Magellan Midstream Partners (MMP) 10-K 24 Feb 14 2013 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Feb. 21, 2014	Jun. 28, 2013
Document And Entity Information [Abstract]	'	'	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Entity Registrant Name	'MAGELLAN MIDSTREAM PARTNERS LP	'	'
Entity Central Index Key	'0001126975	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Entity Common Stock, Shares Outstanding	'	227,068,257	'
Entity Public Float	'	'	$12,320,730,416
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, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement [Abstract]	'	'	'
Transportation and terminals revenue	$1,138,328	$970,744	$893,369
Product sales revenue	744,669	799,382	854,528
Affiliate management fee revenue	14,609	1,948	770
Total revenue	1,897,606	1,772,074	1,748,667
Costs and expenses:	'	'	'
Operating	346,070	328,454	306,415
Cost of product sales	578,029	657,108	706,270
Depreciation and amortization	142,230	128,012	121,179
General and administrative	132,496	109,403	98,669
Total costs and expenses	1,198,825	1,222,977	1,232,533
Earnings of non-controlled entities	6,275	2,961	6,763
Operating profit	705,056	552,058	522,897
Interest expense	130,463	117,981	108,869
Interest income	-342	-107	-61
Interest capitalized	-14,339	-6,195	-3,174
Debt placement fee amortization	2,424	2,087	1,831
Income before provision for income taxes	586,850	438,292	415,432
Provision for income taxes	4,613	2,622	1,866
Net income	582,237	435,670	413,566
Allocation of net income (loss):	'	'	'
Limited partners' interest	582,237	435,670	413,629
Non-controlling owners' interest	$0	$0	($63)
Basic net income per limited partner unit (in dollars per unit)	$2.57	$1.92	$1.83
Diluted net income per limited partner unit (in dollars per unit)	$2.56	$1.92	$1.83
Weighted average number of limited partner units outstanding used for basic net income per unit calculation (in units)	226,829	226,369	225,674
Weighted average number of limited partner units outstanding used for diluted net income per unit calculation (in units)	227,094	226,608	225,974

Consolidated_Statements_Of_Com

Consolidated Statements Of Comprehensive Income (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Net income	$582,237		$435,670		$413,566
Other comprehensive income:	'		'		'
Net gain (loss) on cash flow hedges(1)	-4,744	[1],[2]	13,889	[1],[2]	7,739	[1],[2]
Reclassification of net loss (gain) on cash flow hedges to income(1)	4,245	[1],[2]	-2,924	[1],[2]	-7,903	[1],[2]
Net actuarial (loss) gain(2)	14,089	[1],[3]	-17,804	[1],[3]	-37,058	[1],[3]
Plan amendment(2)	0	[3]	16,020	[1],[3]	0	[3]
Amortization of actuarial loss(2)	5,369	[1],[3]	4,626	[1],[3]	1,591	[1],[3]
Amortization of prior service credit(2)	-3,405	[1],[3]	-1,664	[1],[3]	-544	[1],[3]
Settlement cost(2)	0	[3]	0	[3]	70	[1],[3]
Total other comprehensive income (loss)	15,554		12,143		-36,105
Comprehensive income	597,791		447,813		377,461
Comprehensive loss attributable to non-controlling owners’ interest in consolidated subsidiaries	0		0		-63
Comprehensive income attributable to partners’ capital	$597,791		$447,813		$377,524
[1]	Includes amounts allocated to the non-controlling owners' interest.
[2]	(1) See Note 13–Derivative Financial Instruments for details of the amount of gain/loss recognized in AOCL on derivatives and the amount of gain/loss reclassified from AOCL into income.
[3]	(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, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets:	'		'
Cash and cash equivalents	$25,235		$328,278
Trade accounts receivable (less allowance for doubtful accounts of $5 and $0 at December 31, 2012 and 2013)	116,295		91,114
Other accounts receivable	6,462		12,329
Inventory	187,224		221,888
Energy commodity derivatives deposits	14,782		18,304
Other current assets	46,735		28,365
Total current assets	396,733		700,278
Property, plant and equipment	4,986,750		4,408,550
Less: accumulated depreciation	1,070,492		943,248
Net property, plant and equipment	3,916,258		3,465,302
Investment in non-controlled entities	360,852		107,356
Long-term receivables	2,730		5,135
Goodwill	53,260		53,260
Other intangibles (less accumulated amortization of $16,715 and $8,809 at December 31, 2012 and 2013, respectively)	7,290		13,274
Debt placement costs (less accumulated amortization of $7,886 and $9,113 at December 31, 2012 and 2013, respectively)	17,505		15,080
Tank bottom inventory	61,915		58,493
Other noncurrent assets	4,269		1,889
Total assets	4,820,812		4,420,067
Current liabilities:	'		'
Accounts payable	76,326		112,002
Accrued payroll and benefits	42,243		32,434
Accrued interest payable	44,935		42,059
Accrued taxes other than income	38,574		33,089
Environmental liabilities	12,147		14,442
Deferred revenue	63,164		46,371
Accrued product purchases	63,033		72,049
Energy commodity derivatives contracts, net	6,737		7,338
Current portion of long-term debt	249,971		0
Other current liabilities	41,146		32,836
Total current liabilities	638,276		392,620
Long-term debt	2,435,316		2,393,408
Long-term pension and benefits	51,637		68,134
Other noncurrent liabilities	21,802		16,382
Environmental liabilities	26,339		33,821
Commitments and contingencies	'		'
Partners' capital:	'		'
Limited partner unitholders (226,201 units and 226,679 units outstanding at December 31, 2012 and 2013, respectively)	1,666,946		1,550,760
Accumulated other comprehensive loss	-19,504	[1]	-35,058	[1]
Total partners’ capital	1,647,442		1,515,702
Total liabilities and partners' capital	$4,820,812		$4,420,067
[1]	Includes amounts allocated to the non-controlling owners' interest.

