			3,513			161,741
	G&A expenses	96,411		29,557			22,320			—			148,288
	Operating profit	$	672,152	$	238,473		$	63,606		$	—		$	974,231
	Additions to long-lived assets	$	163,753	$	439,846		$	18,413					$	622,012
		As of December 31, 2014
Segment assets	$	2,875,412	$	1,937,242		$	647,900					$	5,460,554
Corporate assets												56,731
Total assets												$	5,517,285
Goodwill	$	38,369	$	12,082		$	2,809					$	53,260
Investments in non-controlled entities	$	—	$	599,757		$	14,110					$	613,867

Commitments_and_Contingencies_

Commitments and Contingencies Commitments and Contingencies (Notes)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies Disclosure [Text Block]	Commitments and Contingencies
	Environmental Liabilities
	Liabilities recognized for estimated environmental costs were $38.5 million and $36.3 million at December 31, 2013 and December 31, 2014, respectively. We have classified environmental liabilities as current or noncurrent based on management’s estimates regarding the timing of actual payments. Management estimates that expenditures associated with these environmental liabilities will be substantially 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 were $12.0 million, $(5.2) million and $5.0 million for the years ended December 31, 2012, 2013 and 2014, respectively. The lower environmental expense for 2013 was primarily due to the $10.6 million favorable adjustment of an accrual for potential air emission fees.
	Environmental Receivables
	Receivables from insurance carriers and other third parties related to environmental matters at December 31, 2013 were $4.8 million, of which $2.1 million and $2.7 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheets. Receivables from insurance carriers 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 sheets. Amounts received from insurance carriers and other third parties related to environmental matters during 2012, 2013 and 2014 were $1.2 million, $4.2 million and $0.5 million, respectively.
	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 3, Legal Proceedings of Part I of this report on Form 10-K. 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.

Quarterly_Financial_Data

Quarterly Financial Data	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data	Quarterly Financial Data (unaudited)
	Summarized quarterly financial data is as follows (in thousands, except per unit amounts):
	2013	First		Second		Third		Fourth
		Quarter		Quarter		Quarter		Quarter
	Revenue	$	432,421	$	443,912	$	443,835	$	577,438
	Total costs and expenses	$	291,967	$	260,191	$	291,586	$	355,081
	Operating margin	$	208,893	$	251,905	$	222,649	$	296,335
	Net income	$	112,967	$	153,640	$	125,623	$	190,007
	Basic net income per limited partner unit	$	0.5	$	0.68	$	0.55	$	0.84
	Diluted net income per limited partner unit	$	0.5	$	0.68	$	0.55	$	0.83
	2014
	Revenue	$	618,606	$	496,446	$	521,601	$	667,070
	Total costs and expenses	$	343,983	$	320,183	$	297,409	$	387,311
	Operating margin	$	347,535	$	264,424	$	299,268	$	373,033
	Net income	$	242,554	$	146,260	$	198,620	$	252,085
	Basic net income per limited partner unit	$	1.07	$	0.64	$	0.87	$	1.11
	Diluted net income per limited partner unit	$	1.07	$	0.64	$	0.87	$	1.1
	In second quarter 2013 results were benefited by a $10.6 million accrual reversal related to potential air emission fees.
	In the fourth quarter of 2014, total costs and expenses were increased $39.3 million by a lower-of-cost-or-market inventory adjustment, which resulted from a sharp decline in commodity prices during the quarter. Additionally, during the fourth quarter of 2014, the gains and losses we recognized from our NYMEX and CME hedges, as a result of the lower commodity prices, had the impact of increasing product sales revenue by $111.6 million, increasing cost of product sales by $14.0 million and decreasing operating expense by $17.4 million, for a total increase to operating margin and net income of $115.0 million.

Fair_Value_Disclosures

Fair Value Disclosures	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value Disclosures	Fair Value Disclosures
	Fair Value Methods and Assumptions - Financial Assets and Liabilities
	The following methods and assumptions were used 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 13 – 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 13 – Derivative Financial Instruments for further disclosures regarding these contracts.
	•	Long-term receivables. These include lease payments receivable under a direct-financing leasing arrangement and insurance receivables. Fair value was determined by estimating the present value of future cash flows using current market rates.
	•	Debt. The fair value of our publicly traded notes was based on the prices of those notes at December 31, 2013 and 2014; however, where recent observable market trades were not available, prices were determined using adjustments to the last traded value for that debt issuance or by adjustments to the prices of similar debt instruments of peer entities that are actively traded. The carrying amount of borrowings, if any, under our revolving credit facility and our commercial paper program approximates fair value due to the frequent repricing of these obligations.
	Fair Value Measurements - Financial Assets and Liabilities
	The following tables summarize the carrying amounts, fair values and recurring fair value measurements recorded or disclosed as of December 31, 2013 and 2014, based on the three levels established by ASC 820; Fair Value Measurements and Disclosures (in thousands):
									Fair Value Measurements as of
									December 31, 2013 using:
	Assets (Liabilities)		Carrying Amount			Fair Value			Quoted Prices in			Significant Other			Significant
									Active Markets for			Observable			Unobservable
									Identical Assets			Inputs			Inputs
									(Level 1)			(Level 2)			(Level 3)
	Energy commodity derivatives contracts (liabilities)		$	(4,502	)	$	(4,502	)	$	(4,502	)	$	—		$	—
	Long-term receivables		$	2,730		$	2,658		$	—		$	—		$	2,658
	Debt		$	(2,685,287	)	$	(2,815,210	)	$	—		$	(2,815,210	)	$	—
									Fair Value Measurements as of
									December 31, 2014 using:
	Assets (Liabilities)		Carrying Amount			Fair Value			Quoted Prices in			Significant Other			Significant
									Active Markets for			Observable			Unobservable
									Identical Assets			Inputs			Inputs
									(Level 1)			(Level 2)			(Level 3)
	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	)	$	—

Distributions

Distributions	12 Months Ended
	Dec. 31, 2014
Distributions Made to Members or Limited Partners [Abstract]
Distributions
		Distributions
	Distributions we paid during 2012, 2013 and 2014 were as follows (in thousands, except per unit amount):
	Payment Date		Per Unit Cash Distribution Amount		Total Cash Distribution
	2/14/12		$	0.4075	$	92,177
	5/15/12		0.42		95,004
	8/14/12		0.47125		106,597
	11/14/12		0.485		109,707
	Total		$	1.78375	$	403,485
	2/14/13		$	0.5	$	113,340
	5/15/13		0.5075		115,040
	8/14/13		0.5325		120,707
	11/14/13		0.5575		126,374
	Total		$	2.0975	$	475,461
	2/14/14		$	0.585	$	132,835
	5/15/14		0.6125		139,079
	8/14/14		0.64		145,324
	11/14/14		0.6675		151,568
	Total		$	2.505	$	568,806

Partners_Capital

Partners' Capital	12 Months Ended
	Dec. 31, 2014
Stockholders' Equity Note [Abstract]
Owners' Equity	Partners' Capital
	The following table details the changes in the number of our limited partner units outstanding from January 1, 2012 through December 31, 2014:
	Limited partner units outstanding on January 1, 2012	225,473,142
	01/12—Settlement of 2009 award grants	722,766
	01/12—Other(a)	4,964
	Limited partner units outstanding on December 31, 2012	226,200,872
	01/13—Settlement of 2010 award grants	476,682
	01/13—Other(a)	1,884
	Limited partner units outstanding on December 31, 2013	226,679,438
	02/14—Settlement of 2011 award grants	387,216
	02/14—Other(a)	1,603
	Limited partner units outstanding on December 31, 2014	227,068,257
	(a)	Limited partner units issued to settle the equity-based retainer paid to independent directors of our general partner.
	Our partnership agreement allows us to issue additional partnership securities for any partnership purpose at any time and from time to time for consideration and on terms and conditions as our general partner determines, all without approval by the limited partners.
	Limited partners holding our limited partner units have the following rights, among others:
	•	right to receive distributions of our available cash within 45 days after the end of each quarter;
	•	right to elect the board members of our general partner;
	•	right to remove Magellan GP, LLC as our general partner upon a 100% vote of outstanding unitholders;
	•	right to transfer limited partner unit ownership to substitute limited partners;
	•	right to receive an annual report, containing audited financial statements and a report on those financial statements by our independent public accountants, within 120 days after the close of the fiscal year end;
	•	right to receive information reasonably required for tax reporting purposes within 90 days after the close of the calendar year;
	•	right to vote according to the limited partners’ percentage interest in us at any meeting that may be called by our general partner; and
	•	right to inspect our books and records at the unitholders’ own expense.
	In the event of liquidation, we would distribute all property and cash in excess of that required to discharge all liabilities to the partners in proportion to the positive balances in their respective capital accounts. The limited partners' liability is generally limited to their investment.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2014
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events
	Recognizable events
	No recognizable events have occurred subsequent to December 31, 2014.
	Non-recognizable events
	Our collective bargaining agreement with approximately 26% of the employees assigned to our Refined Products segment which are represented by the USW, expired January 31, 2015. We are operating under a 24-hour rolling extension of this agreement while negotiations for a new agreement continue.
	On February 6, 2015, 166,189 phantom unit awards were issued pursuant to our long-term incentive plan. These grants included both performance-based and retention awards and have a three-year vesting period that will end on December 31, 2017.
	On January 30, 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 retainers paid to the directors of our general partner.
	On February 13, 2015, we paid cash distributions of $0.695 per unit on our outstanding limited partner units to unitholders of record at the close of business on February 6, 2015. The total distributions paid were $158.1 million.

Summary_Of_Significant_Account1

Summary Of Significant Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation. Our consolidated financial statements include our refined products, crude oil and marine storage segments. We consolidated all entities in which we have a controlling ownership interest. We apply the equity method of accounting for entities where our ownership interest is greater than 20% but we do not control and which we have determined are not variable interest entities. We have eliminated all intercompany transactions.
Use Of Estimates	Use of Estimates. The preparation of our consolidated financial statements in conformity with generally accepted accounting principles in the U.S. ("GAAP") requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities that exist at the date of our consolidated financial statements, as well as their impact on the reported amounts of revenue and expense during the reporting periods. Actual results could differ from those estimates.
Cash Equivalents	Cash Equivalents. Cash and cash equivalents include demand and time deposits and funds that own highly marketable securities with original maturities of three months or less when acquired. We periodically assess the financial condition of the institutions where we hold these funds, and, at December 31, 2013 and 2014, we believed our credit risk relative to these funds was minimal.
Accounts Receivable And Allowance For Doubtful Accounts	Accounts Receivable and Allowance for Doubtful Accounts. Accounts receivable represent valid claims against customers. We recognize accounts receivable when we sell products or render services and collection of the receivable is probable. We extend credit terms to certain customers based on historical dealings and to other customers after a review of various credit indicators. We establish an allowance for doubtful accounts for all or any portion of an account where we consider collections to be at risk and evaluate reserves no less than quarterly to determine their adequacy. Judgments relative to at-risk accounts include the customers' current financial condition, the customers' historical relationship with us and current and projected economic conditions. We write off accounts receivable when we deem the account uncollectible.
Inventory Valuation	Inventory Valuation. Inventory is comprised primarily of refined products, liquefied petroleum gases, transmix and crude oil, which are stated and relieved at the lower of average cost or market.
Property, Plant and Equipment	Property, Plant and Equipment. Property, plant and equipment consist primarily of pipeline, pipeline-related equipment, storage tanks and processing equipment. We state property, plant and equipment at cost except for certain acquired assets recorded at fair value on their respective acquisition dates and impaired assets. We record impaired assets at fair value on the last impairment evaluation date for which an adjustment was required.
	We assign asset lives based on reasonable estimates when we place an asset into service. Subsequent events could cause us to change our estimates, which would affect the future calculation of depreciation expense. The range of depreciable lives by asset category is detailed in Note 8—Property, Plant and Equipment.
	When we sell or retire property, plant and equipment, we remove its carrying value and the related accumulated depreciation from our accounts and record any associated gains or losses on our income statement in the period of sale or disposition.
	We capitalize expenditures to replace existing assets and retire the replaced assets. We capitalize expenditures when they extend the useful life, increase the productivity or capacity or improve the safety or efficiency of the asset. We capitalize direct project costs such as labor and materials as incurred. Indirect project costs, such as overhead, are capitalized based on a percentage of direct labor charged to the respective capital project. We charge expenditures for maintenance, repairs and minor replacements to operating expense in the period incurred.
Investments in Non-Controlled Entities	Investments in Non-Controlled Entities. We account for investments greater than 20% in affiliates that we do not control using the equity method of accounting. Under this method, an investment is recorded at our acquisition cost or capital contributions, as adjusted by contractual terms, plus equity in earnings or losses since acquisition or formation, plus interest capitalized, less distributions received and amortization of interest capitalized and excess net investment. Excess net investment is the amount by which our investment in a non-controlled entity exceeded our proportionate share of the book value of the net assets of that investment. We amortize excess net investment over the weighted-average depreciable asset lives of the equity investee. Our unamortized excess net investment was $15.1 million and $79.0 million at December 31, 2013 and 2014, respectively. The increase in the amount of unamortized excess investment during 2014 was due primarily to our investment in BridgeTex. We evaluate equity method investments for impairment whenever events or circumstances indicate that there is an other-than-temporary loss in value of the investment. In the event that we determine that the loss in value of an investment is other-than-temporary, we would record a charge to earnings to adjust the carrying value to fair value.
Goodwill and Other Intangible Assets	Goodwill and Other Intangible Assets. We do not amortize goodwill, which represents the excess of fair value of the business acquired over the fair value of assets acquired and liabilities assumed. We evaluate goodwill for impairment annually as of October 1st and when events or changes in circumstances indicate that the fair value of a reporting unit with goodwill has been reduced below carrying value. Goodwill was $53.3 million at both December 31, 2013 and 2014. Our reported goodwill at December 31, 2014 included $38.4 million allocated to our refined products segment, $12.1 million allocated to our crude oil segment and $2.8 million allocated to our marine storage segment.
	For 2014, we performed a qualitative assessment to determine whether the fair value of our reporting units was more likely than not less than their respective carrying amounts.  Our evaluation consisted of assessing the general impact of how a number of different elements would affect the fair value of our reporting units; including, the current and projected future earnings of our reporting units, our capitalization, our current slate of capital projects, the growth in the distributions we pay to our unitholders, current and future interest rates and the impact of lower crude oil prices on our earnings and the acquisition markets.  As of October 1, 2014, our qualitative assessment indicated that there was no need to conduct further quantitative testing nor did our analysis reflect any reporting units at risk.  If, based on the results of our qualitative assessment, we believed it was more likely than not the fair value of our reporting units were less than the carrying amount, we would have performed step one of the two-step goodwill impairment test. The first step of the goodwill impairment test determines whether an impairment exists by comparing the fair value of a reporting unit with its carrying amount, including goodwill.  If the estimated fair value of the reporting unit exceeds its carrying amount, no impairment is indicated. If the carrying amount of a reporting unit exceeds its estimated fair value, an impairment is indicated and the second step of the test is performed to measure the amount of impairment by comparing the implied fair value of the reporting unit goodwill to the carrying amount of that goodwill.  For periods prior to 2014, our October 1st goodwill assessment was based on a quantitative assessment of the fair value of our reporting units.
	We amortize other intangible assets over their estimated useful lives of 5 years up to 25 years. The weighted-average asset life of our other intangible assets at December 31, 2014 was approximately 6 years. We adjust the useful lives of our other intangible assets if events or circumstances indicate there has been a change in the remaining useful lives. We eliminate from our balance sheets the gross carrying amount and the related accumulated amortization for any fully amortized intangibles in the year they are fully amortized. We review our other intangible assets for impairment whenever events or changes in circumstances indicate we should assess the recoverability of the carrying amount of the intangible asset.
Tank Bottoms and Linefill	Tank Bottoms and Linefill. A contract we have with a customer at our crude oil terminal in Cushing, Oklahoma requires us to maintain a minimum volume of crude oil in the tanks they utilize at that facility. Because of this contractual requirement, the crude oil we own at that facility is not sold in the normal course of our business; therefore, we classify these crude oil barrels as a long-term asset carried at cost adjusted for gains or losses on certain derivative contracts classified as fair value hedges.
Impairment of Long-Lived Assets	Impairment of Long-Lived Assets. We evaluate our long-lived assets of identifiable business activities, other than those held for sale, for impairment when events or changes in circumstances indicate, in management's judgment, that the carrying value of such assets may not be recoverable. We base the determination of whether impairment has occurred on management's estimate of undiscounted future cash flows attributable to the assets as compared to the carrying value of the assets. We calculate the amount of the impairment recognized as the excess of the carrying amount of the asset over the fair value of the assets, as determined either through reference to similar asset sales or by estimating the fair value using a discounted cash flow approach.
	Judgments and assumptions are inherent in management's estimate of undiscounted future cash flows used to determine recoverability of an asset and the estimate of an asset's fair value used to calculate the amount of impairment to recognize. The use of alternate judgments and assumptions could result in the recognition of different levels of impairment charges in the financial statements.
Debt Placement Costs	Debt Placement Costs. We capitalize costs incurred for debt borrowings when paid and amortize those costs over the life of the associated debt instrument using the effective interest method. When debt is retired before its scheduled maturity date, we write off any remaining placement costs associated with that debt.
Interest Capitalized	Interest Capitalized. During construction, we capitalize interest on all construction projects requiring a completion period of three months or longer and total project costs exceeding $0.5 million. The interest we capitalize is based on the weighted-average interest rate of our debt.
Pension And Postretirement Medical And Life Benefit Obligations	Pension and Postretirement Medical and Life Benefit Obligations. We sponsor three pension plans that cover substantially all of our employees, a postretirement medical and life benefit plan for certain employees and a defined contribution plan. Our pension and postretirement benefit liabilities represent the funded status of the present value of benefit obligations of these plans.
	We develop pension, postretirement medical and life benefits costs from actuarial valuations. We establish actuarial assumptions to anticipate future events and use those assumptions when calculating the expense and liabilities related to these plans. These factors include assumptions management makes concerning interest rates, expected investment return on plan assets, health care costs trend rates, turnover rates and rates of future compensation increases, among others. In addition, we use subjective factors such as withdrawal and mortality rates to develop actuarial valuations. Management reviews and updates these assumptions on an annual basis. The actuarial assumptions that we use may differ from actual results due to changing market rates or other factors. These differences could affect the amount of pension and postretirement medical and life benefit expense we will recognize in future periods.
Derivative Financial Instruments	Derivative Financial Instruments. We use derivative instruments to manage market price risks associated with inventories, interest rates, our tank bottom and linefill assets and certain forecasted transactions. Our policies prohibit us from engaging in speculative trading activities. For certain physical forward commodity derivative contracts, accounting guidance provides for and we apply the normal purchase/normal sale exception, whereby changes in the mark-to-market values of such contracts are not recognized in income, rather the revenues and expenses associated with such transactions are recognized during the period when commodities are physically delivered or received. Physical forward commodity contracts subject to this exception are evaluated for the probability of future delivery and are periodically back-tested once the forecasted period has passed to determine whether similar forward contracts are probable of physical delivery in the future. For all other derivative contracts, we record the agreements on our balance sheets at fair value.
	For those instruments that qualify for hedge accounting, the accounting treatment depends on their intended use and their designation. We divide derivative financial instruments qualifying for hedge accounting treatment into two categories: (1) cash flow hedges and (2) fair value hedges. We execute cash flow hedges to hedge against the variability in cash flows related to a forecasted transaction and execute fair value hedges to hedge against the changes in the value of a recognized asset or liability. At the inception of a hedged transaction, we document the relationship between the hedging instrument and the hedged item, the risk management objectives and the methods used for assessing and testing correlation and hedge effectiveness. We also assess, both at the inception of the hedge and on an on-going basis, whether the derivatives that are used in our hedging transactions are highly effective in offsetting changes in cash flows or fair value of the hedged item. If we determine that a derivative originally designated as a cash flow or fair value hedge is no longer highly effective, we discontinue hedge accounting prospectively and record the change in the fair value of the derivative in current earnings. The change in fair value of derivative financial instruments that are not designated as a hedging instrument is included in current earnings.
	As part of our risk management process, we assess the creditworthiness of the financial and other institutions with which we execute financial derivatives. Such financial instruments involve the risk of non-performance by the counterparty, which could result in material losses to us.
	We have entered into NYMEX commodity based futures contracts to hedge against price changes on a portion of the refined products we expect to sell in the future and changes in the fair value of our tank bottoms and linefill. Some of these contracts have qualified as cash flow or fair value hedges under Accounting Standards Codification ("ASC") No. 815, Derivatives and Hedging, while others have not. We record the effective portion of the gains or losses for those contracts that qualify for and are designated as cash flow hedges in other comprehensive income and the ineffective portion in product sales revenue. We reclassify gains and losses from contracts that qualify as cash flow hedges from other comprehensive income to product sales revenue when the hedged transaction occurs and we terminate the derivative agreement. 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. We recognize the change in fair value of those agreements that are not designated as hedges in product sales revenue, except for those undesignated agreements that economically hedge the inventories associated with our pipeline system overages. We record the change in fair value of those agreements in operating expenses.
	In addition, we have entered into Chicago Mercantile Exchange ("CME")-traded butane futures agreements to hedge against changes in the price of butane we expect to purchase in the future. We account for all of these agreements as economic hedges, with period changes in the fair value of these agreements recorded as adjustments to cost of product sales.
	We use interest rate derivatives to help manage interest rate risk. We record any ineffectiveness on derivatives designated as hedging instruments to interest expense and the change in fair value of interest rate derivatives that we do not designate as hedging instruments to other income or expense in our results of operations. For the effective portion of interest rate cash flow hedges, we record the noncurrent portion of unrealized gains or losses as an adjustment to other comprehensive income with the current portion recorded as an adjustment to interest expense. For the effective portion of fair value hedges on long-term debt, we record the noncurrent portion of gains or losses as an adjustment to long-term debt with the current portion recorded as an adjustment to interest expense.
Revenue Recognition	Revenue Recognition. We recognize pipeline transportation revenue for crude oil shipments when our customers take possession of their product from our system. For ammonia shipments and shipments of refined products under published tariffs that combine transportation and terminalling services, we recognize revenue when our customers take possession of their product from our system through tanker trucks, railcars or third-party pipelines. For all other shipments, where terminalling services are not included in the tariff, we recognize revenue when our customers' product arrives at the customer-designated delivery point. We have certain agreements that require counterparties to ship a minimum volume over an agreed-upon period. Revenue pursuant to such agreements is recognized at the earlier of when the volume is shipped or when the counterparty’s ability to meet the minimum volume commitment has expired.
	We recognize injection service fees associated with additives upon injection to the customer's product, which occurs at the time we deliver the product to our customers. We recognize leased tank storage, pipeline capacity leases, terminalling, throughput, ethanol loading and unloading services, laboratory testing, data services, pipeline operation fees and other miscellaneous service-related revenue upon completion of contract services. We recognize product sales upon delivery of the product to the customer. See Derivative Financial Instruments above for a discussion of how these agreements impact product sales. We record back-to-back purchases and sales of refined products where we are acting as an agent to facilitate refined product sales between a supplier and a customer on a net basis.
Deferred Transportation Revenues And Costs	Deferred Transportation Revenue and Costs. Generally, we invoice customers on our refined products pipeline for transportation services when their product enters our system. At each period end, we record all invoiced amounts associated with products that have not yet been delivered (in-transit products) as a deferred liability. The value of this liability is calculated as the total of the volume of each product type, for each pipeline region, multiplied by the average tariff rate for that product type for the most recent month invoiced to our customers. We use the most recent month's average tariff rate because the product in our pipeline system generally turns over every month. Additionally, at each period end, we defer the direct costs we have incurred associated with these in-transit products, until delivery occurs, as a deferred asset. These direct costs are estimated based on our average per-barrel direct delivery cost for the current year multiplied by the total in-transit barrels in our system at the end of the period multiplied by 50% to reflect the average transportation costs incurred for all products across all our pipeline systems. We use 50% of the in-transit barrels because that best represents the average delivery point of all barrels in our pipeline system. These deferred revenues and costs are determined using judgments and assumptions that management considers reasonable.
Pipeline Over/Short Product	Pipeline Over/Short Product. The tariffs we charge for our pipeline transportation systems are primarily regulated by the Federal Energy Regulatory Commission (“FERC”); however, certain tariffs are regulated by the Surface Transportation Board or state regulatory authorities. Our tariffs include provisions which allow us to deduct from our customer's inventory a small percentage of the products our customers transport on our pipeline systems. We refer to these product quantities as tender deductions. The purpose of these tender deductions is to help offset the product losses we sustain as a result of shrinkage, evaporation, protection of product quality and product measurement inaccuracies. We record these tender deductions as an increase of pipeline over/short product inventory and a reduction of operating expense. Each period end, we measure the volume of each type of product in our pipeline system, which is compared to the volumes of our customers' inventories (as adjusted for tender deductions).  To the extent that the product volumes in our pipeline system exceeds the volumes of our customers' book inventories, we increase our product inventories and recognize a gain; however, to the extent the product in our pipeline system is less than our customers' book inventories, we record a liability (for product owed to our customers) and recognize a loss.  The product gains and losses we recognize are recorded based on period-end product market prices, and we include those gains or losses in operating expenses on our consolidated statements of income.
Excise Taxes Charged To Customers	Excise Taxes Charged to Customers. Revenues are recorded net of all amounts charged to our customers for excise taxes.
Equity-Based Incentive Compensation Awards	Equity-Based Incentive Compensation. The compensation committee of our general partner (the “compensation committee") has approved incentive awards of phantom units representing limited partner interests in us to certain employees. The awards granted include performance-based awards and retention awards, both of which include distribution equivalent rights. Further, the compensation committee has issued phantom units with distribution equivalent rights to our independent directors who have deferred the receipt of board fees into the director deferred compensation plan.
	Under ASC 718, Compensation-Stock Compensation, we classify unit awards as either equity or liabilities. Fair value for award grants classified as equity is determined on the grant date of the award, and we recognize this value as compensation expense ratably over the requisite service period, which is the vesting period of each unit award. Because all of our unit awards contain full distribution equivalent rights, the per-unit fair value of our equity awards is the closing price of our limited partner units on the grant date. However, the per-unit fair value of the equity awards we issued in 2014 also includes the fair value of the market-based component of those awards. Compensation expense for awards classified as equity is calculated as the number of unit awards classified as equity less estimated forfeitures, multiplied by the per unit grant date fair value of those awards, multiplied by the percentage of the requisite service period completed at each period end, multiplied by the expected payout percentage, less previously-recognized compensation expense. We re-measure unit awards classified as liabilities at fair value on the close of business at each reporting period end until settlement date. Fair value at each re-measurement date is the closing price of our limited partner units at each period end. Compensation expense for unit awards classified as liabilities is the number of unit awards classified as liabilities less estimated forfeitures, multiplied by the re-measured per-unit fair value of the awards, multiplied by the percentage of the requisite service period completed at each period end, multiplied by the expected payout percentage, less previously-recognized compensation expense.
	Performance-based awards include provisions that can result in payouts to the recipients of the 2013 awards of from 0% up to 250% of the targeted amount of the award and, to the recipients of the 2014 awards of from 0% to 200% of the targeted amount of the award. Additionally, the 2014 awards are subject to a market performance metric, which could increase or decrease the payout of the award by as much as 50%. Judgments and assumptions of the final award payouts are inherent in the accruals recorded for equity-based incentive compensation costs. The use of alternate judgments and assumptions could result in the recognition of different levels of equity-based incentive compensation costs.
	Payouts related to retention awards are based solely on the completion of the requisite service period by the employee. Retention awards contain no provisions which would provide for a payout to the employee of anything other than the original number of units awarded and the associated distribution equivalents.
	The vesting period for both the performance-based and retention awards is generally three years; however, certain awards have been issued with shorter vesting periods while others have vesting periods of up to four years. We settle vested non-director award grants by issuing new common units, except for the associated statutory minimum tax withholding, which we settle by paying with cash on hand. Phantom units issued to our directors are settled in cash in January of the year following their death or resignation from the board of directors of our general partner.
Contingencies And Environmental	Contingencies and Environmental. Certain conditions may exist as of the date our consolidated financial statements are issued that could result in a loss to us, but which will only be resolved when one or more future events occur or fail to occur. Our management assesses such contingent liabilities, which inherently involves significant judgment. In assessing loss contingencies related to legal proceedings that are pending against us or for unasserted claims that may result in proceedings, our management, with input from legal counsel, evaluates the perceived merits of any legal proceedings or unasserted claims as well as the perceived merits of the amount of relief sought or expected to be sought therein.
	Environmental expenditures are charged to operating expense or capitalized based on the nature of the expenditures. Environmental expenditures that meet the capitalization criteria for property, plant and equipment, as well as costs that mitigate or prevent environmental contamination that has yet to occur, are capitalized. We expense expenditures that relate to an existing condition caused by past operations. We record environmental liabilities assumed in a business combination at fair value, otherwise, we record environmental liabilities on an undiscounted basis. We recognize liabilities for other commitments and contingencies when, after analyzing the available information, we determine it is probable that an asset has been impaired, or that a liability has been incurred and the amount of impairment or loss can be reasonably estimated. When we can estimate a range of probable loss, we accrue the most likely amount within that range, or if no amount is more likely than another, we accrue the minimum of the range of probable loss. We expense legal costs associated with loss contingencies as incurred.
	We record environmental liabilities independently of any potential claim for recovery. Accruals related to environmental matters are generally determined based on site-specific plans for remediation, taking into account currently available facts, existing technologies and presently enacted laws and regulations. Accruals for environmental matters reflect our prior remediation experience and include an estimate for costs such as fees paid to contractors, outside engineering and consulting firms. Accruals for estimated losses from environmental remediation obligations generally are recognized no later than completion of the remediation feasibility study. Such accruals are adjusted as further information develops or circumstances change.
	We maintain selective insurance coverage, which may cover all or portions of certain environmental expenditures less a deductible. We recognize receivables in cases where we consider the realization of reimbursements of remediation costs as probable. We would sustain losses to the extent of amounts we have recognized as environmental receivables if the counterparties to those transactions were unable to perform their obligations to us.
	The determination of the accrual amounts recorded for environmental liabilities includes significant judgments and assumptions made by management. The use of alternate judgments and assumptions could result in the recognition of different levels of environmental remediation costs.
Income Taxes	Income Taxes. We are a partnership for income tax purposes and, therefore, have not been subject to federal or state income taxes for most of the states in which we operate. The tax on our net income is borne by the individual partners through the allocation of taxable income. Net income for financial statement purposes may differ significantly from taxable income of unitholders because of differences between the tax basis and financial reporting basis of assets and liabilities and the taxable income allocation requirements under our partnership agreement. The aggregate difference in the basis of our net assets for financial and tax reporting purposes cannot be readily determined because information regarding each partner's tax attributes is not available to us.
	As a publicly traded limited partnership, we are subject to a statutory requirement that our "qualifying income" (as defined by the Internal Revenue Code, related Treasury Regulations, and Internal Revenue Service pronouncements) exceed 90% of our total gross income, determined on a calendar year basis. If our qualifying income does not meet this statutory requirement, we could be taxed as a corporation for federal and state income tax purposes. For the years ended December 31, 2012, 2013 and 2014, our qualifying income met the statutory requirement.
	The amounts recognized as provision for income taxes in our consolidated statements of income reflect a partnership-level tax levied by the state of Texas. This tax is based on revenues less direct costs of sale for our assets apportioned to the state of Texas.
Net Income Per Unit	Net Income Per Unit. We calculate basic net income per limited partner unit for each period by dividing net income by the weighted-average number of limited partner units outstanding. Diluted net income per limited partner unit for each period is the same calculation as basic net income per limited partner unit, except the weighted-average limited partner units outstanding includes the dilutive effect of phantom unit grants associated with our long-term incentive plan in periods where contingent performance metrics have been met.
Comprehensive Income	Comprehensive Income. We account for comprehensive income in accordance with ASC 220, Comprehensive Income. Comprehensive income was determined based on our net income adjusted for changes in other comprehensive income (loss) from unrealized gains or losses from derivative hedging transactions, reclassification of derivative gain and losses to net income and adjustments to record the periodic and settlement costs of our pension and postretirement benefit plans and our pension and postretirement benefit obligation liabilities at the funded status of the present value of the benefit obligations.
New Accounting Pronouncements	New Accounting Pronouncements
	In January 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update (“ASU”) 2015-01, Income Statement–Extraordinary and Unusual Items. This standard eliminates the concept of extraordinary and unusual items from U.S. GAAP. The new standard is effective for annual and interim periods after December 15, 2015.  Early adoption is permitted. We adopted this standard on January 1, 2015. Our adoption of this ASU did not have a material impact on our results of operations, financial position or cash flows.
	In August 2014, the FASB issued ASU 2014-15, Presentation of Financial Statements–Going Concern (Subtopic 205-40): Disclosure of Uncertainties About an Entity’s Ability to Continue as a Going Concern. This standard requires management to assess an entity’s ability to continue as a going concern, and to provide related footnote disclosures in certain circumstances. Before this standard, no accounting guidance existed for management on when and how to assess or disclose going concern uncertainties. The amendments are effective for annual periods ending after December 15, 2016, and interim periods within annual periods beginning after December 15, 2016. Early application is permitted. We adopted this standard on January 1, 2015. Our adoption of this ASU did not have a material impact on our results of operations, financial position or cash flows.
	In June 2014, the FASB issued ASU 2014-12, Compensation–Stock Compensation (Topic 718):  Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period. This ASU finalizes the Emerging Issues Task Force’s Proposed ASU No. EITF-13D of the same name and seeks to resolve the diversity in practice that exists when accounting for share-based payments.  This ASU requires that a performance target that affects vesting and can be achieved after the requisite service period to be accounted for as a performance condition.  The new standard is effective for annual and interim periods after December 15, 2015.  Early adoption is permitted. We adopted this standard on January 1, 2015. Our adoption of this ASU did not have a material impact on our results of operations, financial position or cash flows.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers, which eliminates the industry-specific guidance in U.S. GAAP and produces a single, principles-based method for companies to report revenue in their financial statements. This standard requires companies to make more estimates and use more judgment than under current guidance. In addition, all companies must compile more extensive footnote disclosures about how the revenue numbers were derived. This ASU is effective for periods beginning January 1, 2017 and requires either a full retrospective or modified retrospective adoption. We have not yet determined which adoption method we will employ. Early adoption of this standard is not allowed. We are currently in the process of evaluating the impact this new standard will have on our financial statements.
	In April 2014, the FASB issued ASU 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. This standard will limit the number of disposals of assets that should be presented as discontinued operations to those disposals that represent a strategic shift in operations and have a major effect on the organization's operations and financial results. Expanded disclosures will be required to provide more information about the assets, liabilities, income and expenses of discontinued operations as well as significant asset disposals that do not meet the criterion for discontinued operations treatment. This ASU will take effect for annual financial statements with fiscal years beginning on or after December 15, 2014. Our adoption of this ASU did not have a material impact on our results of operations, financial position or cash flows.