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, except Share data, unless otherwise specified
Statement of Financial Position [Abstract]	'	'
Accounts receivable, allowance for doubtful accounts	$0	$5
Other intangibles, accumulated amortization	8,809	16,715
Debt placement costs, accumulated amortization	$9,113	$7,886
Limited partner unitholders, units outstanding	226,679,438	226,200,872

Consolidated_Statments_of_Cash

Consolidated Statments of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Activities:	'	'	'
Net income	$582,237	$435,670	$413,566
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Depreciation and amortization expense	142,230	128,012	121,179
Debt placement fee amortization	2,424	2,087	1,831
Loss on sale and retirement of assets	7,835	12,625	8,599
Earnings of non-controlled entities	-6,275	-2,961	-6,763
Distributions from investments in non-controlled entities	2,494	2,961	5,598
Equity-based incentive compensation expense	24,083	21,036	17,710
Changes in employee benefit plan assets and benefit obligations	1,964	2,962	1,117
Changes in components of operating assets and liabilities (Note 3)	15,708	42,699	14,486
Net cash provided by operating activities	772,700	645,091	577,323
Property, plant and equipment:	'	'	'
Additions to property, plant and equipment	-383,757	-354,168	-199,665
Proceeds from sale and disposition of assets	3,610	1,056	6,299
Increase (decrease) in accounts payable related to capital expenditures	-37,678	55,133	2,126
Acquisition of business	-192,000	0	0
Acquisition of assets	-22,506	0	-17,807
Acquisition of non-controlling owners' interests	0	0	-40,500
Investment in non-controlled entities	-250,495	-74,934	-8,094
Distributions in excess of earnings of non-controlled entities	780	4,832	0
Other	0	0	-1,100
Net cash used by investing activities	-882,046	-368,081	-258,741
Financing Activities:	'	'	'
Distributions paid	-475,461	-403,485	-350,892
Net repayments under revolver	0	0	-15,000
Borrowings under long-term notes	298,680	248,345	260,914
Debt placement costs	-4,849	-2,552	-4,575
Net receipt from (payment on) interest rate derivatives	-184	10,977	5,926
Increase (decrease) in outstanding checks	376	1,364	-5,408
Settlement of tax withholdings on long-term incentive compensation	-12,259	-13,001	-7,410
Net cash used by financing activities	-193,697	-158,352	-116,445
Change in cash and cash equivalents	-303,043	118,658	202,137
Cash and cash equivalents at beginning of period	328,278	209,620	7,483
Cash and cash equivalents at end of period	25,235	328,278	209,620
Issuance of MMP limited partner units in settlement of long-term incentive plan awards	$6,404	$7,295	$4,315

Consolidated_Statement_Of_Owne

Consolidated Statement Of Owners' Equity (USD $)	Total	Limited Partner [Member]	Accumulated Other Comprehensive Loss [Member]	Non-Controlling Owners' Interest [Member]
In Thousands, unless otherwise specified
Balance at Dec. 31, 2010	$1,469,571	$1,466,404	($11,096)	$14,263
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'
Net income	413,566	413,629	'	-63
Total other comprehensive income (loss)	-36,105	'	-36,105	0
Comprehensive income:	'	'	'	'
Comprehensive income	377,461	413,629	-36,105	-63
Distributions	-350,892	-350,892	'	'
Equity method incentive compensation expense	11,043	11,043	'	'
Issuance of MMP limited partner units in settlement of long-term incentive plan awards	4,315	4,315	'	'
Settlement of tax withholdings on long-term incentive compensation	-7,410	-7,410	'	'
Acquisition of non-controlling owners' interest	-40,500	-26,300	'	-14,200
Other	-185	-185	'	'
Balance at Dec. 31, 2011	1,463,403	1,510,604	-47,201	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'
Net income	435,670	435,670	'	'
Total other comprehensive income (loss)	12,143	'	12,143	'
Comprehensive income:	'	'	'	'
Comprehensive income	447,813	435,670	12,143	'
Distributions	-403,485	-403,485	'	'
Equity method incentive compensation expense	14,118	14,118	'	'
Issuance of MMP limited partner units in settlement of long-term incentive plan awards	7,295	7,295	'	'
Settlement of tax withholdings on long-term incentive compensation	-13,001	-13,001	'	'
Other	-441	-441	'	'
Balance at Dec. 31, 2012	1,515,702	1,550,760	-35,058	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'
Net income	582,237	582,237	'	'
Total other comprehensive income (loss)	15,554	'	15,554	'
Comprehensive income:	'	'	'	'
Comprehensive income	597,791	582,237	15,554	'
Distributions	-475,461	-475,461	'	'
Equity method incentive compensation expense	15,532	15,532	'	'
Issuance of MMP limited partner units in settlement of long-term incentive plan awards	6,404	6,404	'	'
Settlement of tax withholdings on long-term incentive compensation	-12,259	-12,259	'	'
Other	-267	-267	'	'
Balance at Dec. 31, 2013	$1,647,442	$1,666,946	($19,504)	$0