Summary_Of_Significant_Account2

Summary Of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Schedule of Accumulated Other Comprehensive Loss	Amounts included in accumulated other comprehensive loss ("AOCL") are as follows (in thousands):
		Derivative			Pension and			Accumulated
		Gains			Postretirement			Other
		(Losses)			Liabilities			Comprehensive
								Loss
	Balance, January 1, 2012	$	3,161		$	(50,362	)	$	(47,201	)
	Derivative activity:
	Net gain on cash flow hedges(1)	13,889			—			13,889
	Reclassification of net gain on cash flow hedges to income(1)	(2,924		)	—			(2,924		)
	Changes in employee benefit plan assets and benefit obligations recognized in other comprehensive income:
	Net actuarial loss(2)	—			(17,804		)	(17,804		)
	Plan amendment(2)	—			16,020			16,020
	Amortization of prior service credit(2)	—			(1,664		)	(1,664		)
	Amortization of actuarial loss(2)	—			4,626			4,626
	Balance, December 31, 2012	14,126			(49,184		)	(35,058		)
	Derivative activity:
	Net loss on cash flow hedges(1)	(4,744		)	—			(4,744		)
	Reclassification of net loss on cash flow hedges to income(1)	4,245			—			4,245
	Changes in employee benefit plan assets and benefit obligations recognized in other comprehensive income:
	Net actuarial gain(2)	—			14,089			14,089
	Amortization of prior service credit(2)	—			(3,405		)	(3,405		)
	Amortization of actuarial loss(2)	—			5,369			5,369
	Balance, December 31, 2013	13,627			(33,131		)	(19,504		)
	Derivative activity:
	Net loss on cash flow hedges(1)	(30,090		)	—			(30,090		)
	Reclassification of net gain on cash flow hedges to income(1)	(124		)	—			(124		)
	Changes in employee benefit plan assets and benefit obligations recognized in other comprehensive income:
	Net actuarial loss(2)	—			(33,937		)	(33,937		)
	Amortization of prior service credit(2)	—			(3,680		)	(3,680		)
	Amortization of actuarial loss(2)	—			3,986			3,986
	Settlement cost(2)	—			1,809			1,809
	Balance, December 31, 2014	$	(16,587	)	$	(64,953	)	$	(81,540	)
	(1) See Note 13–Derivative Financial Instruments for additional detail of the amount of gain (loss) recognized in AOCL on derivatives and the amount of (gain) loss reclassified from AOCL into income.
	(2) See Note 10–Employee Benefit Plans for additional detail of the changes in employee benefit plan assets and benefit obligations that are recognized in other comprehensive income (loss).

Consolidated_Statements_Of_Cas1

Consolidated Statements Of Cash Flows - Supplemental Disclosures (Tables)	12 Months Ended
	Dec. 31, 2014
Supplemental Cash Flow Information [Abstract]
Consolidated Statement Of Cash Flows	Changes in the components of operating assets and liabilities are as follows (in thousands):
		Year Ended December 31,
		2012			2013			2014
	Trade accounts receivable and other accounts receivable	$	(10,867	)	$	(19,314	)	$	49,215
	Inventory	36,972			34,664			29,462
	Energy commodity derivatives contracts, net of derivatives deposits	16,097			534			(7,583		)
	Accounts payable	(11,175		)	2,002			(10,918		)
	Accrued payroll and benefits	2,250			9,809			6,055
	Accrued interest payable	1,512			2,876			1,038
	Accrued taxes other than income	5,519			5,485			9,094
	Accrued product purchases	12,249			(9,016		)	(18,678		)
	Deferred revenue	6,388			16,793			7,978
	Current and noncurrent environmental liabilities	(1,372		)	(12,247		)	(2,144		)
	Other current and noncurrent assets and liabilities	(13,510		)	(15,502		)	19,875
	Total	$	44,063		$	16,084		$	83,394

Investments_in_NonControlled_E1

Investments in Non-Controlled Entities Investments in Non-Controlled Entities (Tables)	12 Months Ended
	Dec. 31, 2014
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	A summary of our investments in non-controlled entities follows (in thousands):
		BridgeTex			All Others			Consolidated
	Investments at December 31, 2013	$	246,875		$	113,977		$	360,852
	Additional investment	392,812			15,189			408,001
	Adjustment to investment due to the distribution of assets to owners	(165,157		)	—			(165,157		)
	Other adjustment to investment	—			(650		)	(650		)
	Earnings of non-controlled entities:
	Proportionate share of earnings	15,348			5,326			20,674
	Amortization of excess investment and capitalized interest	(530		)	(750		)	(1,280		)
	Earnings of non-controlled entities	14,818			4,576			19,394
	Less:
	Distributions of earnings from investments in non-controlled entities	—			3,086			3,086
	Distributions in excess of earnings of non-controlled entities	—			5,487			5,487
	Investments at December 31, 2014	$	489,348		$	124,519		$	613,867
	Summarized financial information of our non-controlled entities as of and for the year ended December 31, 2014 follows (in thousands):
		BridgeTex			All Others			Consolidated
	Current assets	$	66,409		$	11,032		$	77,441
	Noncurrent assets	821,323			210,587			1,031,910
	Total assets	$	887,732		$	221,619		$	1,109,351
	Current liabilities	$	71,066		$	4,724		$	75,790
	Noncurrent liabilities	94			1,783			1,877
	Total liabilities	$	71,160		$	6,507		$	77,667
	Equity	$	816,572		$	215,112		$	1,031,684
	Revenue	$	49,200		$	34,856		$	84,056
	Net income	$	30,696		$	10,583		$	41,279

Business_Combinations_and_Asse1

Business Combinations and Asset Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Schedule of Business Acquisitions, by Acquisition [Table Text Block]	The final purchase price and assessment of the fair value of the assets acquired and liabilities assumed in the business combination we completed during 2013 were as follows (in thousands):
	Purchase price allocation:	$	192,000
	Fair value of assets acquired (liabilities assumed):
	Property, plant and equipment	$	192,422
	Other current assets	2,048
	Current environmental liabilities	(2,470		)
	Total	$	192,000
	The following amounts from this business combination were included in our operating results for the year ending December 31, 2013 (in thousands):
	Revenue		$	12,661
	Operating profit		$	6,400
	The following summarized pro forma consolidated income statement information assumes that this acquisition of a business during 2013 referred to above occurred as of January 1, 2012. These pro forma results are for comparative purposes only and may not be indicative of the results that would have occurred had this acquisition been completed on January 1, 2012 or the results that will be attained in the future (in thousands).
			Year Ended December 31, 2012				Year Ended December 31, 2013
			As Reported		Pro Forma		As Reported		Pro Forma
	Revenue		$	1,772,074	$	1,812,635	$	1,897,606	$	1,924,316
	Net income		$	435,670	$	442,096	$	582,237	$	591,377

Inventory_Tables

Inventory (Tables)	12 Months Ended
	Dec. 31, 2014
Inventory Disclosure [Abstract]
Inventory	Inventory at December 31, 2013 and 2014 was as follows (in thousands):
		December 31,
		2013		2014
	Refined products	$	77,144	$	67,055
	Liquefied petroleum gases	23,476		37,642
	Transmix	72,156		36,867
	Crude oil	7,188		10,015
	Additives	7,260		6,183
	Total inventory	$	187,224	$	157,762

Product_Sales_Revenue_Tables

Product Sales Revenue (Tables)	12 Months Ended
	Dec. 31, 2014
Product Sales Revenue [Abstract]
Disclosure Of Product Sales Revenue	For the years ended December 31, 2012, 2013 and 2014, product sales revenue included the following (in thousands):
		Year Ended December 31,
		2012			2013			2014
	Physical sale of refined products	$	833,581		$	755,266		$	733,654
	NYMEX contract adjustments:
	Change in value of NYMEX contracts that did not qualify for hedge accounting treatment and the effective portion of gains and losses of matured NYMEX contracts that qualified for hedge accounting treatment associated with our butane blending and fractionation activities(1)	(30,270		)	(10,586		)	145,308
	Change in value of NYMEX contracts that did not qualify for hedge accounting treatment associated with the Houston-to-El Paso pipeline section linefill working inventory(1)	(3,940		)	—			—
	Other	11			(11		)	12
	Total NYMEX contract adjustments	(34,199		)	(10,597		)	145,320
	Total product sales revenue	$	799,382		$	744,669		$	878,974
	(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.

Property_Plant_And_Equipment_T

Property, Plant And Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment consisted of the following (in thousands):
						Estimated  Depreciable Lives
		December 31,
		2013		2014
	Construction work-in-progress	$	165,129	$	314,349
	Land and rights-of-way	78,405		75,219
	Carrier property	2,135,905		2,231,319		7 to 59 years
	Buildings	41,383		45,567		20 to 55 years
	Storage tanks	1,141,271		1,198,758		10 to 40 years
	Pipeline and station equipment	593,396		715,891		3 to 59 years
	Processing equipment	716,103		826,587		3 to 56 years
	Other	115,158		126,245		3 to 48 years
	Property, Plant and Equipment, Gross	$	4,986,750	$	5,533,935

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
Changes In Benefit Obligations And Plan Assets	The following table presents the changes in benefit obligations and plan assets for pension benefits and other postretirement benefits for the years ended December 31, 2013 and 2014 (in thousands):
			Pension Benefits							Other Postretirement Benefits
			2013				2014			2013				2014
	Change in benefit obligation:
	Benefit obligation at beginning of year		$	142,703			$	142,310		$	13,195			$	10,418
	Service cost		13,901				13,400			288				227
	Interest cost		5,368				6,675			412				506
	Plan participants’ contributions		—				—			248				210
	Actuarial loss (gain)		(14,121		)		37,934			(2,675		)		1,951
	Benefits paid		(5,541		)		(4,196		)	(1,050		)		(866		)
	Settlement payments		—				(5,460		)	—				—
	Benefit obligation at end of year		142,310				190,663			10,418				12,446
	Change in plan assets:
	Fair value of plan assets at beginning of year		87,106				100,556			—				—
	Employer contributions		15,470				24,056			802				656
	Plan participants’ contributions		—				—			248				210
	Actual return on plan assets		3,521				12,311			—				—
	Benefits paid		(5,541		)		(4,196		)	(1,050		)		(866		)
	Settlement payments		—				(5,460		)	—				—
	Fair value of plan assets at end of year		100,556				127,267			—				—
	Funded status at end of year		$	(41,754	)		$	(63,396	)	$	(10,418	)		$	(12,446	)
	Accumulated benefit obligation		$	103,466			$	137,851
Amounts Recognized In Consolidated Balance Sheets	Amounts recognized in the consolidated balance sheets included in these financial statements were as follows (in thousands):
			Pension Benefits							Other Postretirement Benefits
			2013				2014			2013				2014
	Amounts recognized in consolidated balance sheets:
	Current accrued benefit cost		$	—			$	—		$	(535	)		$	(687	)
	Long-term pension and benefit cost		(41,754		)		(63,396		)	(9,883		)		(11,759		)
			(41,754		)		(63,396		)	(10,418		)		(12,446		)
	Accumulated other comprehensive loss:
	Net actuarial loss		36,151				63,257			7,708				8,744
	Prior service cost (credit)		33				—			(10,761		)		(7,048		)
			36,184				63,257			(3,053		)		1,696
	Net amount recognized in consolidated balance sheets		$	(5,570	)		$	(139	)	$	(13,471	)		$	(10,750	)
Consolidated Net Periodic Benefit Costs	Net periodic benefit expense for the years ended December 31, 2012, 2013 and 2014 were as follows (in thousands):
			Pension Benefits											Other  Postretirement Benefits
			2012				2013			2014				2012			2013			2014
	Components of net periodic pension and postretirement benefit expense:
	Service cost		$	12,222			$	13,901		$	13,400			$	396		$	288		$	227
	Interest cost		4,862				5,368			6,675				821			412			506
	Expected return on plan assets		(5,066		)		(6,228		)	(6,363		)		—			—			—
	Amortization of prior service cost (credit)		307				307			33				(1,971		)	(3,712		)	(3,713		)
	Amortization of actuarial loss		3,605				4,334			3,071				1,021			1,035			915
	Settlement cost(1)		—				—			1,809				—			—			—
	Net periodic expense (credit)		$	15,930			$	17,682		$	18,625			$	267		$	(1,977	)	$	(2,065	)
Other Changes In Plan Assets And Benefit Obligations Recognized In Other Comprehensive Loss	Other changes in plan assets and benefit obligations recognized in other comprehensive loss during 2013 and 2014 were as follows (in thousands):
			Pension Benefits							Other Postretirement Benefits
			2013				2014			2013				2014
	Other changes in plan assets and benefit obligations recognized in other comprehensive loss:
	Net actuarial loss (gain)		$	(11,414	)		$	31,986		$	(2,675	)		$	1,951
	Amortization of prior service credit (cost)		(307		)		(33		)	3,712				3,713
	Amortization of actuarial loss		(4,334		)		(3,071		)	(1,035		)		(915		)
	Settlement cost		—				(1,809		)	—				—
	Total recognized in other comprehensive loss		(16,055		)		27,073			2				4,749
	Net periodic expense (credit)		17,682				18,625			(1,977		)		(2,065		)
	Total recognized in net periodic benefit cost and other comprehensive loss		$	1,627			$	45,698		$	(1,975	)		$	2,684
Weighted-Average Rate Assumptions Used For Benefit Obligations	The weighted-average rate assumptions used to determine benefit obligations as of December 31, 2013 and 2014 were as follows:
			Pension Benefits				Other
							Postretirement Benefits
			2013		2014		2013		2014
	Discount rate—Salaried plan		4.89%		3.91%		n/a		n/a
	Discount rate—USW plan		4.26%		3.56%		n/a		n/a
	Discount rate—IUOE plan		4.89%		3.93%		n/a		n/a
	Discount rate—Other Postretirement Benefits		n/a		n/a		4.52%		3.66%
	Rate of compensation increase—Salaried plan		5.00%		5.00%		n/a		n/a
	Rate of compensation increase—USW plan		3.50%		3.50%		n/a		n/a
	Rate of compensation increase—IUOE plan		5.00%		5.00%		n/a		n/a
	The weighted-average rate assumptions used to determine net pension and other postretirement benefit expense for the years ended December 31, 2012, 2013 and 2014 were as follows:
			Pension Benefits						Other
									Postretirement Benefits
			2012		2013		2014		2012	2013			2014
	Discount rate—Salaried plan		4.39%		4.00%		4.89%		n/a	n/a			n/a
	Discount rate—USW plan		4.00%		3.39%		4.07%		n/a	n/a			n/a
	Discount rate—IUOE plan		4.37%		3.99%		4.89%		n/a	n/a			n/a
	Discount rate—Other Postretirement Benefits		n/a		n/a		n/a		3.75%	3.58	%		4.52	%
	Rate of compensation increase—Salaried plan		5.00%		5.00%		5.00%		n/a	n/a			n/a
	Rate of compensation increase—USW plan		3.50%		3.50%		3.50%		n/a	n/a			n/a
	Rate of compensation increase—IUOE plan		5.00%		5.00%		5.00%		n/a	n/a			n/a
	Expected rate of return on plan assets—Salaried plan		6.80%		6.80%		6.00%		n/a	n/a			n/a
	Expected rate of return on plan assets—USW plan		6.80%		6.80%		6.00%		n/a	n/a			n/a
	Expected rate of return on plan assets—IUOE plan		6.80%		6.80%		6.00%		n/a	n/a			n/a
Changes In Assumed Health Care Cost Trend Rates	As of December 31, 2014, a 1.0% change in assumed health care cost trend rates would have the following effect (in thousands):
			1%				1%
			Increase				Decrease
	Change in total of service and interest cost components		$	31			$	28
	Change in postretirement benefit obligation		$	566			$	519
Fair Value, Assets Measured on Recurring Basis [Table Text Block]	The fair value of the pension plan assets at December 31, 2013 were as follows (in thousands):
	Asset Category		Total				Quoted Prices in Active  Markets for			Significant				Significant
							Identical Assets			Observable				Unobservable
							(Level 1)			Inputs				Inputs
										(Level 2)				(Level 3)
	Domestic Equity Securities(a):
	Small-cap fund		$	2,480			$	2,480		$	—			$	—
	Mid-cap fund		2,465				2,465			—				—
	Large-cap fund		18,642				18,642			—				—
	International equity fund		11,793				11,793			—				—
	Fixed Income Securities(a):
	Short-term bond funds		3,243				3,243			—				—
	Intermediate-term bond funds		12,492				12,492			—				—
	Long-term investment grade bond fund		45,900				45,900			—				—
	Other:
	Short-term investment funds		3,244				3,244			—				—
	Group annuity contract		297				—			—				297
	Fair value of plan assets		$	100,556			$	100,259		$	—			$	297
	(a) We hold equity and fixed income securities through investments in mutual funds, which are dedicated to each category as indicated.
	The fair value of the pension plan assets at December 31, 2014 were as follows (in thousands):
	Asset Category		Total				Quoted Prices in Active  Markets for			Significant				Significant
							Identical Assets			Observable				Unobservable
							(Level 1)			Inputs				Inputs
										(Level 2)				(Level 3)
	Domestic Equity Securities(a):
	Small-cap fund		$	3,050			$	3,050		$	—			$	—
	Mid-cap fund		3,025				3,025			—				—
	Large-cap fund		22,760				22,760			—				—
	International equity fund		13,990				13,990			—				—
	Fixed Income Securities(a):
	Short-term bond funds		3,485				3,485			—				—
	Intermediate-term bond funds		19,713				19,713			—				—
	Long-term investment grade bond funds		56,361				56,361			—				—
	Other:
	Short-term investment funds		4,603				4,603			—				—
	Group annuity contract		280				—			—				280
	Fair value of plan assets		$	127,267			$	126,987		$	—			$	280
	(a) We hold equity and fixed income securities through investments in mutual funds, which are dedicated to each category as indicated.
Fair Value Of Annuity Contract With Unobservable Inputs	The fair value measurements for the group annuity contract which used significant unobservable inputs (Level 3) for the years ended December 31, 2013 and 2014 were as follows (in thousands):
		2013				2014
	Beginning balance	$	358			$	297
	Actual return on plan assets:
	Relating to assets still held at the reporting date	(7		)		17
	Purchases, issuances, sales and settlements:
	Settlements	(54		)		(34		)
	Ending balance	$	297			$	280
Schedule of Allocation of Plan Assets	The target allocation and actual weighted-average asset allocation percentages at December 31, 2013 and 2014 were as follows:
			2013				2014
			Actual(a)		Target		Actual(a)		Target
	Equity securities		35%		30%		34%		30%
	Debt securities		62%		67%		62%		67%
	Other		3%		3%		4%		3%
	(a)	Cash contributions of $15.5 million and $24.1 million were made to the pension plans during 2013 and 2014, respectively. Amounts contributed in 2013 and 2014 in excess of benefit payments made were to be invested in debt and equity securities over a twelve-month period, with the amounts that remained uninvested as of December 31, 2013 and 2014 scheduled for investment in accordance with the target. Excluding these uninvested cash amounts, the actual allocation percentages at December 31, 2013 would have been 36% equity securities and 64% debt securities and at December 31, 2014, would have been 35% equity securities and 65% debt securities. In 2015, we will invest these uninvested cash amounts to bring the total asset allocation in line with the target allocation.
Expected Benefit Payments	As of December 31, 2014, the benefit amounts we expect to pay through December 31, 2024 were as follows (in thousands):
			Pension				Other
			Benefits				Postretirement
							Benefits
	2015		$	5,994			$	687
	2016		$	6,653			$	631
	2017		$	10,170			$	655
	2018		$	10,185			$	681
	2019		$	10,597			$	756
	2020 through 2024		$	72,278			$	4,497

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Consolidated Debt	Debt at December 31, 2013 and 2014 was as follows (in thousands):
							Weighted-Average Interest Rate at December 31, 2014 (1)
			December 31,
			2013		2014
	Commercial paper(2)		$	—	$	296,942	0.30%
	Revolving credit facility(2)		—		—		1.30%
	$250.0 million of 6.45% Notes due 2014(2)		249,971		—		6.30%
	$250.0 million of 5.65% Notes due 2016		251,183		250,758		5.70%
	$250.0 million of 6.40% Notes due 2018		259,346		257,280		5.40%
	$550.0 million of 6.55% Notes due 2019		571,515		567,868		5.70%
	$550.0 million of 4.25% Notes due 2021		557,213		556,304		4.00%
	$250.0 million of 6.40% Notes due 2037		248,998		249,017		6.40%
	$250.0 million of 4.20% Notes due 2042		248,377		248,406		4.20%
	$550.0 million ($300.0 million at December 31, 2013) of 5.15% Notes due 2043(2)		298,684		556,320		5.10%
	Total debt		$	2,685,287	$	2,982,895	4.90%
	-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 year ending December 31, 2014 (borrowings on our revolving credit facility and senior notes due 2014 were repaid before year end). 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)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule Of Forward Purchase And Sales Contracts	As of December 31, 2014, we had commitments under these forward purchase and sale contracts as follows (in millions):
		Notional Value				Barrels
	Forward purchase contracts	$	108.2			2.8
	Forward sale contracts	$	0.5			—
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 December 31, 2014 were as follows:
	Type of Contract/Accounting Methodology		Product Represented by the Contract and Associated Barrels		Maturity Dates
	NYMEX - Fair Value Hedges		0.7 million barrels of crude oil		Between December 2015 and November 2016
	NYMEX - Economic Hedges		3.5 million barrels of refined products and crude oil		Between January and October 2015
	CME Butane Futures Agreements - Economic Hedges		0.4 million barrels of butane		Between January and April 2015
Derivatives and Offset Amounts [Table Text Block]	A schedule of the derivative amounts we have offset and the deposit amounts we could offset under a master netting arrangement are provided below as of December 31, 2013 and 2014 (in thousands):
			31-Dec-13
	Description		Gross Amounts of Recognized Liabilities				Gross Amounts of Assets				Net Amounts of Liabilities Presented in the Consolidated Balance Sheet(1)				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet				Net Asset Amount(3)
	Energy commodity derivatives		$	(7,167	)		$	2,665			$	(4,502	)		$	14,782			$	10,280
			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(2)				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
	(1) Net amount includes energy commodity derivative contracts classified as current liabilities, net, of $6,737 and noncurrent assets of $2,235.
	(2) Net amount includes energy commodity derivative contracts classified as current 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.
Derivatives And Hedging-Cash Flow Hedges	The following is a summary of the effect on our consolidated statements of income and statements of comprehensive income for the years ended December 31, 2012, 2013 and 2014 of derivatives accounted for under ASC 815-30, Derivatives and Hedging—Cash Flow Hedges, that were designated as hedging instruments (in thousands). See Note 7 - Product Sales Revenue for further details regarding the impact of our NYMEX agreements on product sales.
			Year Ended December 31, 2012
	Derivative Instrument		Amount of Gain Recognized in AOCL on  Derivative						Location of Gain Reclassified from AOCL into Income		Amount of Gain Reclassified from AOCL into Income
											Effective Portion						Ineffective Portion
	Interest rate contracts			$	10,977				Interest expense			$	164					$	—
	NYMEX commodity contracts			2,912					Product sales revenue			2,760						—
	Total cash flow hedges			$	13,889				Total			$	2,924					$	—
			Year Ended December 31, 2013
	Derivative Instrument		Amount of Loss Recognized in AOCL on  Derivative						Location of Gain (Loss) Reclassified from AOCL into Income		Amount of Gain (Loss) Reclassified from AOCL into Income
											Effective Portion						Ineffective Portion
	Interest rate contracts			$	(184	)			Interest expense			$	163					$	—
	NYMEX commodity contracts			(4,560		)			Product sales revenue			(4,408		)				—
	Total cash flow hedges			$	(4,744	)			Total			$	(4,245	)				$	—
			Year Ended December 31, 2014
	Derivative Instrument		Amount of Loss Recognized in AOCL on  Derivative						Location of Loss Reclassified from AOCL into Income		Amount of Gain (Loss) Reclassified from AOCL into Income
											Effective Portion						Ineffective Portion
	Interest rate contracts			$	(30,090	)			Interest expense			$	(242	)				$	366
Derivatives And Hedging-Overall-Subsequent Measurement	The following table provides a summary of the effect on our consolidated statements of income for the years ended December 31, 2012, 2013 and 2014 of derivatives accounted for under ASC 815-10-35; Derivatives and Hedging—Overall—Subsequent Measurement, that were not designated as hedging instruments (in thousands):
					Amount of Gain (Loss)
					Recognized on Derivative
					Year Ended December 31,
	Derivative Instrument		Location of Gain (Loss)		2012				2013				2014
			Recognized on Derivative
	NYMEX commodity contracts		Product sales revenue		$	(36,959	)		$	(6,189	)		$	145,320
	NYMEX commodity contracts		Operating expenses		(2,055		)		(3,770		)		17,818
	Butane futures agreements		Cost of product sales		1,203				2,682				(17,141		)
			Total		$	(37,811	)		$	(7,277	)		$	145,997
Derivatives And Hedging-Designated	The following tables provide a summary of the amounts included on our consolidated balance sheets of the fair value of derivatives accounted for under ASC 815, Derivatives and Hedging, that were designated as hedging instruments as of December 31, 2013 and 2014 (in thousands):
			December 31, 2013
			Asset Derivatives						Liability Derivatives
	Derivative Instrument		Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
	NYMEX commodity contracts		Energy commodity derivatives contracts, net		$	—			Energy commodity derivatives contracts, net		$	146
	NYMEX commodity contracts		Other noncurrent assets		2,235				Other noncurrent liabilities		—
			Total		$	2,235			Total		$	146
			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
	The following tables provide a summary of the amounts included on our consolidated balance sheets of the fair value of derivatives accounted for under ASC 815, Derivatives and Hedging, that were not designated as hedging instruments as of December 31, 2013 and 2014 (in thousands):
			December 31, 2013
			Asset Derivatives						Liability Derivatives
	Derivative Instrument		Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
	NYMEX commodity contracts		Energy commodity derivatives contracts, net		$	48			Energy commodity derivatives contracts, net		$	7,021
	Butane futures agreements		Energy commodity derivatives contracts, net		382				Energy commodity derivatives contracts, net		—
			Total		$	430			Total		$	7,021
			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		$	—
	Butane futures agreements		Energy commodity derivatives contracts, net		—				Energy commodity derivatives contracts, net		10,622
			Total		$	92,000			Total		$	10,622

Leases_Tables

Leases (Tables)	12 Months Ended
	Dec. 31, 2014
Leases [Abstract]
Lessee, Future Minimum Rental Payments	Future minimum annual rentals under non-cancellable operating leases with initial or remaining terms greater than one year as of December 31, 2014, were as follows (in millions):
	2015	$	26.5
	2016	23.9
	2017	23.3
	2018	18.6
	2019	8
	Thereafter	82.5
	Total	$	182.8
Lessor, Future Minimum Payments Receivable	Future minimum payments receivable under these arrangements as of December 31, 2014, were as follows (in millions):
	2015	$	249.7
	2016	229
	2017	158.3
	2018	110.4
	2019	83.3
	Thereafter	266.1
	Total	$	1,096.80
Leases, Investment in Direct Financing Lease	The net investment under direct financing leasing arrangements as of December 31, 2014 was as follows (in millions):
			December 31, 2014
	Total minimum lease payments receivable		$	37.9
	Less: Unearned income		7
	Recorded net investment in direct financing lease		$	30.9
	The net investment in direct financing leases was classified in the consolidated balance sheets as follows (in millions):
			31-Dec-14
	Current accounts receivable		$	6.1
	Non-current accounts receivable		24.8
	Total		$	30.9

LongTerm_Incentive_Plan_Tables

Long-Term Incentive Plan (Tables)	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Changes In Non-Vested Unit Awards	The amounts below include no adjustments for above-target or below-target performance and forfeitures are actual amounts through December 31, 2014.
			Equity Method															Liability Method Performance-Based Awards
			Performance-Based Awards								Retention Awards													Total Awards
			Number of Unit				Weighted-Average Grant Date Fair Value				Number of Unit			Weighted-Average Grant Date Fair Value				Number of Unit			Weighted-Average Fair Value			Number of Unit			Weighted-Average Fair Value
			Awards								Awards							Awards						Awards
	Non-vested units - 1/1/2014		389,410				$	41.9			75,211			$	32.87			97,355			$	63.27		561,976			$	44.4
	Units granted during 2014		187,371				$	72.77			33,903			$	82.86			—			$	—		221,274			$	74.32
	Units vested during 2014		(187,388	)			$	33.61			(60,514	)		$	34.35			(46,847	)		$	82.66		(294,749	)		$	41.56
	Units forfeited during 2014		(39,076	)			$	41.88			(1,932	)		$	31.66			(9,630	)		$	82.66		(50,638	)		$	49.24
	Non-vested units - 12/31/14		350,317		—		$	62.85			46,668			$	76.99			40,878			$	82.66		437,863			$	66.21
Total Non-Vested Unit Awards	The table below summarizes the total non-vested unit awards granted by the compensation committee adjusted for units we estimate will be forfeited by the end of the vesting period and for estimated amounts of above-target financial performance to determine the total number of unit awards included in our total equity-based liability accrual.
	Grant Date	Unit Awards Granted			Estimated Forfeitures			Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results			Total Unit Award Accrual			Vesting Date		Unrecognized Compensation Expense(a)         (in millions)
	Performance-Based Awards:
	2013 Awards	228,498			31,870			245,786			442,414			12/31/15		$	8.5
	2014 Awards	187,371			8,899			89,239			267,711			12/31/16		13
	Retention Awards:
	2015 Vesting Date	444			23			—			421			12/31/15		—			(b)
	2016 Vesting Date	20,757			1,037			—			19,720			12/31/16		0.9
	2017 Vesting Date	25,438			1,272			—			24,166			12/31/17		1.9
	Total	462,508			43,101			335,025			754,432					$	24.3
	(a) Unrecognized compensation expense will be recognized over the remaining vesting period of the awards.
	(b) Less than $0.1 million.
Weighted-Average Grant Date Fair Values	The weighted-average grant-date fair value of award grants issued during 2012, 2013 and 2014 were as follows:
			Equity Method
			Performance-Based Awards							Retention Awards							Liability Method Performance-Based Awards
			Number of			Weighted-Average Grant Date Fair Value				Number of Unit			Weighted-Average Grant Date Fair Value				Number of Unit			Weighted-Average Fair Value
			Unit							Awards							Awards
			Awards
	Units granted during 2012		214,232			$	33.57			7,016			$	30.54			53,558			$	33.57
	Units granted during 2013		182,798			$	51.49			22,668			$	53.02			45,700			$	51.49
	Units granted during 2014		187,371			$	72.77			33,903			$	82.86			—			$	—
Vested Unit Awards	The table below sets forth the numbers and values of units that vested in each of the three years ended December 31, 2014. The vested limited partner units include adjustments for above-target performance.
	Vesting Date		Vested		Fair Value of Unit Awards on Vesting Date (in millions)		Intrinsic Value of Unit Awards on Vesting Date (in millions)
			Limited
			Partner Units
	12/31/12		751,237		$17.10		$32.50
	12/31/13		572,353		$20.50		$36.20
	12/31/14		528,984		$22.40		$43.70
Cash Flow Effects Of LTIP Settlements	We settle awards that vest by issuing limited partner units. The difference between the limited partner units issued to the participants and the total units accrued represents the minimum tax withholdings associated with the award settlement, which we pay in cash.
	Settlement Date		Number of Limited Partner Units Issued, Net of Tax Withholdings		Minimum Tax Withholdings		Employer Taxes (in millions)		Total Cash Taxes Paid (in millions)
					(in millions)
	Jan-12		722,766		$13.00		$1.30		$14.30
	Jan-13		476,682		$12.30		$1.10		$13.40
	Jan-14		387,216		$14.80		$1.20		$16.00
Equity-Based Incentive Compensation Expense	Equity-based incentive compensation expense for 2012, 2013 and 2014 was as follows (in thousands):
		Year Ended December 31, 2012												Year Ended December 31, 2013											Year Ended December 31, 2014
		Equity				Liability				Total				Equity				Liability				Total			Equity				Liability		Total
		Method				Method								Method				Method							Method				Method
	2010 awards	$	4,937			$	3,723			$	8,660			$	121			$	73			$	194		$	—			$	—	$	—
	2011 awards	5,062				2,094				7,156				5,359				4,280				9,639			—				—		—
	2012 awards	3,426				1,101				4,527				4,751				2,747				7,498			4,418				3,896		8,314
	2013 awards	—				—				—				4,726				1,451				6,177			7,427				3,425		10,852
	2014 awards	—				—				—				—				—				—			6,494				—		6,494
	Retention awards	693				—				693				575				—				575			1,624				—		1,624
	Total	$	14,118			$	6,918			$	21,036			$	15,532			$	8,551			$	24,083		$	19,963			$	7,321	$	27,284
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense									$	18,587											$	23,264								$	26,700
	Operating expense									2,449												819									584
	Total									$	21,036											$	24,083								$	27,284

Segment_Disclosures_Tables

Segment Disclosures (Tables)	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Segment Reporting Information By Segment
		Year Ended December 31, 2012
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
		(in thousands)
	Transportation and terminals revenue	$	723,835	$	92,288		$	154,621		$	—		$	970,744
	Product sales revenue	790,116		—			9,266			—			799,382
	Affiliate management fee revenue	—		1,734			214			—			1,948
	Total revenue	1,513,951		94,022			164,101			—			1,772,074
	Operating expenses	267,694		5,229			58,486			(2,955		)	328,454
	Cost of product sales	653,429		—			3,679			—			657,108
	Earnings of non-controlled entities	—		(2,574		)	(387		)	—			(2,961		)
	Operating margin	592,828		91,367			102,323			2,955			789,473
	Depreciation and amortization expense	86,218		12,228			26,611			2,955			128,012
	G&A expenses	87,309		5,420			16,674			—			109,403
	Operating profit	$	419,301	$	73,719		$	59,038		$	—		$	552,058
	Additions to long-lived assets	$	127,744	$	166,960		$	56,485					$	351,189
		As of December 31, 2012
	Segment assets	$	2,530,770	$	875,005		$	656,855					$	4,062,630
	Corporate assets												357,437
	Total assets												$	4,420,067
	Goodwill	$	38,369	$	12,082		$	2,809					$	53,260
	Investments in non-controlled entities	$	—	$	91,629		$	15,727					$	107,356
		Year Ended December 31, 2013
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
		(in thousands)
	Transportation and terminals revenue	$	801,128	$	178,409		$	158,791		$	—		$	1,138,328
	Product sales revenue	738,271		—			6,398			—			744,669
	Affiliate management fee revenue	—		13,361			1,248			—			14,609
	Total revenue	1,539,399		191,770			166,437			—			1,897,606
	Operating expenses	270,711		19,131			59,407			(3,179		)	346,070
	Cost of product sales	574,703		—			3,326			—			578,029
	Earnings of non-controlled entities	—		(3,781		)	(2,494		)	—			(6,275		)
	Operating margin	693,985		176,420			106,198			3,179			979,782
	Depreciation and amortization expense	86,926		24,119			28,006			3,179			142,230
	G&A expenses	91,658		19,896			20,942			—			132,496
	Operating profit	$	515,401	$	132,405		$	57,250		$	—		$	705,056
	Additions to long-lived assets	$	361,134	$	199,362		$	32,563					$	593,059
		As of December 31, 2013
	Segment assets	$	2,811,398	$	1,252,036		$	648,061					$	4,711,495
	Corporate assets												109,317
	Total assets												$	4,820,812
	Goodwill	$	38,369	$	12,082		$	2,809					$	53,260
	Investments in non-controlled entities	$	—	$	345,904		$	14,948					$	360,852
		Year Ended December 31, 2014
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
		(in thousands)
	Transportation and terminals revenue	$	921,762	$	310,136		$	170,740		$	—		$	1,402,638
	Product sales revenue	872,537		—			6,437			—			878,974
	Affiliate management fee revenue	—		20,790			1,321			—			22,111
	Total revenue	1,794,299		330,926			178,498			—			2,303,723
	Operating expenses	331,207		51,405			65,173			(3,513		)	444,272
	Cost of product sales	592,887		—			1,698			—			594,585
	Earnings of non-controlled entities	—		(16,309		)	(3,085		)	—			(19,394		)
	Operating margin	870,205		295,830			114,712			3,513			1,284,260
	Depreciation and amortization expense	101,642		27,800			28,786			3,513			161,741
	G&A expenses	96,411		29,557			22,320			—			148,288
	Operating profit	$	672,152	$	238,473		$	63,606		$	—		$	974,231
	Additions to long-lived assets	$	163,753	$	439,846		$	18,413					$	622,012
		As of December 31, 2014
	Segment assets	$	2,875,412	$	1,937,242		$	647,900					$	5,460,554
	Corporate assets												56,731
Total assets												$	5,517,285
Goodwill	$	38,369	$	12,082		$	2,809					$	53,260
Investments in non-controlled entities	$	—	$	599,757		$	14,110					$	613,867