Organization_And_Description_O

Organization And Description Of Business	12 Months Ended
	Dec. 31, 2013
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, our independent terminals, our ammonia pipeline as well as our blending and fractionation activities, each of which is briefly described below:
	•	Our refined products pipeline consists of approximately 9,500 miles of pipeline and 53 terminals that provide transportation, storage and distribution services. Our refined products pipeline covers a 15-state area from the Gulf Coast across the central U.S. The products transported on our pipeline are primarily gasoline, distillates, aviation fuels and liquefied petroleum gases. Product originates on our pipeline 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 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 two 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 is comprised of approximately 1,100 miles of crude oil pipelines and storage facilities with an aggregate storage capacity of approximately 18 million barrels, of which 12 million is used for leased storage. A brief description of these operations is as follows:
	•	Our Longhorn crude oil pipeline consists of approximately 450 miles of pipeline which originates from 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 other pipeline systems;
	•	Our terminal in Cushing, Oklahoma, one of the largest crude oil trading hubs in the U.S., consists of approximately 10 million barrels used for leased storage. This terminal principally serves refiners, marketers and traders. We earn revenue primarily from leasing tanks as well as from throughput fees;
	•	Our terminal at East Houston, Texas includes approximately one million barrels of crude oil storage used for leased storage and our terminal at Corpus Christi, Texas includes approximately one million barrels of condensate storage used for leased storage; and
	•	We own approximately 300 miles of pipeline in Kansas and Oklahoma currently used for crude oil service. A majority of these pipelines are leased to third parties, and we earn revenue from these pipeline segments for capacity reserved even if not used by the customers.
	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 is constructing 450 miles of pipeline and related infrastructure that is being constructed to transport crude oil from Colorado City, Texas for delivery to the Houston and Texas City, Texas refineries. This pipeline is expected to begin service in mid-2014.
	Marine Storage. Our marine storage segment is comprised of storage terminals, which 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 that 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 of wholly-owned storage. Because the rates charged at these terminals are unregulated, the marketplace determines the prices we can charge for our services. 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"), that owns approximately one million barrels of storage located at our terminal in Galena Park, Texas, which is included in our aggregate storage capacity.

Summary_Of_Significant_Account

Summary Of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
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 ownership interests, except four 50%-owned investments that we do not control and which we have determined are not variable interest entities. Accordingly, we apply the equity method of accounting for the following entities: (i) Osage; (ii) Texas Frontera; (iii) Double Eagle; and (iv) BridgeTex. 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 highly marketable securities or 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, 2012 and 2013, we believed our credit risk relative to these funds was minimal.
	Accounts Receivable and Allowance for Doubtful Accounts. Accounts receivable represent valid claims against non-affiliated customers. We recognize accounts receivable when we sell products or render services, except tariff-related transportation services of our refined products pipeline, which we recognize when our customers' product enters our system, 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, crude oil and additives, which are stated and relieved at the lower of average cost or market.
	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 depreciate most of our assets individually on a straight-line basis over their useful lives; however, we group the individual components of certain assets, such as some of our older tanks, together into a composite asset, and we depreciate those assets using a composite rate. 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 associated with existing assets when they improve the productivity or increase the useful life 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.
	Asset Retirement Obligation.  We record the fair value of a liability related to the retirement of long-lived assets at the time we incur a legal obligation if the liability can be reasonably estimated.  When we initially record the liability, we increase the carrying amount of the related asset by the amount of the liability. Over time, we accrete the liability to its future value and record the accretion amount to operating expense.
	Our operating assets generally consist of underground pipelines and related components along rights-of-way and above ground storage tanks and related facilities.  Our right-of-way agreements typically do not require the dismantling, removal and reclamation of the right-of-way upon permanent cessation of pipeline service.  Additionally, management is unable to predict when, or if, our pipelines, storage tanks and related facilities would become completely obsolete and require decommissioning.  Accordingly, except for a $4.2 million liability associated with anticipated tank liner and seal replacements, we have recorded no other liability or corresponding asset as an asset retirement obligation as both the amounts and timing of such potential future costs are indeterminable.
	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, plus equity in earnings or losses since acquisition or formation, plus interest capitalized, less distributions received and amortization of excess net investment. Excess net investment is the amount by which our initial investment exceeded our proportionate share of the book value of the net assets of the investment. We amortize excess net investment over the weighted-average depreciable asset lives of the equity investee. Our unamortized excess net investment was $15.8 million and $15.1 million at December 31, 2012 and 2013, respectively. We evaluate equity method investments for impairment annually or 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 2011, 2012 or 2013.
	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 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, 2012 and 2013. Our reported goodwill at December 31, 2013 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.
	We base our determination of whether goodwill is impaired on management's estimate of the fair value of our reporting units using a discounted future cash flow (“DFCF”) model as compared to their carrying values. Critical assumptions used in our DFCF model included: (i) time horizon of 20 years, (ii) operating margin growth of 2.5%, (iii) annual maintenance capital spending growth of 2.5% and (iv) 11.0 times earnings before interest, taxes and depreciation and amortization ("EBITDA") multiple for terminal value. Management believes an 11.0 times EBITDA multiple is conservative and reasonable for determining terminal value because market participants in the energy industry community use EBITDA multiples ranging from 11.0 to 14.0, and higher, to determine fair value for assets being acquired or sold. We use October 1 as our impairment measurement test date and have determined that our goodwill was not impaired as of October 1, 2011, 2012 or 2013. If impairment were to occur, we would charge the amount of the impairment against earnings in the period in which the impairment occurred. The amount of the impairment would be determined by subtracting the implied fair value of the reporting unit goodwill from the carrying amount of the goodwill.
	Judgments and assumptions are inherent in management's estimates used to determine the fair value of our operating segments and are consistent with what management believes would be utilized by the primary market participant. The use of alternate judgments and assumptions could result in the recognition of different levels of impairment charges in our financial statements.
	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, 2013 was approximately 7 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 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 2011, 2012 and 2013. Amortization of other intangible assets was $2.8 million, $1.9 million and $6.0 million in 2011, 2012 and 2013, respectively, of which $0.6 million, $0.6 million and $0.2 million was charged against transportation and terminals revenue in each year during 2011, 2012 and 2013, respectively. During 2013, we retired fully amortized intangible assets of $13.9 million.
	Tank Bottom Inventory. 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 as described below. At December 31, 2013, our tank bottom inventory consisted of 0.7 million barrels of crude oil with a carrying value of $61.9 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 bottom inventory. The cumulative losses of these derivative agreements as of December 31, 2012 and 2013 were $5.5 million and $8.9 million, respectively, which were recorded as increases to the tank bottom inventory.
	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 2011, 2012 and 2013 were not material.
	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, based on the weighted-average interest rate of our debt.
	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, rates of increase in health care costs, 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 have recorded or may record.
	Paid-Time Off Benefits. We recognize liabilities for paid-time off benefits when earned. Paid-time off liabilities were $12.8 million and $14.3 million at December 31, 2012 and 2013, respectively. These balances represented the remaining vested paid-time off benefits of employees. We reflect liabilities for paid-time off in the accrued payroll and benefits balances of the accompanying consolidated balance sheets.
	Derivative Financial Instruments. We record derivative instruments on our balance sheets at fair value as either assets or liabilities. We account for derivatives that qualify for and are elected for treatment as normal purchases and sales using traditional accrual accounting.
	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 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 either do not qualify for hedge accounting or 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. 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 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 or liabilities being hedged and the ineffective portions 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 or forecasted butane purchases. We record the change in fair value of those agreements in operating expenses and cost of product sales, respectively.
	We use interest rate derivatives to help manage interest rate risk. We record any ineffectiveness on derivatives designated as hedging instruments 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 when shipments are complete. 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, shipments are complete when 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, shipments are complete when the product arrives at the customer-designated delivery point. We recognize injection service fees associated with customer proprietary 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. We increase or decrease, as appropriate, product sales for gains and losses associated with the period change in fair value of our NYMEX agreements that we do not designate as hedges, except for those undesignated agreements that economically hedge the inventories associated with our pipeline system overages (which are recorded as adjustments to operating expense), and for the ineffective portion of our NYMEX agreements that we designate as cash flow hedges. When the physical sale of hedged refined products occurs, we increase or decrease, as appropriate, product sales for the effective portion of the gains and losses of the associated derivative agreement. 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. 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 production 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 shippers' inventories (as adjusted for tender deductions).  To the extent that the product volumes in our pipeline system exceeds the volumes of our shippers' book inventories, we increase our product inventories and recognize a gain and to the extent the product in our pipeline system is less than our shippers' book inventories, we record a liability (for product owed to our shippers) 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 Awards. 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 contain 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 equity awards is the closing price of our limited partner units on the grant date. 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 from 0% up to 250% of the amount of the award. Additionally, certain of these awards are also subject to personal and other performance components, which could increase or decrease the payout of the number of limited partner units by as much as 20%. 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 participant. Retention awards contain no provisions which would provide for a payout to the participant of anything other than the original number of units awarded and the associated distribution equivalents.
	The vesting period of the performance-based awards is three years. The vesting period for retention awards generally does not exceed three years; however, certain retention awards with a four-year vesting period have been granted. We settle vested non-director award grants by issuing new units, except for the associated 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. Environmental expenditures are charged to operating expense or capitalized based on the nature of the expenditures. We expense expenditures that relate to an existing condition caused by past operations that do not contribute to current or future revenue generation. 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. 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.
	The amounts recognized as provision for income taxes in our results of operations reflects 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 the limited partners' allocation of 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 our derivative hedging transactions, related amortization of realized gains/losses and adjustments to record 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(3)
	Balance, January 1, 2011	$	3,325		$	(14,421	)	$	(11,096	)
	Derivative activity:
	Net gain on cash flow hedges(1)	7,739			—			7,739
	Reclassification of net gain on cash flow hedges to income(1)	(7,903		)	—			(7,903		)
	Changes in employee benefit plan assets and benefit obligations recognized in other comprehensive income:
	Net actuarial loss(2)	—			(37,058		)	(37,058		)
	Amortization of actuarial loss(2)	—			1,591			1,591
	Amortization of prior service credit(2)	—			(544		)	(544		)
	Settlement cost(2)	—			70			70
Balance, December 31, 2011	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 actuarial loss(2)	—			4,626			4,626
Amortization of prior service credit(2)	—			(1,664		)	(1,664		)
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 actuarial loss(2)	—			5,369			5,369
Amortization of prior service credit(2)	—			(3,405		)	(3,405		)
Balance, December 31, 2013	$	13,627		$	(33,131	)	$	(19,504	)
(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).
(3) Includes amounts allocated to the non-controlling owners' interest.
New Accounting Pronouncements
In February 2013, the Financial Accounting Standards Board ("FASB") issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. The amendments in ASU 2013-02 do not change the current requirements for reporting net income or other comprehensive income in financial statements. However, the amendments require an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to present, either on the face of the statement where net income is presented or in the notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under U.S. GAAP to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures required under U.S. GAAP that provide additional detail about those amounts. ASU 2013-02 became effective for annual and interim periods beginning after December 15, 2012 and was to be applied prospectively. Our adoption of this standard in the first quarter of 2013 did not have a material impact on our results of operations, financial position or cash flows.
In December 2011, the FASB issued ASU 2011-11, Disclosures about Offsetting Assets and Liabilities. This ASU requires entities that have financial instruments and derivatives that are either: (i) offset in accordance with ASC Topic 210 or Topic 815 or (ii) are subject to an enforceable master netting arrangement or similar agreement to make additional disclosures of the gross and net amounts of those assets and liabilities, the amounts offset in accordance with ASC Topics 210 and 815, as well as qualitative disclosures of the entity's master netting arrangement or similar agreement. In January 2013, the FASB issued ASU 2013-01, Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities. The amendments in ASU 2013-01 clarify that the scope of ASU 2011-11 applies to derivatives accounted for in accordance with ASC Topic 815, Derivatives and Hedging. ASU 2011-11 must be applied retrospectively and became effective for fiscal years beginning on or after January 1, 2013. We adopted these standards in the first quarter of 2013 and their adoption 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, 2013
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,
		2011			2012			2013
	Restricted cash	$	14,379		$	—		$	—
	Trade accounts receivable and other accounts receivable	5,791			(10,867		)	(19,314		)
	Inventory	(42,452		)	36,972			34,664
	Energy commodity derivatives contracts, net of derivatives deposits	(19,782		)	16,097			534
	Accounts payable	20,226			(11,175		)	2,002
	Accrued payroll and benefits	(2,209		)	2,250			9,809
	Accrued interest payable	4,069			1,512			2,876
	Accrued taxes other than income	617			5,519			5,485
	Accrued product purchases	12,476			12,249			(9,016		)
	Deferred revenue	5,250			6,388			16,793
	Current and noncurrent environmental liabilities	16,861			(1,372		)	(12,247		)
	Other current and noncurrent assets and liabilities	(740		)	(14,874		)	(15,878		)
	Total	$	14,486		$	42,699		$	15,708
	At December 31, 2011, 2012 and 2013, the long-term pension and benefits liability was increased (decreased) by $37.1 million, $1.8 million and $(14.1) million, respectively, resulting in a corresponding increase (decrease) in accumulated other comprehensive loss. These non-cash amounts were reflected in the consolidated financial statements but were not reflected in the statements of cash flows.