Quarterly_Financial_Data_Table

Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data	Summarized quarterly financial data is as follows (in thousands, except per unit amounts):
	2013	First		Second		Third		Fourth
		Quarter		Quarter		Quarter		Quarter
	Revenue	$	432,421	$	443,912	$	443,835	$	577,438
	Total costs and expenses	$	291,967	$	260,191	$	291,586	$	355,081
	Operating margin	$	208,893	$	251,905	$	222,649	$	296,335
	Net income	$	112,967	$	153,640	$	125,623	$	190,007
	Basic net income per limited partner unit	$	0.5	$	0.68	$	0.55	$	0.84
	Diluted net income per limited partner unit	$	0.5	$	0.68	$	0.55	$	0.83
	2014
	Revenue	$	618,606	$	496,446	$	521,601	$	667,070
	Total costs and expenses	$	343,983	$	320,183	$	297,409	$	387,311
	Operating margin	$	347,535	$	264,424	$	299,268	$	373,033
	Net income	$	242,554	$	146,260	$	198,620	$	252,085
	Basic net income per limited partner unit	$	1.07	$	0.64	$	0.87	$	1.11
	Diluted net income per limited partner unit	$	1.07	$	0.64	$	0.87	$	1.1

Fair_Value_Disclosures_Tables

Fair Value Disclosures (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Recurring Fair Value Measurements Of Our Commodity Contracts And Interest Rate Swaps	The following tables summarize the carrying amounts, fair values and recurring fair value measurements recorded or disclosed as of December 31, 2013 and 2014, based on the three levels established by ASC 820; Fair Value Measurements and Disclosures (in thousands):
								Fair Value Measurements as of
								December 31, 2013 using:
	Assets (Liabilities)	Carrying Amount			Fair Value			Quoted Prices in			Significant Other			Significant
								Active Markets for			Observable			Unobservable
								Identical Assets			Inputs			Inputs
								(Level 1)			(Level 2)			(Level 3)
	Energy commodity derivatives contracts (liabilities)	$	(4,502	)	$	(4,502	)	$	(4,502	)	$	—		$	—
	Long-term receivables	$	2,730		$	2,658		$	—		$	—		$	2,658
	Debt	$	(2,685,287	)	$	(2,815,210	)	$	—		$	(2,815,210	)	$	—
								Fair Value Measurements as of
								December 31, 2014 using:
	Assets (Liabilities)	Carrying Amount			Fair Value			Quoted Prices in			Significant Other			Significant
								Active Markets for			Observable			Unobservable
								Identical Assets			Inputs			Inputs
								(Level 1)			(Level 2)			(Level 3)
	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	)	$	—

Distributions_Tables

Distributions (Tables)	12 Months Ended
	Dec. 31, 2014
Distributions Made to Members or Limited Partners [Abstract]
Schedule of Distributions Made to Members or Limited Partners, by Distribution [Table Text Block]	Distributions we paid during 2012, 2013 and 2014 were as follows (in thousands, except per unit amount):
	Payment Date	Per Unit Cash Distribution Amount		Total Cash Distribution
	2/14/12	$	0.4075	$	92,177
	5/15/12	0.42		95,004
	8/14/12	0.47125		106,597
	11/14/12	0.485		109,707
	Total	$	1.78375	$	403,485
	2/14/13	$	0.5	$	113,340
	5/15/13	0.5075		115,040
	8/14/13	0.5325		120,707
	11/14/13	0.5575		126,374
	Total	$	2.0975	$	475,461
	2/14/14	$	0.585	$	132,835
	5/15/14	0.6125		139,079
	8/14/14	0.64		145,324
	11/14/14	0.6675		151,568
	Total	$	2.505	$	568,806

Partners_CapitalTables

Partners' Capital(Tables)	12 Months Ended
	Dec. 31, 2014
Stockholders' Equity Note [Abstract]
Changes In Outstanding Limited Partner Units	The following table details the changes in the number of our limited partner units outstanding from January 1, 2012 through December 31, 2014:
	Limited partner units outstanding on January 1, 2012	225,473,142
	01/12—Settlement of 2009 award grants	722,766
	01/12—Other(a)	4,964
	Limited partner units outstanding on December 31, 2012	226,200,872
	01/13—Settlement of 2010 award grants	476,682
	01/13—Other(a)	1,884
	Limited partner units outstanding on December 31, 2013	226,679,438
	02/14—Settlement of 2011 award grants	387,216
	02/14—Other(a)	1,603
	Limited partner units outstanding on December 31, 2014	227,068,257
	(a)	Limited partner units issued to settle the equity-based retainer paid to independent directors of our general partner.

Organization_And_Description_O1

Organization And Description Of Business (Narrative) (Details)	Dec. 31, 2014
	mi
Osage Pipeline Co [Member]
Organization and Description of Business [Line Items]
Pipeline, Length	135
Equity Method Investment, Ownership Percentage	50.00%
Double Eagle Pipeline Llc [Member]
Organization and Description of Business [Line Items]
Pipeline, Length	195
Equity Method Investment, Ownership Percentage	50.00%
BridgeTex [Member]
Organization and Description of Business [Line Items]
Pipeline, Length	400
Equity Method Investment, Ownership Percentage	50.00%
Texas Frontera Llc [Member]
Organization and Description of Business [Line Items]
Storage Capacity	1,000,000
Equity Method Investment, Ownership Percentage	50.00%
Refined Products Segment [Member]
Organization and Description of Business [Line Items]
Number of Pipeline Terminals	53
Number of States in which Entity Operates	15
Number of Fractionators	3
Number of Independent Terminals	27
Refined Products Segment [Member] | Refined Products Transportation Services [Member]
Organization and Description of Business [Line Items]
Pipeline, Length	9,500
Refined Products Segment [Member] | Ammonia Transportation Services [Member]
Organization and Description of Business [Line Items]
Pipeline, Length	1,100
Crude Oil Pipeline and Terminals Segment [Member]
Organization and Description of Business [Line Items]
Pipeline, Length	1,600
Leaseable Storage Capacity	12,000,000
Crude Oil Pipeline and Terminals Segment [Member] | Osage Pipeline Co [Member]
Organization and Description of Business [Line Items]
Pipeline, Length	135
Equity Method Investment, Ownership Percentage	50.00%
Crude Oil Pipeline and Terminals Segment [Member] | Double Eagle Pipeline Llc [Member]
Organization and Description of Business [Line Items]
Pipeline, Length	195
Equity Method Investment, Ownership Percentage	50.00%
Crude Oil Pipeline and Terminals Segment [Member] | BridgeTex [Member]
Organization and Description of Business [Line Items]
Pipeline, Length	400
Equity Method Investment, Ownership Percentage	50.00%
Crude Oil Pipeline and Terminals Segment [Member] | Crane, Texas [Member]
Organization and Description of Business [Line Items]
Pipeline, Length	450
Crude Oil Pipeline and Terminals Segment [Member] | Cushing, Oklahoma [Member]
Organization and Description of Business [Line Items]
Leaseable Storage Capacity	10,000,000
Crude Oil Pipeline and Terminals Segment [Member] | East Houston, Texas [Member]
Organization and Description of Business [Line Items]
Leaseable Storage Capacity	1,000,000
Crude Oil Pipeline and Terminals Segment [Member] | Corpus Christi, Texas [Member]
Organization and Description of Business [Line Items]
Leaseable Storage Capacity	1,000,000
Crude Oil Pipeline and Terminals Segment [Member] | Kansas and Oklahoma [Member]
Organization and Description of Business [Line Items]
Pipeline, Length	300
Marine Storage Segment [Member]
Organization and Description of Business [Line Items]
Number of Independent Terminals	5
Storage Capacity	26,000,000
Marine Storage Segment [Member] | Texas Frontera Llc [Member]
Organization and Description of Business [Line Items]
Storage Capacity	1,000,000
Equity Method Investment, Ownership Percentage	50.00%

Summary_Of_Significant_Account3

Summary Of Significant Accounting Policies (Narrative) (Details) (USD $)	3 Months Ended		12 Months Ended
	Dec. 31, 2014		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Summary of Significant Accounting Policies [Line Items]
Lower-of-cost-or-market inventory adjustment	$39,300,000		$39,300,000
Equity investments, unamortized excess net investment	79,000,000		79,000,000		15,100,000
Goodwill	53,260,000		53,260,000		53,260,000		53,260,000
Intangible asset estimated useful life			6 years
Other intangible assets, amortization			2,700,000		6,000,000		1,900,000
Tank bottoms and linefill	42,585,000		42,585,000		61,915,000
Other Asset Impairment Charges			9,400,000
Interest capitalization threshold for construction in process			500,000
Deferred Cost Multiplier			0.5
Long-term Debt, Weighted Average Interest Rate	4.90%	[1]	4.90%	[1]	5.20%	[1]	5.30%	[1]
Refined Products Segment [Member]
Summary of Significant Accounting Policies [Line Items]
Goodwill	38,400,000		38,400,000
Crude Oil Pipeline and Terminals Segment [Member]
Summary of Significant Accounting Policies [Line Items]
Goodwill	12,100,000		12,100,000
Marine Storage Segment [Member]
Summary of Significant Accounting Policies [Line Items]
Goodwill	2,800,000		2,800,000
Minimum [Member]
Summary of Significant Accounting Policies [Line Items]
Intangible asset estimated useful life			5 years
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			3 years
Maximum [Member]
Summary of Significant Accounting Policies [Line Items]
Intangible asset estimated useful life			25 years
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			4 years
Sales [Member]
Summary of Significant Accounting Policies [Line Items]
Other intangible assets, amortization					200,000		600,000
Fair Value Hedging [Member]
Summary of Significant Accounting Policies [Line Items]
Derivative, Nonmonetary Notional Amount	700,000		700,000
Fair Value Hedging [Member] | Commodity Contract [Member]
Summary of Significant Accounting Policies [Line Items]
Derivative, Nonmonetary Notional Amount	700,000		700,000		700,000
Increase (Decrease) in Fair Value of Price Risk Fair Value Hedging Instruments			13,300,000		-8,700,000
Other Noncurrent Assets [Member] | Fair Value Hedging [Member] | Commodity Contract [Member]
Summary of Significant Accounting Policies [Line Items]
Increase (Decrease) in Fair Value of Price Risk Fair Value Hedging Instruments			$13,300,000		($8,700,000)
2013 Awards [Member] | Performance Shares [Member]
Summary of Significant Accounting Policies [Line Items]
Equity-based compensation, award payout percentage, minimum			0.00%
Equity-based compensation, award payout percentage, maximum			250.00%
2014 Awards [Member] | Performance Shares [Member]
Summary of Significant Accounting Policies [Line Items]
Equity-based compensation, award payout percentage, minimum			0.00%
Equity-based compensation, award payout percentage, maximum			200.00%
Equity Based Compensation Award Payout Fluctuation Of Award Market			50.00%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			3 years
[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.

Summary_Of_Significant_Account4

Summary Of Significant Accounting Policies (Amounts Included In Accumulated Other Comprehensive Loss) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance, Beginning	($19,504)		($35,058)		($47,201)
Net gain (loss) on cash flow hedges(1)	-30,090	[1]	-4,744	[1]	13,889	[1]
Reclassification of net loss (gain) on cash flow hedges to income(1)	-124	[1]	4,245	[1]	-2,924	[1]
Net actuarial loss(2)	-33,937	[2]	14,089	[2]	-17,804	[2]
Plan amendment(2)			0	[2]	16,020	[2]
Amortization of prior service credit(2)	-3,680	[2]	-3,405	[2]	-1,664	[2]
Amortization of actuarial loss(2)	3,986	[2]	5,369	[2]	4,626	[2]
Settlement cost(2)	1,809	[2]	0	[2]	0	[2]
Balance, Ending	-81,540		-19,504		-35,058
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance, Beginning	13,627		14,126		3,161
Net gain (loss) on cash flow hedges(1)	-30,090	[3]	-4,744	[3]	13,889	[3]
Reclassification of net loss (gain) on cash flow hedges to income(1)	-124	[3]	4,245	[3]	-2,924	[3]
Balance, Ending	-16,587		13,627		14,126
Accumulated Defined Benefit Plans Adjustment [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Balance, Beginning	-33,131		-49,184		-50,362
Net actuarial loss(2)	-33,937	[2]	14,089	[2]	-17,804	[2]
Plan amendment(2)	0	[2]			16,020	[2]
Amortization of prior service credit(2)	-3,680	[2]	-3,405	[2]	-1,664	[2]
Amortization of actuarial loss(2)	3,986	[2]	5,369	[2]	4,626	[2]
Settlement cost(2)	1,809	[2]
Balance, Ending	($64,953)		($33,131)		($49,184)
[1]	See Note 13–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 10–Employee Benefit Plans for additional detail of the changes in employee benefit plan assets and benefit obligations that are recognized in other comprehensive income (loss).
[3]	See Note 13–Derivative Financial Instruments for additional detail of the amount of gain (loss) recognized in AOCL on derivatives and the amount of (gain) loss reclassified from AOCL into income.

Consolidated_Statements_Of_Cas2

Consolidated Statements Of Cash Flows - Supplemental Disclosures (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplemental Cash Flow Information [Abstract]
Increase (decrease) in long-term pension and benefits liability	$33.90	($14.10)	$1.80
Increase (Decrease) in Derivative Liabilities	$26.50

Consolidated_Statements_Of_Cas3

Consolidated Statements Of Cash Flows - Supplemental Disclosures (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplemental Cash Flow Information [Abstract]
Trade accounts receivable and other accounts receivable	$49,215	($19,314)	($10,867)
Inventory	29,462	34,664	36,972
Energy commodity derivatives contracts, net of derivatives deposits	-7,583	534	16,097
Accounts payable	-10,918	2,002	-11,175
Accrued payroll and benefits	6,055	9,809	2,250
Accrued interest payable	1,038	2,876	1,512
Accrued taxes other than income	9,094	5,485	5,519
Accrued product purchases	-18,678	-9,016	12,249
Increase (Decrease) in Deferred Revenue	7,978	16,793	6,388
Current and noncurrent environmental liabilities	-2,144	-12,247	-1,372
Other current and noncurrent assets and liabilities	19,875	-15,502	-13,510
Changes in components of operating assets and liabilities	$83,394	$16,084	$44,063

Investments_in_NonControlled_E2

Investments in Non-Controlled Entities Investments in Non-Controlled Entities (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Nov. 30, 2014
				bbl
				mi
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2013	$360,852,000	$107,356,000
Additional Investments	408,001,000	250,495,000	74,934,000
Adjustment to JV Investment due to Sale of Assets	-165,157,000
Other Adjustment to Equity Investment	-650,000
Proportionate Share of Equity Earnings	20,674,000
Amortization of Excess Investment and Capitalized Interest	-1,280,000
Income (Loss) from Equity Method Investments	19,394,000	6,275,000	2,961,000
Distributions from investments in non-controlled entities	3,086,000	2,494,000	2,961,000
Distributions in excess of earnings of non-controlled entities	5,487,000	780,000	4,832,000
Investments at December 31, 2014	613,867,000	360,852,000	107,356,000
Equity Method Investment, Summarized Financial Information, Current Assets	77,441,000
Equity Method Investment, Summarized Financial Information, Noncurrent Assets	1,031,910,000
Equity Method Investment, Summarized Financial Information, Assets	1,109,351,000
Equity Method Investment, Summarized Financial Information, Current Liabilities	75,790,000
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities	1,877,000
Equity Method Investment, Summarized Financial Information, Liabilities	77,667,000
Equity Method Investment Summarized Financial Information, Equity	1,031,684,000
Equity Method Investment, Summarized Financial Information, Revenue	84,056,000
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	41,279,000
BridgeTex 40-Mile Pipeline [Member]
Schedule of Equity Method Investments [Line Items]
Storage Capacity				1,400,000
Pipeline, Length				40
Texas Frontera Llc [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Storage Capacity	1,000,000
Osage Pipeline Co [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Pipeline, Length	135
Double Eagle Pipeline Llc [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Pipeline, Length	195
Double Eagle Pipeline Llc [Member] | Corporate Joint Venture [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party	2,700,000	1,400,000
Accounts Receivable, Related Parties, Current	300,000	200,000
BridgeTex [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
Pipeline, Length	400
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2013	246,875,000
Additional Investments	392,812,000
Adjustment to JV Investment due to Sale of Assets	-165,157,000
Other Adjustment to Equity Investment	0
Proportionate Share of Equity Earnings	15,348,000
Amortization of Excess Investment and Capitalized Interest	-530,000
Income (Loss) from Equity Method Investments	14,818,000
Distributions from investments in non-controlled entities	0
Distributions in excess of earnings of non-controlled entities	0
Investments at December 31, 2014	489,348,000
Equity Method Investment, Summarized Financial Information, Current Assets	66,409,000
Equity Method Investment, Summarized Financial Information, Noncurrent Assets	821,323,000
Equity Method Investment, Summarized Financial Information, Assets	887,732,000
Equity Method Investment, Summarized Financial Information, Current Liabilities	71,066,000
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities	94,000
Equity Method Investment, Summarized Financial Information, Liabilities	71,160,000
Equity Method Investment Summarized Financial Information, Equity	816,572,000
Equity Method Investment, Summarized Financial Information, Revenue	49,200,000
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	30,696,000
BridgeTex [Member] | Corporate Joint Venture [Member]
Schedule of Equity Method Investments [Line Items]
Due to Related Parties, Current	2,200,000
BridgeTex [Member] | Corporate Joint Venture [Member] | BridgeTex 40-Mile Pipeline [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party	2,600,000
Accounts Receivable, Related Parties, Current	2,600,000
All Other Equity Investments [Member]
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2013	113,977,000
Additional Investments	15,189,000
Adjustment to JV Investment due to Sale of Assets	0
Other Adjustment to Equity Investment	-650,000
Proportionate Share of Equity Earnings	5,326,000
Amortization of Excess Investment and Capitalized Interest	-750,000
Income (Loss) from Equity Method Investments	4,576,000
Distributions from investments in non-controlled entities	3,086,000
Distributions in excess of earnings of non-controlled entities	5,487,000
Investments at December 31, 2014	124,519,000
Equity Method Investment, Summarized Financial Information, Current Assets	11,032,000
Equity Method Investment, Summarized Financial Information, Noncurrent Assets	210,587,000
Equity Method Investment, Summarized Financial Information, Assets	221,619,000
Equity Method Investment, Summarized Financial Information, Current Liabilities	4,724,000
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities	1,783,000
Equity Method Investment, Summarized Financial Information, Liabilities	6,507,000
Equity Method Investment Summarized Financial Information, Equity	215,112,000
Equity Method Investment, Summarized Financial Information, Revenue	34,856,000
Equity Method Investment, Summarized Financial Information, Net Income (Loss)	$10,583,000