Investments_in_NonControlled_E

Investments in Non-Controlled Entities Investments in Non-Controlled Entities (Notes)	12 Months Ended
	Dec. 31, 2013
Equity Method Investments and Joint Ventures [Abstract]	'
Investments in Non-Controlled Entities [Text Block]	'
	Investments in Non-Controlled Entities
	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 lease agreement. Texas Frontera began operations in October 2012. We receive management fees from Texas Frontera, which we report as affiliate management fee revenue on our consolidated statements of income.
	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 is operated by an affiliate of the other 50% member of Double Eagle. We receive connection fees from Double Eagle that are included in our transportation and terminals revenue on our consolidated statements of income. For the year ended December 31, 2013, we received connection fees of $1.4 million and recognized a $0.2 million trade accounts receivable from Double Eagle at December 31, 2013.
	BridgeTex. We own a 50% interest in BridgeTex, which is in the process of constructing a 450-mile pipeline with related infrastructure to transport crude oil from Colorado City, Texas for delivery to Houston and Texas City, Texas refineries. This pipeline is expected to begin service in mid-2014. We receive construction management fees from BridgeTex, which we report as affiliate management fee revenue on our consolidated statements of income.
	During 2013, we received $4.8 million from BridgeTex as a deposit for the purchase of emission reduction credits, which we expect to transfer to BridgeTex during the first half of 2014. Also in 2013, we received $1.4 million from BridgeTex for the purchase of easement rights from us, of which $0.7 million was recorded as a reduction of operating expense and $0.7 million was recorded as an adjustment to our investment in BridgeTex, which will be amortized as a reduction of operating expense over the weighted average depreciable lives of the BridgeTex assets.
	A summary of our investments in non-controlled entities follows (in thousands):
		Texas Frontera		Osage			Double Eagle		BridgeTex			Consolidated
	Investment at December 31, 2012	$	15,728	$	18,888		$	40,840	$	31,900		$	107,356
	Additional investment	—		—			35,500		214,995			250,495
	Earnings (losses) of non-controlled entities:
	Proportionate share of earnings (losses)	2,494		4,383			82		(20		)	6,939
	Amortization of excess investment	—		(664		)	—		—			(664		)
	Earnings (losses) of non-controlled entities	2,494		3,719			82		(20		)	6,275
	Less:
	Distributions of earnings from investments in non-controlled entities	2,494		—			—		—			2,494
	Distributions in excess of earnings of non-controlled entities	780		—			—		—			780
	Investment at December 31, 2013	$	14,948	$	22,607		$	76,422	$	246,875		$	360,852
	The operating results from Texas Frontera are included in our marine storage segment and the operating results from Osage, Double Eagle and BridgeTex are included in our crude oil segment.
	Our initial investment in Osage included an excess net investment amount of $21.7 million. Excess investment is the amount by which our initial investment exceeded our proportionate share of the book value of the net assets of the investment. The unamortized excess net investment amount at December 31, 2013 was $15.1 million.

Business_Combinations_Notes

Business Combinations (Notes)	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Business Combination Disclosure	'
	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 a 250-mile pipeline that transports refined petroleum products from El Paso, Texas north to Albuquerque, New Mexico and transports products south to the U.S.–Mexico border for delivery within Mexico via a third-party pipeline for $57.0 million, which we funded with cash on hand. This pipeline system serves as a natural extension of our existing refined products pipeline system and allows us to provide options to customers in Albuquerque and central New Mexico to access refined products from West Texas, Gulf Coast and Mid-Continent refiners. The operating results have been included in our refined products segment since the acquisition date.
	•	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. The system includes four terminals with nearly 1.7 million barrels of storage. We funded this $135.0 million acquisition primarily with proceeds from our debt offering in October 2013. This pipeline system is a strategic fit with our existing assets and customer relationships and extends the reach of our pipeline system to allow us to serve new geographic markets. The operating results have been included in our refined products segment since the acquisition date.
	We have completed our appraisal of the assets acquired with the New Mexico/Texas pipeline system and the fair values and purchase price allocations for these assets are final; however, we are still in the process of completing an appraisal of the Rocky Mountain system assets acquired in November 2013. Our final determination of the fair value of these assets and the allocation of the purchase price will be made when that valuation process has been completed. The purchase price and initial 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 our business combination were included in our operating results since the date of acquisition through December 31, 2013 (in thousands):
	Revenue	$	12,661
	Operating profit	$	6,400
	The following summarized pro forma consolidated income statement information assumes that the 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.

Inventory

Inventory	12 Months Ended
	Dec. 31, 2013
Inventory Disclosure [Abstract]	'
Inventory	'
	Inventory
	Inventory at December 31, 2012 and 2013 was as follows (in thousands):
		2012		2013
	Refined petroleum products	$	88,630	$	77,144
	Liquefied petroleum gases	45,657		23,476
	Transmix	63,026		72,156
	Crude oil	17,443		7,188
	Additives	7,132		7,260
	Total inventory	$	221,888	$	187,224

Product_Sales_Revenue

Product Sales Revenue	12 Months Ended
	Dec. 31, 2013
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. We use NYMEX contracts to hedge against changes in the price of refined products we expect to sell from our business activities where we acquire or produce petroleum products. Some of these NYMEX contracts qualify for hedge accounting treatment and we designate and account for these as either cash flow or fair value hedges. The effective portion of the fair value changes in contracts designated as cash flow hedges are recognized as adjustments to product sales when the hedged product is physically sold. Ineffectiveness in the contracts designated as cash flow hedges is recognized as an adjustment to product sales in the period the ineffectiveness occurs. We account for NYMEX contracts that do not qualify for hedge accounting treatment as economic hedges, with the period changes in fair value recognized as product sales, except for those agreements that economically hedge the inventories associated with our pipeline system overages (the period changes in the fair value of these agreements are charged to operating expense). See Note 13 - Derivative Financial Instruments for further disclosures regarding our NYMEX contracts.
	For the years ended December 31, 2011, 2012 and 2013, product sales revenue included the following (in thousands):
		Year Ended December 31,
		2011			2012			2013
	Physical sale of refined products	$	870,007		$	833,581		$	755,266
	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)	(4,330		)	(30,270		)	(10,586		)
	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)	(11,149		)	(3,940		)	—
	Other	—			11			(11		)
	Total NYMEX contract adjustments	(15,479		)	(34,199		)	(10,597		)
	Total product sales revenue	$	854,528		$	799,382		$	744,669
	(1) The associated refined 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, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant And Equipment	'
	Property, Plant and Equipment
	Property, plant and equipment consisted of the following (in thousands):
		December 31,				Estimated Depreciable
		2012		2013		Lives
	Construction work-in-progress	$	247,571	$	165,129
	Land and rights-of-way	83,014		78,405
	Carrier property	1,835,265		2,135,905		7 to 59 years
	Buildings	37,672		41,383		20 to 55 years
	Storage tanks	975,277		1,141,271		10 to 40 years
	Pipeline and station equipment	479,531		593,396		3 to 59 years
	Processing equipment	645,140		716,103		3 to 56 years
	Other	105,080		115,158		3 to 48 years
	Property, Plant and Equipment, Gross	$	4,408,550	$	4,986,750
	Carrier property is defined as pipeline assets regulated by the FERC. Other includes total interest capitalized as of December 31, 2012 and 2013 of $24.3 million and $33.2 million, respectively. Depreciation expense for the years ended December 31, 2011, 2012 and 2013 was $118.9 million, $126.7 million and $136.4 million, respectively.