Business_Combinations_and_Asse2

Business Combinations and Asset Acquisitions (Narrative) (Details) (USD $)	12 Months Ended			1 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Nov. 30, 2014	Jul. 31, 2013	Nov. 30, 2013
				mi	mi	mi
				bbl		bbl
						Terminal
Business Combination and Asset Acquisition [Line Items]
Acquisition of business	$0	$192,000,000	$0
Debt Instrument, Face Amount	2,900,000,000	2,700,000,000
Payments to Acquire Other Productive Assets	75,000,000	22,506,000	0
Plains Pipeline Acquisition [Member]
Business Combination and Asset Acquisition [Line Items]
Business Acquisition, Transaction Costs		2,800,000
BridgeTex 40-Mile Pipeline [Member]
Business Combination and Asset Acquisition [Line Items]
Pipeline, Length				40
Storage Capacity				1,400,000
Payments to Acquire Other Productive Assets				75,000,000
Acquisition of Assets Ownership Percentage				100.00%
New Mexico/Texas [Member] | Plains Pipeline Acquisition [Member]
Business Combination and Asset Acquisition [Line Items]
Pipeline, Length					250
Acquisition of business					57,000,000
Rocky Mountains [Member] | Plains Pipeline Acquisition [Member]
Business Combination and Asset Acquisition [Line Items]
Pipeline, Length						550
Acquisition of business						135,000,000
Number of Pipeline Terminals						4
Storage Capacity						1,700,000
Debt Offering Part One [Member] | Senior Notes [Member] | Five Point One Five Percentage Notes Due Two Thousand Forty Three [Member]
Business Combination and Asset Acquisition [Line Items]
Debt Instrument, Face Amount						$300,000,000

Schedule_of_Business_Acquisiti

Schedule of Business Acquisitions, by Acquisition (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Business Combination and Asset Acquisition [Line Items]
Revenues	$667,070	$521,601	$496,446	$618,606	$577,438	$443,835	$443,912	$432,421	$2,303,723	$1,897,606	$1,772,074
Operating Income (Loss)									974,231	705,056	552,058
Net income	252,085	198,620	146,260	242,554	190,007	125,623	153,640	112,967	839,519	582,237	435,670
Business Acquisition, Pro Forma Revenue										1,924,316	1,812,635
Business Acquisition, Pro Forma Net Income (Loss)										591,377	442,096
Plains Pipeline Acquisition [Member]
Business Combination and Asset Acquisition [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment					192,422					192,422
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other					2,048					2,048
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other					-2,470					-2,470
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Less Noncontrolling Interest					192,000					192,000
Revenues										12,661
Operating Income (Loss)										$6,400

Inventory_Inventory_Details

Inventory (Inventory) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Inventory Disclosure [Abstract]
Refined petroleum products	$67,055	$77,144
Liquefied petroleum gases	37,642	23,476
Transmix	36,867	72,156
Crude oil	10,015	7,188
Additives	6,183	7,260
Total inventory	$157,762	$187,224

Product_Sales_Revenue_Disclosu

Product Sales Revenue (Disclosure Of Product Sales Revenue) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Product Information [Line Items]
Physical sale of petroleum products	$733,654		$755,266		$833,581
NYMEX Adjustments Included in Product Sales	145,320		-10,597		-34,199
Total product sales revenues	878,974		744,669		799,382
Petroleum Products Blending And Fractionation Activities [Member]
Product Information [Line Items]
NYMEX Adjustments Included in Product Sales	145,308	[1]	-10,586	[1]	-30,270	[1]
Houston-To-El Paso Pipeline Section Line Fill And Working Inventory [Member]
Product Information [Line Items]
NYMEX Adjustments Included in Product Sales	0	[1]	0	[1]	-3,940	[1]
Other Product Sale Revenue [Member]
Product Information [Line Items]
NYMEX Adjustments Included in Product Sales	$12		($11)		$11
[1]	The associated petroleum products for these activities are, to the extent still owned as of the statement date, or were, to the extent no longer owned as of the statement date, classified as inventory in current assets on our consolidated balance sheets.

Property_Plant_And_Equipment_N

Property, Plant And Equipment (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$5,533,935,000	$4,986,750,000
Depreciation expense	159,000,000	136,400,000	126,700,000
Property, Plant and Equipment, Other Types [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	126,245,000	115,158,000
Capitalized Interest [Member] | Property, Plant and Equipment, Other Types [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$35,800,000	$33,200,000

Property_Plant_And_Equipment_P

Property, Plant And Equipment (Property, Plant And Equipment) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	5,533,935	$4,986,750
Construction in Progress [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	314,349	165,129
Land [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	75,219	78,405
Carrier Property [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	2,231,319	2,135,905
Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	45,567	41,383
Storage Tanks [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	1,198,758	1,141,271
Pipelines [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	715,891	593,396
Processing Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	826,587	716,103
Property, Plant and Equipment, Other Types [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	126,245	$115,158
Minimum [Member] | Carrier Property [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	7 years
Minimum [Member] | Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	20 years
Minimum [Member] | Storage Tanks [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	10 years
Minimum [Member] | Pipelines [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	3 years
Minimum [Member] | Processing Equipment [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	3 years
Minimum [Member] | Property, Plant and Equipment, Other Types [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	3 years
Maximum [Member] | Carrier Property [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	59 years
Maximum [Member] | Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	55 years
Maximum [Member] | Storage Tanks [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	40 years
Maximum [Member] | Pipelines [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	59 years
Maximum [Member] | Processing Equipment [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	56 years
Maximum [Member] | Property, Plant and Equipment, Other Types [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	48 years

Major_Customers_and_Concentrat1

Major Customers and Concentration Of Risks (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Concentration Risk [Line Items]
Number of employees	1,565
Refined Products Segment [Member]
Concentration Risk [Line Items]
Number of employees	880
Crude Oil Pipeline and Terminals Segment [Member]
Concentration Risk [Line Items]
Number of employees	88
Marine Storage Segment [Member]
Concentration Risk [Line Items]
Number of employees	169
Customer Concentration Risk [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	12.00%	8.00%	14.00%
Concentration Risk, Benchmark Percentage	10.00%
Unionized Employees Concentration Risk [Member] | Refined Products Segment [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	26.00%
Unionized Employees Concentration Risk [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	0.00%
Unionized Employees Concentration Risk [Member] | Marine Storage Segment [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	17.00%

Employee_Benefit_Plans_Narrati

Employee Benefit Plans (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	pension_plan
Defined Benefit Plan Disclosure [Line Items]
Number of Union Pension Plans	2
Defined contribution plan, expenses	$8,300,000	$7,100,000	$6,500,000
Defined benefit plan, assumed rate of increase in health care cost trend rate for 2013	5.80%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	4.60%
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Accumulated Benefit Obligation	137,851,000	103,466,000
Defined Benefit Plan, Fair Value of Plan Assets	127,267,000	100,556,000	87,106,000
Actuarial loss	37,934,000	-14,121,000
Defined Benefit Plan, Future Amortization of Gain (Loss)	-5,400,000
Contributions estimated to be paid	21,100,000
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0	0	0
Actuarial loss	1,951,000	-2,675,000
Defined Benefit Plan, Future Amortization of Gain (Loss)	-900,000
Defined Benefit Plan, Future Amortization of Prior Service Cost (Credit)	-3,700,000
Contributions estimated to be paid	700,000
Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations	67.00%	67.00%
Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations	30.00%	30.00%
Scenario, Plan [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations	70.00%
Scenario, Plan [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Target Plan Asset Allocations	30.00%
Unionized Employees Concentration Risk [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Projected Benefit Obligation		47,700,000
Defined Benefit Plan, Accumulated Benefit Obligation		41,100,000
Defined Benefit Plan, Fair Value of Plan Assets		$36,600,000

Employee_Benefit_Plans_Changes

Employee Benefit Plans (Changes In Benefit Obligations And Plan Assets) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Pension Plan [Member]
Change in benefit obligation:
Benefit obligation at beginning of year	$142,310	$142,703
Service cost	13,400	13,901	12,222
Interest cost	6,675	5,368	4,862
Plan participants’ contributions	0	0
Actuarial loss	37,934	-14,121
Benefits paid	-4,196	-5,541
Settlements	-5,460	0
Benefit obligation at end of year	190,663	142,310	142,703
Change in plan assets:
Beginning balance	100,556	87,106
Employer contributions	24,056	15,470
Plan participants’ contributions	0	0
Actual return on plan assets	12,311	3,521
Benefits paid	-4,196	-5,541
Settlements	-5,460	0
Fair value of plan assets at end of year	127,267	100,556	87,106
Funded status at end of year	-63,396	-41,754
Accumulated benefit obligation	137,851	103,466
Other Postretirement Benefits [Member]
Change in benefit obligation:
Benefit obligation at beginning of year	10,418	13,195
Service cost	227	288	396
Interest cost	506	412	821
Plan participants’ contributions	210	248
Actuarial loss	1,951	-2,675
Benefits paid	-866	-1,050
Settlements	0	0
Benefit obligation at end of year	12,446	10,418	13,195
Change in plan assets:
Beginning balance	0	0
Employer contributions	656	802
Plan participants’ contributions	210	248
Actual return on plan assets	0	0
Benefits paid	-866	-1,050
Settlements	0	0
Fair value of plan assets at end of year	0	0	0
Funded status at end of year	($12,446)	($10,418)

Employee_Benefit_Plans_Amounts

Employee Benefit Plans (Amounts Recognized In Consolidated Balance Sheets) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Amounts recognized in consolidated balance sheet:
Long-term pension and benefit cost	($75,155)	($51,637)
Pension Plan [Member]
Amounts recognized in consolidated balance sheet:
Current accrued benefit cost	0	0
Long-term pension and benefit cost	-63,396	-41,754
Net amount recognized in consolidated balance sheet	-63,396	-41,754
Accumulated other comprehensive loss:
Net actuarial loss	63,257	36,151
Prior service cost (credit)	0	33
Total pension and benefit costs included in accumulated other comprehensive loss	63,257	36,184
Total pension and benefit costs recognized in consolidated balance sheet	-139	-5,570
Other Postretirement Benefits [Member]
Amounts recognized in consolidated balance sheet:
Current accrued benefit cost	-687	-535
Long-term pension and benefit cost	-11,759	-9,883
Net amount recognized in consolidated balance sheet	-12,446	-10,418
Accumulated other comprehensive loss:
Net actuarial loss	8,744	7,708
Prior service cost (credit)	-7,048	-10,761
Total pension and benefit costs included in accumulated other comprehensive loss	1,696	-3,053
Total pension and benefit costs recognized in consolidated balance sheet	($10,750)	($13,471)

Employee_Benefit_Plans_Consoli

Employee Benefit Plans (Consolidated Net Periodic Benefit Costs) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Number of Employees Receiving USW Settlement	11
Pension Plan [Member]
Components of net periodic pension and postretirement benefit expense:
Service cost	$13,400		$13,901	$12,222
Interest cost	6,675		5,368	4,862
Expected return on plan assets	-6,363		-6,228	-5,066
Amortization of prior service cost (credit)	33		307	307
Amortization of net actuarial loss	3,071		4,334	3,605
Settlement	1,809	[1]	0	0
Net periodic expense (credit)	18,625		17,682	15,930
Other Postretirement Benefits [Member]
Components of net periodic pension and postretirement benefit expense:
Service cost	227		288	396
Interest cost	506		412	821
Expected return on plan assets	0		0	0
Amortization of prior service cost (credit)	-3,713		-3,712	-1,971
Amortization of net actuarial loss	915		1,035	1,021
Settlement	0		0	0
Net periodic expense (credit)	($2,065)		($1,977)	$267
[1]	Eleven participants took a lump sum distribution from the USW plan in 2014, resulting in a pension settlement cost of $1.8 million.

Employee_Benefit_Plans_Other_C

Employee Benefit Plans (Other Changes In Plan Assets And Benefit Obligations Recognized In Other Comprehensive Loss) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Other changes in plan assets and benefit obligations recognized in other comprehensive loss:
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax	$33,937	[1]	($14,089)	[1]	$17,804	[1]
Other Comprehensive (Income) Loss, Amortization Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Prior Service Cost (Credit), Net of Tax	3,680	[1]	3,405	[1]	1,664	[1]
Other Comprehensive Income (Loss), Reclassification, Pension and Other Postretirement Benefit Plans, Net Gain (Loss) Recognized in Net Periodic Benefit Cost, Net of Tax	-3,986	[1]	-5,369	[1]	-4,626	[1]
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	-1,809	[1]	0	[1]	0	[1]
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	62,036		-15,554		-12,143
Pension Plan [Member]
Other changes in plan assets and benefit obligations recognized in other comprehensive loss:
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax	31,986		-11,414
Other Comprehensive (Income) Loss, Amortization Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Prior Service Cost (Credit), Net of Tax	-33		-307
Other Comprehensive Income (Loss), Reclassification, Pension and Other Postretirement Benefit Plans, Net Gain (Loss) Recognized in Net Periodic Benefit Cost, Net of Tax	-3,071		-4,334
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	-1,809		0
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	27,073		-16,055
Net periodic expense (credit)	18,625		17,682		15,930
Total recognized in net periodic benefit cost and other comprehensive loss	45,698		1,627
Other Postretirement Benefits [Member]
Other changes in plan assets and benefit obligations recognized in other comprehensive loss:
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax	1,951		-2,675
Other Comprehensive (Income) Loss, Amortization Adjustment from AOCI, Pension and Other Postretirement Benefit Plans, for Net Prior Service Cost (Credit), Net of Tax	3,713		3,712
Other Comprehensive Income (Loss), Reclassification, Pension and Other Postretirement Benefit Plans, Net Gain (Loss) Recognized in Net Periodic Benefit Cost, Net of Tax	-915		-1,035
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	0		0
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent	4,749		2
Net periodic expense (credit)	-2,065		-1,977		267
Total recognized in net periodic benefit cost and other comprehensive loss	$2,684		($1,975)
[1]	See Note 10–Employee Benefit Plans for additional detail of the changes in employee benefit plan assets and benefit obligations that are recognized in other comprehensive income (loss).

Employee_Benefit_Plans_Weighte

Employee Benefit Plans (Weighted-Average Rate Assumptions Used For Benefit Obligations) (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Pension Plan [Member] | Salaried Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	3.91%	4.89%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	5.00%	5.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.89%	4.00%	4.39%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	5.00%	5.00%	5.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	6.00%	6.80%	6.80%
Pension Plan [Member] | USW Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	3.56%	4.26%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	3.50%	3.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.07%	3.39%	4.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	3.50%	3.50%	3.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	6.00%	6.80%	6.80%
Pension Plan [Member] | IUOE Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	3.93%	4.89%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	5.00%	5.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.89%	3.99%	4.37%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	5.00%	5.00%	5.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	6.00%	6.80%	6.80%
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	3.66%	4.52%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.52%	3.58%	3.75%

Employee_Benefit_Plans_Changes1

Employee Benefit Plans (Changes In Assumed Health Care Cost Trend Rates) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
Change in total service and interest cost components, 1% increase	$31
Change in total service and interest cost components, 1% decrease	28
Change in postretirement benefit obligation, 1% increase	566
Change in postretirement benefit obligation, 1% decrease	$519

Employee_Benefit_Plans_Fair_Va

Employee Benefit Plans (Fair Value Of Pension Plan Assets) (Details) (USD $)	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Group Annuity Contract [Member] | Significant Unobservable Inputs (Level 3) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	$280		$297		$358
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	127,267		100,556		87,106
Pension Plan [Member] | Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	126,987		100,259
Pension Plan [Member] | Significant Unobservable Inputs (Level 3) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	280		297
Pension Plan [Member] | Small-Cap Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	3,050	[1]	2,480	[1]
Pension Plan [Member] | Small-Cap Fund [Member] | Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	3,050	[1]	2,480	[1]
Pension Plan [Member] | Mid-Cap Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	3,025	[1]	2,465	[1]
Pension Plan [Member] | Mid-Cap Fund [Member] | Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	3,025	[1]	2,465	[1]
Pension Plan [Member] | Large-Cap Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	22,760	[1]	18,642	[1]
Pension Plan [Member] | Large-Cap Fund [Member] | Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	22,760	[1]	18,642	[1]
Pension Plan [Member] | International Equity Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	13,990	[1]	11,793
Pension Plan [Member] | International Equity Fund [Member] | Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	13,990	[1]	11,793
Pension Plan [Member] | Short-Term Bond Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	3,485	[1]	3,243	[1]
Pension Plan [Member] | Short-Term Bond Fund [Member] | Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	3,485	[1]	3,243	[1]
Pension Plan [Member] | Intermediate-Term Bond Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	19,713	[1]	12,492	[1]
Pension Plan [Member] | Intermediate-Term Bond Funds [Member] | Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	19,713	[1]	12,492	[1]
Pension Plan [Member] | Long-Term Investment Grade Bond Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	56,361	[1]	45,900	[1]
Pension Plan [Member] | Long-Term Investment Grade Bond Fund [Member] | Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	56,361	[1]	45,900	[1]
Pension Plan [Member] | Short-Term Investment Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	4,603		3,244
Pension Plan [Member] | Short-Term Investment Fund [Member] | Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	4,603		3,244
Pension Plan [Member] | Group Annuity Contract [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	280		297
Pension Plan [Member] | Group Annuity Contract [Member] | Quoted Prices In Active Markets For Identical Assets (Level 1) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	0		0
Pension Plan [Member] | Group Annuity Contract [Member] | Significant Unobservable Inputs (Level 3) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	$280		$297
[1]	We hold equity and fixed income securities through investments in mutual funds, which are dedicated to each category as indicated.