Major_Customers_and_Concentrat

Major Customers and Concentration Of Risks	12 Months Ended
	Dec. 31, 2013
Major Customers and Concentration Of Risks [Abstract]	'
Major Customers and Concentration Of Risks	'
	Major Customers and Concentration of Risks
	Major Customers. No customer accounted for 10% or more of our consolidated total revenue in 2013. However, one customer accounted for 21% and 14% of our consolidated total revenue in 2011 and 2012, respectively. 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 and from sales associated with the management of our linefill for the Houston-to-El Paso pipeline section, all of which are or were activities conducted by our refined products segment.
	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 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.
	As of December 31, 2013, we had 1,459 employees.  At December 31, 2013, the labor force of 842 employees assigned to our refined products segment was concentrated in the central U.S.  Approximately 26% of these employees were represented by the United Steel Workers (“USW”) and covered by a collective bargaining agreement that expires January 31, 2015. At December 31, 2013, the labor force of 51 employees assigned to our crude oil segment was concentrated in the central U.S. and none of these employees were covered by a collective bargaining agreement.  The labor force of 171 employees assigned to our marine storage segment at December 31, 2013 was primarily located in the Gulf and East Coast regions of the U.S.  Approximately 16% 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, 2013
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, 2012 and 2013 (in thousands):
			Pension Benefits							Other Postretirement
										Benefits
			2012				2013			2012				2013
	Change in benefit obligation:
	Benefit obligation at beginning of year		$	113,914			$	142,703		$	23,786			$	13,195
	Service cost		12,222				13,901			396				288
	Interest cost		4,862				5,368			821				412
	Plan participants’ contributions		—				—			221				248
	Actuarial loss (gain)		15,975				(14,121		)	4,751				(2,675		)
	Benefits paid		(4,270		)		(5,541		)	(760		)		(1,050		)
	Plan amendment		—				—			(16,020		)		—
	Benefit obligation at end of year		142,703				142,310			13,195				10,418
	Change in plan assets:
	Fair value of plan assets at beginning of year		70,052				87,106			—				—
	Employer contributions		13,336				15,470			539				802
	Plan participants’ contributions		—				—			221				248
	Actual return on plan assets		7,988				3,521			—				—
	Benefits paid		(4,270		)		(5,541		)	(760		)		(1,050		)
	Fair value of plan assets at end of year		87,106				100,556			—				—
	Funded status at end of year		$	(55,597	)		$	(41,754	)	$	(13,195	)		$	(10,418	)
	Accumulated benefit obligation		$	101,233			$	103,466
	The amounts included in pension benefits in the previous table combine the Union plans with the Salaried plan. At December 31, 2012, the fair value of each of the pension plans' assets was less than the fair values of the respective accumulated benefit obligations. At December 31, 2013, the Union plans' assets had a combined accumulated benefit obligation of $41.1 million, which exceeded the combined fair value of plan assets of $36.6 million.
	The 2012 actuarial loss of $16.0 million for our pension plans was due primarily to the impact of decreases in the discount rate used to calculate the benefit obligation. The 2013 actuarial gain of $14.1 million was due primarily to the impact of increases in the discount rate used to calculate the benefit obligation.
	Prior to July 1, 2012, our postretirement benefits provided coverage to participants age 65 and older that was secondary to Medicare Part A, Part B and Part D. The cost to plan participants for the age-65-and-older component of this coverage was higher than similar medical insurance coverage available in the marketplace. Therefore, in June 2012, we amended our other postretirement medical benefit to exclude coverage for post-65 participants. For participants under age 65, the medical coverage remains unchanged. We accounted for this change as a negative plan amendment which resulted in a reduction of our postretirement liability of $16.0 million.
	Amounts recognized in the consolidated balance sheets included in these financial statements were as follows (in thousands):
			Pension Benefits							Other Postretirement
										Benefits
			2012				2013			2012				2013
	Amounts recognized in consolidated balance sheet:
	Current accrued benefit cost		$	—			$	—		$	(658	)		$	(535	)
	Long-term pension and benefit cost		(55,597		)		(41,754		)	(12,537		)		(9,883		)
			(55,597		)		(41,754		)	(13,195		)		(10,418		)
	Accumulated other comprehensive loss:
	Net actuarial loss		51,899				36,151			11,418				7,708
	Prior service cost (credit)		340				33			(14,473		)		(10,761		)
			52,239				36,184			(3,055		)		(3,053		)
	Net amount recognized in consolidated balance sheet		$	(3,358	)		$	(5,570	)	$	(16,250	)		$	(13,471	)
	Net periodic benefit expense for the years ended December 31, 2011, 2012 and 2013 were as follows (in thousands):
			Pension Benefits											Other Postretirement Benefits
			2011				2012			2013				2011			2012			2013
	Components of net periodic pension and postretirement benefit expense:
	Service cost		$	9,628			$	12,222		$	13,901			$	430		$	396		$	288
	Interest cost		4,343				4,862			5,368				999			821			412
	Expected return on plan assets		(4,357		)		(5,066		)	(6,228		)		—			—			—
	Amortization of prior service cost (credit)		307				307			307				(851		)	(1,971		)	(3,712		)
	Amortization of actuarial loss		1,424				3,605			4,334				167			1,021			1,035
	Settlement cost		70				—			—				—			—			—
	Net periodic expense (credit)		$	11,415			$	15,930		$	17,682			$	745		$	267		$	(1,977	)
	Other changes in plan assets and benefit obligations recognized in other comprehensive loss during 2012 and 2013 were as follows (in thousands):
			Pension Benefits							Other Postretirement
										Benefits
			2012				2013			2012				2013
	Other changes in plan assets and benefit obligations recognized in other comprehensive loss:
	Net actuarial loss (gain)		$	13,053			$	(11,414	)	$	4,751			$	(2,675	)
	Plan amendment		—				—			(16,020		)		—
	Amortization of actuarial loss		(3,605		)		(4,334		)	(1,021		)		(1,035		)
	Amortization of prior service credit (cost)		(307		)		(307		)	1,971				3,712
	Total recognized in other comprehensive loss		9,141				(16,055		)	(10,319		)		2
	Net periodic expense (credit)		15,930				17,682			267				(1,977		)
	Total recognized in net periodic benefit cost and other comprehensive loss		$	25,071			$	1,627		$	(10,052	)		$	(1,975	)
We match our employees' qualifying contributions to our defined contribution plan, resulting in expense to us. Expenses related to the defined contribution plan were $6.2 million, $6.5 million and $7.1 million in 2011, 2012 and 2013, respectively.
The estimated net actuarial loss and prior service cost for the defined benefit pension plans that will be amortized from AOCL into net periodic benefit cost in 2014 are $2.5 million and less than $0.1 million, respectively. 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 2014 are $0.8 million and $(3.7) million, respectively.
The weighted-average rate assumptions used to determine benefit obligations as of December 31, 2012 and 2013 were as follows:
		Pension Benefits				Other
						Postretirement Benefits
		2012		2013		2012		2013