Employee_Benefit_Plans_Fair_Va1

Employee Benefit Plans (Fair Value Of Annuity Contract With Unobservable Inputs) (Details) (Group Annuity Contract [Member], Significant Unobservable Inputs (Level 3) [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Group Annuity Contract [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$297	$358
Actual return on plan assets:
Relating to assets still held at the reporting date	17	-7
Purchases, issuances, sales and settlements:
Settlements	-34	-54
Fair value of plan assets at end of year	$280	$297

Employee_Benefit_Plans_Investm

Employee Benefit Plans (Investment Strategies) (Details)	12 Months Ended
	Dec. 31, 2014
Small-Cap Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset Category	Small-cap fund
Fund's Investment Strategy	Seeks to track performance of the Center for Research in Security Prices ("CRSP") US Small Cap Index
Mid-Cap Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset Category	Mid-cap fund
Fund's Investment Strategy	Seeks to track performance of the CRSP US Mid Cap Index
Large-Cap Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset Category	Large-cap fund
Fund's Investment Strategy	Seeks to track performance of the Standard & Poor’s 500 Index
International Equity Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset Category	International equity fund
Fund's Investment Strategy	Seeks long-term growth of capital by investing 65% or more of assets in international equities
Short-Term Bond Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset Category	Short-term bond funds
Fund's Investment Strategy	Seeks current income with limited price volatility through investment in primarily high quality bonds
Intermediate-Term Bond Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset Category	Intermediate-term bond funds
Fund's Investment Strategy	Seeks moderate and sustainable level of current income by investing primarily in high quality fixed income securities with maturities from five to ten years
Long-Term Investment Grade Bond Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset Category	Long-term investment grade bond funds
Fund's Investment Strategy	Seeks high and sustainable current income through investment primarily in long-term high grade bonds
Short-Term Investment Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset Category	Short-term investment funds
Fund's Investment Strategy	Invests primarily in high quality commercial paper and government securities
Group Annuity Contract [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset Category	Group annuity contract
Fund's Investment Strategy	Guarantees a specified return based on a specified index

Employee_Benefit_Plans_Target_

Employee Benefit Plans (Target Allocation And Actual Weighted-Average Asset Allocation Of Plan Assets) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Actual plan asset allocation	34.00%	[1]	35.00%	[1]
Target plan asset allocation	30.00%		30.00%
Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Actual plan asset allocation	62.00%	[1]	62.00%	[1]
Target plan asset allocation	67.00%		67.00%
Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Actual plan asset allocation	4.00%	[1]	3.00%	[1]
Target plan asset allocation	3.00%		3.00%
Pro Forma [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Actual plan asset allocation	35.00%		36.00%
Pro Forma [Member] | Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Actual plan asset allocation	65.00%		64.00%
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Contributions by Employer	24,056		15,470
[1]	Cash contributions of $15.5 million and $24.1 million were made to the pension plans during 2013 and 2014, respectively. Amounts contributed in 2013 and 2014 in excess of benefit payments made were to be invested in debt and equity securities over a twelve-month period, with the amounts that remained uninvested as of December 31, 2013 and 2014 scheduled for investment in accordance with the target. Excluding these uninvested cash amounts, the actual allocation percentages at December 31, 2013 would have been 36% equity securities and 64% debt securities and at December 31, 2014, would have been 35% equity securities and 65% debt securities. In 2015, we will invest these uninvested cash amounts to bring the total asset allocation in line with the target allocation.

Employee_Benefit_Plans_Expecte

Employee Benefit Plans (Expected Benefit Payments) (Details) (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
2015	$5,994
2016	6,653
2017	10,170
2018	10,185
2019	10,597
2020 through 2024	72,278
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
2015	687
2016	631
2017	655
2018	681
2019	756
2020 through 2024	$4,497

Related_Party_Transactions_Nar

Related Party Transactions (Narrative) (Details) (Targa Resource Partners L P [Member], Director [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Targa Resource Partners L P [Member] | Director [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$28.20	$30.40	$27.40
Accounts Payable, Related Parties	$0.90	$1

Debt_Narrative_Details

Debt (Narrative) (Details) (USD $)	12 Months Ended			1 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2014
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$2,900,000,000	$2,700,000,000
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	0
Long-term Debt, Maturities, Repayments of Principal in Year Two	250,000,000
Long-term Debt, Maturities, Repayments of Principal in Year Three	0
Long-term Debt, Maturities, Repayments of Principal in Year Four	546,900,000
Long-term Debt, Maturities, Repayments of Principal in Year Five	550,000,000
Long-term Debt, Maturities, Repayments of Principal after Year Five	1,600,000,000
Payments of Debt Issuance Costs	2,912,000	4,849,000	2,552,000
Cash Payments for Interest	149,500,000	134,600,000	123,300,000
Senior Notes [Member] | 5.15% Notes Due 2043 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	550,000,000	300,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.15%
Senior Notes [Member] | 6.45% Notes Due 2014 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	0	250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.45%			6.45%
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	1,000,000,000
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	0.13%
Letters of Credit Outstanding, Amount	5,600,000
Debt Instrument, Covenant Description	The revolving credit facility described above requires us to maintain a specified ratio of consolidated debt to EBITDA (as defined in the agreement) of no greater than 5.0 to 1.0
Debt Instrument, Consolidated Debt to EBITDA Ratio	5
Revolving Credit Facility [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.75%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	0.28%
Revolving Credit Facility [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.00%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	0.10%
Commercial Paper [Member]
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Year Four	296,942,000
Line of Credit Facility, Maximum Borrowing Capacity	1,000,000,000
Commercial Paper [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Term	397 days
Debt Offering Part Two [Member] | Senior Notes [Member] | 5.15% Notes Due 2043 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount				250,000,000
Debt Instrument, Interest Rate, Stated Percentage				5.15%
Notes At Price				103.10%
After Underwriting Discounts				255,000,000
Payments of Debt Issuance Costs				$2,700,000

Debt_Consolidated_Debt_Details

Debt (Consolidated Debt) (Details) (USD $)	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Mar. 31, 2014
Debt Instrument [Line Items]
Long-term Debt	$2,982,895,000		$2,685,287,000
Long-term Debt, Weighted Average Interest Rate	4.90%	[1]	5.20%	[1]	5.30%	[1]
Debt Instrument, Face Amount	2,900,000,000		2,700,000,000
Commercial Paper [Member]
Debt Instrument [Line Items]
Long-term Debt	296,942,000		0
Long-term Debt, Weighted Average Interest Rate	0.30%	[1],[2]
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Long-term Debt	0		0
Long-term Debt, Weighted Average Interest Rate	1.30%	[1],[2]
6.45% Notes Due 2014 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt	0		249,971,000
Long-term Debt, Weighted Average Interest Rate	6.30%	[1],[2]
Debt Instrument, Face Amount	0		250,000,000				250,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.45%						6.45%
5.65% Notes Due 2016 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt	250,758,000		251,183,000
Long-term Debt, 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%
6.40% Notes Due 2018 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt	257,280,000		259,346,000
Long-term Debt, 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%
6.55% Notes Due 2019 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt	567,868,000		571,515,000
Long-term Debt, 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%
4.25% Notes Due 2021 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt	556,304,000		557,213,000
Long-term Debt, 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%
6.40% Notes Due 2037 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt	249,017,000		248,998,000
Long-term Debt, 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%
4.20% Notes Due 2042 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt	248,406,000		248,377,000
Long-term Debt, 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%
5.15% Notes Due 2043 [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Long-term Debt	556,320,000		298,684,000
Long-term Debt, Weighted Average Interest Rate	5.10%	[1],[2]
Debt Instrument, Face Amount	$550,000,000		$300,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.15%
[1]	Weighted-average interest rate includes the amortization/accretion of discounts, premiums and gains/losses realized on historical cash flow and fair value hedges recognized as interest expense.
[2]	These borrowings were outstanding for only a portion of the year ending December 31, 2014 (borrowings on our revolving credit facility and senior notes due 2014 were repaid before year end). 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_Instrumen2

Derivative Financial Instruments Derivative Financial Instruments (Narrative) (Details) (USD $)	12 Months Ended						0 Months Ended	1 Months Ended	3 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Oct. 03, 2013	Nov. 30, 2012	Mar. 31, 2014
								Payment
Derivative [Line Items]
Net gain (loss) on cash flow hedges(1)	($30,090,000)	[1]	($4,744,000)	[1]	$13,889,000	[1]
Debt Instrument, Face Amount	2,900,000,000		2,700,000,000
Energy commodity derivatives deposits	6,184,000		14,782,000
Deposit Liability, Current	84,463,000		0
Cash Flow Hedging [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	0
Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Notional Amount							150,000,000	250,000,000
Number of Future Semi-Annual Interest Payments Being Hedged								60
Net gain (loss) on cash flow hedges(1)							-200,000	11,000,000
Derivative, Term of Contract							30 years
Debt Instrument, Face Amount								250,000,000
Debt Instrument, Interest Rate, Stated Percentage								6.45%
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	366,000
Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	700,000
Fair Value Hedging [Member] | Commodity Contract [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	700,000		700,000
Increase (Decrease) in Fair Value of Price Risk Fair Value Hedging Instruments	13,300,000		-8,700,000
Gain (Loss) on Fair Value Hedge Ineffectiveness, Net	-8,600,000
Fair Value Hedging [Member] | Commodity Contract [Member] | Other Noncurrent Assets [Member]
Derivative [Line Items]
Increase (Decrease) in Fair Value of Price Risk Fair Value Hedging Instruments	13,300,000		-8,700,000
Interest Expense [Member]
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	-100,000
Future Debt Issue [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Notional Amount	250,000,000
Number of Future Semi-Annual Interest Payments Being Hedged	60
Derivative Liability, Fair Value, Gross Liability	26,478,000
Notes Due 2043 [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Notional Amount									200,000,000
Net gain (loss) on cash flow hedges(1)									-3,600,000
Debt Instrument, Face Amount									$250,000,000
Debt Instrument, Interest Rate, Stated Percentage									5.15%
[1]	See Note 13–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 Derivative Financial Instruments (Schedule of Forward Purchase and Sales Agreements) (Details) (Forward Contracts [Member], USD $)	Dec. 31, 2014
In Millions, unless otherwise specified	bbl
Forward Contracts [Member]
Derivative [Line Items]
Purchase Commitment, Remaining Minimum Amount Committed	$108.20
Barrels Accounted for Forward Purchase Contract for Product Purchases	2,800,000
Supply Commitment, Remaining Minimum Amount Committed	$0.50
Barrels Accounted for Forward Sale Contract for Product Sales	0

Derivative_Financial_Instrumen4

Derivative Financial Instruments (Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements) (Details)	Dec. 31, 2014	Dec. 31, 2013
	bbl	bbl
Cash Flow Hedging [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	0
Fair Value Hedging [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	700,000
Fair Value Hedging [Member] | Commodity Contract [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	700,000	700,000
Economic Hedges [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	3,500,000
Economic Hedges Futures [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	400,000

Derivative_Financial_Instrumen5

Derivative Financial Instruments Derivative Financial Instruments (Schedule of Derivative Offset Amounts) (Details) (Exchange Traded [Member], USD $)	Dec. 31, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Liability	($10,622)		($7,167)
Derivative Liability, Fair Value, Amount Not Offset Against Collateral			-4,502	[1]
Derivative, Collateral, Right to Reclaim Cash			14,782
Amount After Offset	17,863	[2]	10,280	[2]
Derivative Asset, Fair Value, Gross Asset	106,764		2,665
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	96,142	[3]
Derivative, Collateral, Obligation to Return Cash	-78,279
Other Current Liabilities [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral			-6,737
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	-5,413
Other Noncurrent Assets [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral			2,235
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	14,404
Other Current Assets [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	$87,151
[1]	Net amount includes energy commodity derivative contracts classified as current liabilities, net, of $6,737 and noncurrent assets of $2,235.
[2]	This represents the maximum amount of loss we would incur if our counterparties failed to perform on their derivative contracts.
[3]	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.

Derivative_Financial_Instrumen6

Derivative Financial Instruments (Derivatives And Hedging-Cash Flow Hedges) (Details) (USD $)	12 Months Ended						0 Months Ended	1 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Oct. 03, 2013	Nov. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	($30,090)	[1]	($4,744)	[1]	$13,889	[1]
Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax							-200	11,000
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	366
Cash Flow Hedging [Member] | Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax			-4,744		13,889
Derivative Instruments, Loss Reclassified from Accumulated OCI into Income, Effective Portion			-4,245		2,924
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax			0		0
Cash Flow Hedging [Member] | Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	-30,090		-184		10,977
Cash Flow Hedging [Member] | Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Loss Reclassified from Accumulated OCI into Income, Effective Portion	-242		163		164
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	366		0		0
Cash Flow Hedging [Member] | Designated as Hedging Instrument [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax			-4,560		2,912
Cash Flow Hedging [Member] | Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Loss Reclassified from Accumulated OCI into Income, Effective Portion			-4,408		2,760
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax			$0		$0
[1]	See Note 13–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-Overall-Subsequent Measurement) (Details) (USD $)	3 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$115,000
Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	111,600
Operating Expenses [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	17,400
Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	-14,000
Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		145,997	-7,277	-37,811
Not Designated as Hedging Instrument [Member] | Sales [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		145,320	-6,189	-36,959
Not Designated as Hedging Instrument [Member] | Operating Expenses [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		17,818	-3,770	-2,055
Not Designated as Hedging Instrument [Member] | Cost of Sales [Member] | Butane Futures Agreements [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net		($17,141)	$2,682	$1,203

Derivative_Financial_Instrumen8

Derivative Financial Instruments (Derivatives And Hedging-Designated) (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$14,764	$2,235
Derivative Liability, Fair Value, Gross Liability	26,478	146
Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	360	0
Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	0	146
Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	14,404	2,235
Designated as Hedging Instrument [Member] | Commodity Contract [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
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	92,000	430
Derivative Liability, Fair Value, Gross Liability	10,622	7,021
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	92,000	48
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	0	7,021
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	382
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	$10,622	$0

Leases_Narrative_Details

Leases (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating Leases [Line Items]
Total rent expense	$21	$12	$4.80
Minimum [Member]
Operating Leases [Line Items]
Lessor Leasing Arrangements, Operating Leases, Term of Contract	1 year
Maximum [Member]
Operating Leases [Line Items]
Lessor Leasing Arrangements, Operating Leases, Term of Contract	20 years

Leases_Lessee_future_minimum_r

Leases (Lessee, future minimum rental payments) (Details) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Leases [Abstract]
2015	$26.50
2016	23.9
2017	23.3
2018	18.6
2019	8
Thereafter	82.5
Total	$182.80

Leases_Lessor_future_minimum_p

Leases (Lessor, future minimum payments receivable) (Details) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Leases [Abstract]
2015	$249.70
2016	229
2017	158.3
2018	110.4
2019	83.3
Thereafter	266.1
Total	$1,096.80

Leases_Leases_Investment_in_Di

Leases Leases (Investment in Direct Financing Lease) (Details) (USD $)	Dec. 31, 2014	Jan. 31, 2014
In Millions, unless otherwise specified		mi
Direct Financing Lease [Line Items]
Direct Financing Lease, Minimum Pmts to be Received	$37.90
Direct Financing Lease, Unearned Income	7
Direct Financing Lease, Net Investment	30.9
Direct Financing Leases, Future Minimum Payments Receivable, Next Twelve Months	7.4
Direct Financing Leases, Future Minimum Payments, Receivable in Two Years	7.4
Direct Financing Leases, Future Minimum Payments Due in Three Years	4.1
Direct Financing Leases, Future Minimum Payments, Receivable in Four Years	1.7
Direct Financing Leases, Future Minimum Payments Due in Five Years	1.7
Other Current Assets [Member]
Direct Financing Lease [Line Items]
Direct Financing Lease, Net Investment	6.1
Other Noncurrent Assets [Member]
Direct Financing Lease [Line Items]
Direct Financing Lease, Net Investment	$24.80
Texas and New Mexico Pipeline (Leased) [Member]
Direct Financing Lease [Line Items]
Pipeline, Length		40

LongTerm_Incentive_Plan_Narrat

Long-Term Incentive Plan (Narrative) (Details)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Long Term Incentive Plan [Line Items]
Limited partners' capital account, units issued	9.4
Limited partner unitholders, units remaining available	1.3
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Payout Calculation Established Financial Metric		80.00%
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Payout Calculation Established Financial Metric and Personal Performance		20.00%
2013 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Equity Based Compensation, Award Payout Percentage, Maximum	250.00%
Performance-based awards, description of payout calculation		For performance-based awards, we base the payout calculation for 80% of the award solely on the attainment of a financial metric established by the compensation committee. We account for this portion of the award grants as equity. The payout calculation for the remaining 20% of the unit awards is based on both the attainment of a financial metric and the individual employee's personal performance as determined by the compensation committee.
Equity Based Compensation, Award Payout Percentage, Minimum	0.00%
2014 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Equity Based Compensation, Award Payout Percentage, Maximum	200.00%
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Equity Based Compensation, Award Payout Percentage, Minimum	0.00%
Equity Based Compensation Award Payout Fluctuation Of Award Market	50.00%

LongTerm_Incentive_Plan_Change

Long-Term Incentive Plan (Changes In Non-Vested Unit Awards) (Details) (Management [Member], USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Non-vested units - 1/1/2014	561,976
Units granted	221,274
Units vested during 2014	-294,749
Units forfeited during 2014	-50,638
Non-vested units - 12/31/14	437,863
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Roll Forward]
Non-vested units - 1/1/2014	$44.40
Units granted during 2014	$74.32
Units vested during 2014	$41.56
Units forfeited during 2014	$49.24
Non-vested units - 12/31/14	$66.21
Liability Method [Member] | Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Non-vested units - 1/1/2014	97,355
Units granted	0	45,700	53,558
Units vested during 2014	-46,847
Units forfeited during 2014	-9,630
Non-vested units - 12/31/14	40,878	97,355
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Roll Forward]
Non-vested units - 1/1/2014	$63.27
Units granted during 2014	$0	$51.49	$33.57
Units vested during 2014	$82.66
Units forfeited during 2014	$82.66
Non-vested units - 12/31/14	$82.66	$63.27
Equity Method [Member] | Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Non-vested units - 1/1/2014	389,410
Units granted	187,371	182,798	214,232
Units vested during 2014	-187,388
Units forfeited during 2014	-39,076
Non-vested units - 12/31/14	350,317	389,410
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Roll Forward]
Non-vested units - 1/1/2014	$41.90
Units granted during 2014	$72.77	$51.49	$33.57
Units vested during 2014	$33.61
Units forfeited during 2014	$41.88
Non-vested units - 12/31/14	$62.85	$41.90
Equity Method [Member] | Retention Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Non-vested units - 1/1/2014	75,211
Units granted	33,903	22,668	7,016
Units vested during 2014	-60,514
Units forfeited during 2014	-1,932
Non-vested units - 12/31/14	46,668	75,211
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Roll Forward]
Non-vested units - 1/1/2014	$32.87
Units granted during 2014	$82.86	$53.02	$30.54
Units vested during 2014	$34.35
Units forfeited during 2014	$31.66
Non-vested units - 12/31/14	$76.99	$32.87

LongTerm_Incentive_Plan_Total_

Long-Term Incentive Plan (Total Non-Vested Unit Awards) (Details) (Management [Member], USD $)	Dec. 31, 2014
In Millions, except Share data, unless otherwise specified
Long Term Incentive Plan [Line Items]
Unit Awards Granted	462,508
Estimated Forfeitures	43,101
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results	335,025
Total Unit Award Accrual	754,432
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$24.30	[1]
2013 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Unit Awards Granted	228,498
Estimated Forfeitures	31,870
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results	245,786
Total Unit Award Accrual	442,414
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	8.5	[1]
2014 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Unit Awards Granted	187,371
Estimated Forfeitures	8,899
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results	89,239
Total Unit Award Accrual	267,711
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	13	[1]
Retention Awards Vesting 2015 [Member] | Retention Awards [Member]
Long Term Incentive Plan [Line Items]
Unit Awards Granted	444
Estimated Forfeitures	23
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results	0
Total Unit Award Accrual	421
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	0.1	[1]
Retention Awards Vesting 2016 [Member] | Retention Awards [Member]
Long Term Incentive Plan [Line Items]
Unit Awards Granted	20,757
Estimated Forfeitures	1,037
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results	0
Total Unit Award Accrual	19,720
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	0.9	[1]
Retention Awards Vesting 2017 [Member] | Retention Awards [Member]
Long Term Incentive Plan [Line Items]
Unit Awards Granted	25,438
Estimated Forfeitures	1,272
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results	0
Total Unit Award Accrual	24,166
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$1.90	[1]
[1]	Unrecognized compensation expense will be recognized over the remaining vesting period of the awards.

LongTerm_Incentive_Plan_Weight

Long-Term Incentive Plan (Weighted-Average Grant Date Fair Values) (Details) (Management [Member], USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Long Term Incentive Plan [Line Items]
Units granted	221,274
Weighted-Average Grant Date Fair Value	$74.32
Equity Method [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Units granted	187,371	182,798	214,232
Weighted-Average Grant Date Fair Value	$72.77	$51.49	$33.57
Equity Method [Member] | Retention Awards [Member]
Long Term Incentive Plan [Line Items]
Units granted	33,903	22,668	7,016
Weighted-Average Grant Date Fair Value	$82.86	$53.02	$30.54
Liability Method [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Units granted	0	45,700	53,558
Weighted-Average Grant Date Fair Value	$0	$51.49	$33.57

LongTerm_Incentive_Plan_Vested

Long-Term Incentive Plan (Vested Unit Awards) (Details) (Management [Member], USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Management [Member]
Long Term Incentive Plan [Line Items]
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Nonvested Total Unit Award Accrual Number	528,984	572,353	751,237
Fair Value of Unit Awards on Vesting Date (in millions)	$22.40	$20.50	$17.10
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Vested	$43.70	$36.20	$32.50

LongTerm_Incentive_Plan_Cash_F

Long-Term Incentive Plan (Cash Flow Effects Of LTIP Settlements) (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Long Term Incentive Plan [Line Items]
Settlement of tax withholdings on long-term incentive compensation	$14,813,000	$12,259,000	$13,001,000
Management [Member]
Long Term Incentive Plan [Line Items]
Partners' Capital Account, Units, Unit-based Compensation	387,216	476,682	722,766
Settlement of tax withholdings on long-term incentive compensation	14,800,000	12,300,000	13,000,000
Payments for Other Taxes	1,200,000	1,100,000	1,300,000
Total Cash Taxes Paid (in millions)	$16,000,000	$13,400,000	$14,300,000

LongTerm_Incentive_Plan_Equity

Long-Term Incentive Plan (Equity-Based Incentive Compensation Expense) (Details) (Management [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	$27,284	$24,083	$21,036
G&A Expense [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	26,700	23,264	18,587
Operating Expenses [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	584	819	2,449
Retention Awards [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	1,624	575	693
2010 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	0	194	8,660
2011 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	0	9,639	7,156
2012 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	8,314	7,498	4,527
2013 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	10,852	6,177	0
2014 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	6,494	0	0
Liability Method [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	7,321	8,551	6,918
Liability Method [Member] | 2010 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	0	73	3,723
Liability Method [Member] | 2011 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	0	4,280	2,094
Liability Method [Member] | 2012 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	3,896	2,747	1,101
Liability Method [Member] | 2013 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	3,425	1,451	0
Liability Method [Member] | 2014 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	0	0	0
Equity Method [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	19,963	15,532	14,118
Equity Method [Member] | Retention Awards [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	1,624	575	693
Equity Method [Member] | 2010 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	0	121	4,937
Equity Method [Member] | 2011 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	0	5,359	5,062
Equity Method [Member] | 2012 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	4,418	4,751	3,426
Equity Method [Member] | 2013 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	7,427	4,726	0
Equity Method [Member] | 2014 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	$6,494	$0	$0

Segment_Disclosures_Segment_Re

Segment Disclosures (Segment Reporting Information By Segment) (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Segment Reporting Information [Line Items]
Transportation and terminals revenue									$1,402,638	$1,138,328	$970,744
Product sales revenue									878,974	744,669	799,382
Affiliate management fee revenue									22,111	14,609	1,948
Total revenue	667,070	521,601	496,446	618,606	577,438	443,835	443,912	432,421	2,303,723	1,897,606	1,772,074
Operating expenses									444,272	346,070	328,454
Cost of product sales									594,585	578,029	657,108
Earnings of non-controlled entities									-19,394	-6,275	-2,961
Operating margin	373,033	299,268	264,424	347,535	296,335	222,649	251,905	208,893	1,284,260	979,782	789,473
Depreciation and amortization expense									161,741	142,230	128,012
G&A expenses									148,288	132,496	109,403
Operating profit									974,231	705,056	552,058
Total assets	5,517,285				4,820,812				5,517,285	4,820,812	4,420,067
Goodwill	53,260				53,260				53,260	53,260	53,260
Investments in non-controlled entities	613,867				360,852				613,867	360,852	107,356
Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Goodwill	38,400								38,400
Crude Oil Pipeline and Terminals Segment [Member]
Segment Reporting Information [Line Items]
Goodwill	12,100								12,100
Marine Storage Segment [Member]
Segment Reporting Information [Line Items]
Goodwill	2,800								2,800
Operating Segments [Member]
Segment Reporting Information [Line Items]
Additions to long-lived assets									622,012	593,059	351,189
Total assets	5,460,554				4,711,495				5,460,554	4,711,495	4,062,630
Operating Segments [Member] | Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue									921,762	801,128	723,835
Product sales revenue									872,537	738,271	790,116
Affiliate management fee revenue									0	0	0
Total revenue									1,794,299	1,539,399	1,513,951
Operating expenses									331,207	270,711	267,694
Cost of product sales									592,887	574,703	653,429
Earnings of non-controlled entities									0	0	0
Operating margin									870,205	693,985	592,828
Depreciation and amortization expense									101,642	86,926	86,218
G&A expenses									96,411	91,658	87,309
Operating profit									672,152	515,401	419,301
Additions to long-lived assets									163,753	361,134	127,744
Total assets	2,875,412				2,811,398				2,875,412	2,811,398	2,530,770
Goodwill	38,369				38,369				38,369	38,369	38,369
Investments in non-controlled entities	0				0				0	0	0
Operating Segments [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue									310,136	178,409	92,288
Product sales revenue									0	0	0
Affiliate management fee revenue									20,790	13,361	1,734
Total revenue									330,926	191,770	94,022
Operating expenses									51,405	19,131	5,229
Cost of product sales									0	0	0
Earnings of non-controlled entities									-16,309	-3,781	-2,574
Operating margin									295,830	176,420	91,367
Depreciation and amortization expense									27,800	24,119	12,228
G&A expenses									29,557	19,896	5,420
Operating profit									238,473	132,405	73,719
Additions to long-lived assets									439,846	199,362	166,960
Total assets	1,937,242				1,252,036				1,937,242	1,252,036	875,005
Goodwill	12,082				12,082				12,082	12,082	12,082
Investments in non-controlled entities	599,757				345,904				599,757	345,904	91,629
Operating Segments [Member] | Marine Storage Segment [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue									170,740	158,791	154,621
Product sales revenue									6,437	6,398	9,266
Affiliate management fee revenue									1,321	1,248	214
Total revenue									178,498	166,437	164,101
Operating expenses									65,173	59,407	58,486
Cost of product sales									1,698	3,326	3,679
Earnings of non-controlled entities									-3,085	-2,494	-387
Operating margin									114,712	106,198	102,323
Depreciation and amortization expense									28,786	28,006	26,611
G&A expenses									22,320	20,942	16,674
Operating profit									63,606	57,250	59,038
Additions to long-lived assets									18,413	32,563	56,485
Total assets	647,900				648,061				647,900	648,061	656,855
Goodwill	2,809				2,809				2,809	2,809	2,809
Investments in non-controlled entities	14,110				14,948				14,110	14,948	15,727
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Total assets	56,731				109,317				56,731	109,317	357,437
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue									0	0	0
Product sales revenue									0	0	0
Affiliate management fee revenue									0	0	0
Total revenue									0	0	0
Operating expenses									-3,513	-3,179	-2,955
Cost of product sales									0	0	0
Earnings of non-controlled entities									0	0	0
Operating margin									3,513	3,179	2,955
Depreciation and amortization expense									3,513	3,179	2,955
G&A expenses									0	0	0
Operating profit									$0	$0	$0

Commitments_and_Contingencies_1

Commitments and Contingencies Commitments and Contingencies (Details) (Narrative) (USD $)	12 Months Ended			3 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jun. 30, 2013
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies	$36.30	$38.50
Estimated Environmental Liabilities Over A Period	10 years
Environmental Remediation Expense	5	-5.2	12
Recorded Third-Party Environmental Recoveries Receivable	5.1	4.8
Recorded Third-Party Environmental Recoveries, Amount	0.5	4.2	1.2
Texas Commission On Environmental Quality Fees [Member]
Loss Contingencies [Line Items]
Loss Contingency, Loss in Period		-10.6		-10.6
Accounts Receivable [Member]
Loss Contingencies [Line Items]
Recorded Third-Party Environmental Recoveries Receivable	1.3	2.1
Other Noncurrent Assets [Member]
Loss Contingencies [Line Items]
Recorded Third-Party Environmental Recoveries Receivable	$3.80	$2.70

Quarterly_Financial_Data_Detai

Quarterly Financial Data (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Quarterly Financial Data [Line Items]
Total revenues	$667,070,000	$521,601,000	$496,446,000	$618,606,000	$577,438,000	$443,835,000	$443,912,000	$432,421,000	$2,303,723,000	$1,897,606,000	$1,772,074,000
Total costs and expenses	387,311,000	297,409,000	320,183,000	343,983,000	355,081,000	291,586,000	260,191,000	291,967,000	1,348,886,000	1,198,825,000	1,222,977,000
Operating margin (loss)	373,033,000	299,268,000	264,424,000	347,535,000	296,335,000	222,649,000	251,905,000	208,893,000	1,284,260,000	979,782,000	789,473,000
Net income	252,085,000	198,620,000	146,260,000	242,554,000	190,007,000	125,623,000	153,640,000	112,967,000	839,519,000	582,237,000	435,670,000
Basic net income per limited partner unit (in dollars per unit)	$1.11	$0.87	$0.64	$1.07	$0.84	$0.55	$0.68	$0.50	$3.69	$2.57	$1.92
Diluted net income per limited partner unit (in dollars per unit)	$1.10	$0.87	$0.64	$1.07	$0.83	$0.55	$0.68	$0.50	$3.69	$2.56	$1.92
Lower-of-cost-or-market inventory adjustment	39,300,000								39,300,000
Derivative, Gain (Loss) on Derivative, Net	115,000,000
Texas Commission On Environmental Quality Fees [Member]
Quarterly Financial Data [Line Items]
Loss Contingency, Loss in Period							-10,600,000			-10,600,000
Sales [Member]
Quarterly Financial Data [Line Items]
Derivative, Gain (Loss) on Derivative, Net	111,600,000
Cost of Sales [Member]
Quarterly Financial Data [Line Items]
Derivative, Gain (Loss) on Derivative, Net	-14,000,000
Operating Expense [Member]
Quarterly Financial Data [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$17,400,000

Fair_Value_Disclosures_Details

Fair Value Disclosures (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Reported Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term receivables	$28,611	$2,730
Debt	-2,982,895	-2,685,287
Reported Value Measurement [Member] | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	96,142
Derivative Liability		-4,502
Reported Value Measurement [Member] | Interest Rate Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	-26,478
Estimate of Fair Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term receivables	30,200	2,658
Debt	-3,212,462	-2,815,210
Estimate of Fair Value Measurement [Member] | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	96,142
Derivative Liability		-4,502
Estimate of Fair Value Measurement [Member] | Interest Rate Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	-26,478
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term receivables	0	0
Debt	0	0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term receivables	0	0
Debt	-3,212,462	-2,815,210
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term receivables	30,200	2,658
Debt	0	0
Fair Value, Measurements, Recurring [Member] | Commodity Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	96,142
Derivative Liability		-4,502
Fair Value, Measurements, Recurring [Member] | Commodity Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	0
Derivative Liability		0
Fair Value, Measurements, Recurring [Member] | Commodity Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	0
Derivative Liability		0
Fair Value, Measurements, Recurring [Member] | Interest Rate Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	0
Fair Value, Measurements, Recurring [Member] | Interest Rate Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	-26,478
Fair Value, Measurements, Recurring [Member] | Interest Rate Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	$0

Distributions_Distributions_De

Distributions (Distributions) (Details) (USD $)	0 Months Ended												12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Nov. 14, 2014	Aug. 14, 2014	15-May-14	Feb. 14, 2014	Nov. 14, 2013	Aug. 14, 2013	15-May-13	Feb. 14, 2013	Nov. 14, 2012	Aug. 14, 2012	15-May-12	Feb. 14, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Aug. 14, 2014
Distributions Made to Limited Liability Company (LLC) Member [Line Items]
Per unit cash distribution amount (in dollars per unit)	$0.67		$0.61	$0.59	$0.56	$0.53	$0.51	$0.50	$0.49	$0.47	$0.42	$0.41	$2.50	$2.10	$1.78	$0.64
Limited partner units	$151,568	$145,324	$139,079	$132,835	$126,374	$120,707	$115,040	$113,340	$109,707	$106,597	$95,004	$92,177	$568,806	$475,461	$403,485

Partners_Capital_Changes_In_Li

Partners' Capital (Changes In Limited Partner Units Outstanding) (Details)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Limited Partners' Capital Account [Roll Forward]
Limited partner unitholders, units outstanding	226,679,438						225,473,142
Limited partner unitholders, units outstanding	227,068,257				226,200,872		225,473,142
Limited Partners' Capital Account, Right to Receive Distribution in Cash, Period	45 days
Limited Partners' Capital Account, Removal of Magellan GP, LLC, Percentage Vote	100.00%
Limited Partners' Capital Account, Annual Report Available, Period	120 days
Limited Partners' Capital Account, Tax Reporting Information, Period	90 days
Management [Member]
Limited Partners' Capital Account [Roll Forward]
Partners' Capital Account, Units, Unit-based Compensation	387,216		476,682		722,766
Director [Member]
Limited Partners' Capital Account [Roll Forward]
Partners' Capital Account, Units, Unit-based Compensation	1,603	[1]	1,884	[1]	4,964	[1]
[1]	Limited partner units issued to settle the equity-based retainer paid to independent directors of our general partner.

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	0 Months Ended												12 Months Ended						0 Months Ended
In Thousands, except Share data, unless otherwise specified	Nov. 14, 2014	Aug. 14, 2014	15-May-14	Feb. 14, 2014	Nov. 14, 2013	Aug. 14, 2013	15-May-13	Feb. 14, 2013	Nov. 14, 2012	Aug. 14, 2012	15-May-12	Feb. 14, 2012	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Feb. 13, 2015	Feb. 06, 2015	Jan. 30, 2015
Subsequent Event [Line Items]
Cash distribution per limited partner unit	$0.67	$0.64	$0.61	$0.59	$0.56	$0.53	$0.51	$0.50	$0.49	$0.47	$0.42	$0.41	$2.50		$2.10		$1.78
Total cash distributions	$151,568	$145,324	$139,079	$132,835	$126,374	$120,707	$115,040	$113,340	$109,707	$106,597	$95,004	$92,177	$568,806		$475,461		$403,485
Subsequent Event [Member]
Subsequent Event [Line Items]
Units granted																				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
Cash distribution per limited partner unit																			$0.70
Total cash distributions																			$158,100
Management [Member]
Subsequent Event [Line Items]
Units granted													221,274
Partners' Capital Account, Units, Unit-based Compensation													387,216		476,682		722,766
Management [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Partners' Capital Account, Units, Unit-based Compensation																					354,529
Director [Member]
Subsequent Event [Line Items]
Partners' Capital Account, Units, Unit-based Compensation													1,603	[1]	1,884	[1]	4,964	[1]
Director [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Partners' Capital Account, Units, Unit-based Compensation																					3,543
Refined Products Segment [Member] | Unionized Employees Concentration Risk [Member]
Subsequent Event [Line Items]
Concentration Risk, Percentage													26.00%
[1]	Limited partner units issued to settle the equity-based retainer paid to independent directors of our general partner.