Discount rate—Salaried plan		4.00%		4.89%		n/a		n/a
Discount rate—USW plan		3.39%		4.26%		n/a		n/a
Discount rate—IUOE plan		3.99%		4.89%		n/a		n/a
Discount rate—Other Postretirement Benefits		n/a		n/a		3.58%		4.52%
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, 2011, 2012 and 2013 were as follows:
		Pension Benefits						Other
								Postretirement Benefits
		2011		2012		2013		2011	2012			2013
Discount rate—Salaried plan		5.54%		4.39%		4.00%		n/a	n/a			n/a
Discount rate—USW plan		5.07%		4.00%		3.39%		n/a	n/a			n/a
Discount rate—IUOE plan		5.52%		4.37%		3.99%		n/a	n/a			n/a
Discount rate—Other Postretirement Benefits		n/a		n/a		n/a		5.56%	3.75	%		3.58	%
Rate of compensation increase—Salaried plan		5.00%		5.00%		5.00%		n/a	n/a			n/a
Rate of compensation increase—USW plan		4.50%		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%		6.80%		n/a	n/a			n/a
Expected rate of return on plan assets—USW plan		6.80%		6.80%		6.80%		n/a	n/a			n/a
Expected rate of return on plan assets—IUOE plan		3.25%		6.80%		6.80%		n/a	n/a			n/a
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 2014 is 6.0% decreasing systematically to 4.7% by 2087 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, 2013, 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		$	39			$	35
Change in postretirement benefit obligation		$	533			$	486
The fair value of the pension plan assets at December 31, 2012 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		$	1,726			$	1,726		$	—			$	—
Mid-cap fund		1,708				1,708			—				—
Large-cap fund		12,810				12,810			—				—
International equity fund		8,019				8,019			—				—
Fixed Income Securities(a):
Short-term bond funds		2,824				2,824			—				—
Intermediate-term bond funds		16,677				16,677			—				—
Long-term investment grade bond fund		40,370				40,370			—				—
Other:
Short-term investment fund		2,614				2,614			—				—
Group annuity contract		358				—			—				358
Fair value of plan assets		$	87,106			$	86,748		$	—			$	358
(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, 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 funds		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 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, 2012 and 2013 were as follows (in thousands):
	2012				2013
Beginning balance	$	400			$	358
Actual return on plan assets:
Relating to assets still held at the reporting date	16				(7		)
Purchases, issuances, sales and settlements:
Settlements	(58		)		(54		)
Ending balance	$	358			$	297
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		Seek current income with limited price volatility through investment in primarily high quality bonds
Intermediate-term bond funds		Seek 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		Seek high and sustainable current income through investment primarily in long-term high grade bonds
Other:
Short-term investment funds		Invest 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, 2012 and 2013 were as follows:
		2012				2013
		Actual(a)		Target		Actual(a)		Target
Equity securities		28%		30%		35%		30%
Debt securities		69%		67%		62%		67%
Other		3%		3%		3%		3%
(a)	Cash contributions of $13.3 million and $15.5 million were made to the pension plans during 2012 and 2013, respectively. Amounts contributed in 2012 and 2013 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, 2012 and 2013 scheduled for investment in accordance with the target. Excluding these uninvested cash amounts, the actual allocation percentages at December 31, 2012 would have been 29% equity securities and 71% debt securities and at December 31, 2013, would have been 36% equity securities and 64% debt securities. In 2014, we will invest these uninvested cash amounts to bring the total asset allocation in line with the target allocation.
As of December 31, 2013, the benefit amounts we expect to pay through December 31, 2023 were as follows (in thousands):
		Pension				Other
		Benefits				Postretirement
						Benefits
2014		$	5,207			$	535
2015		$	5,507			$	590
2016		$	6,282			$	578
2017		$	9,267			$	627
2018		$	9,032			$	665
2019 through 2023		$	58,108			$	4,205
Contributions estimated to be paid into the plans in 2014 are $19.8 million and $0.5 million for the pension and other postretirement benefit plans, respectively.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	Barry R. Pearl is an independent member of our general partner's board of directors and is also a director of Targa Resources Partners, L.P. ("Targa"). In the normal course of business, we purchase butane from subsidiaries of Targa. For the years ended December 31, 2011, 2012 and 2013, we made purchases of butane from subsidiaries of Targa of $11.7 million, $27.4 million and $30.4 million, respectively. These purchases were made on the same terms as comparable third-party transactions. The amount payable to Targa at December 31, 2012 was $0.1 million. There were no amounts payable to Targa at December 31, 2013.
	In January 2011, our former chief executive officer, Don R. Wellendorf, retired. In conjunction with Mr. Wellendorf's retirement, our general partner's board of directors engaged Mr. Wellendorf as a consultant to us for a period of twelve months beginning in February 2011 for consideration of $0.3 million and an agreement that certain of his previously-awarded phantom unit awards would not be forfeited. Expense associated with these awards for the years ended December 31, 2011 and 2012 was $2.1 million and $0.5 million, 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, 2013
Debt Disclosure [Abstract]	'
Debt	'
	Debt
	Debt at December 31, 2012 and 2013 was as follows (in thousands):
							Weighted-Average Interest Rate at December 31, 2013 (a)
			December 31,
			2012		2013
	Revolving credit facility		$	—	$	—	—%
	$250.0 million of 6.45% Notes due 2014		249,905		249,971		6.30%
	$250.0 million of 5.65% Notes due 2016		251,609		251,183		5.70%
	$250.0 million of 6.40% Notes due 2018		261,411		259,346		5.40%
	$550.0 million of 6.55% Notes due 2019		575,065		571,515		5.70%
	$550.0 million of 4.25% Notes due 2021		558,088		557,213		4.00%
	$250.0 million of 6.40% Notes due 2037		248,981		248,998		6.40%
	$250.0 million of 4.20% Notes due 2042		248,349		248,377		4.20%
	$300.0 million of 5.15% Notes due 2043		—		298,684		5.20%
	Total debt		$	2,393,408	$	2,685,287	5.20%
	(a)	Weighted-average interest rate includes the amortization/accretion of discounts and premiums and the amortization/accretion of gains and losses realized on historical cash flow and fair value hedges on interest expense.
	The revolving credit facility and notes detailed in the table above are senior indebtedness.
	The face value of our debt at December 31, 2012 and 2013 was $2.4 billion and $2.7 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, 2013, maturities of our debt were as follows: $250.0 million in 2014; $0 in 2015; $250.0 million in 2016; $0 in 2017; $250.0 million in 2018; and $1.9 billion thereafter.
	2013 Debt Offering
	In October 2013, we issued $300.0 million of 5.15% notes due October 15, 2043 in an underwritten public offering. The notes were issued for the discounted price of 99.6% of par. We used the net proceeds from this offering of approximately $295.6 million, after underwriting discounts and offering expenses of $3.1 million, to repay borrowings outstanding under our revolving credit facility and for general partnership purposes, including expansion capital.
	Other Debt
	Revolving Credit Facility. During November 2013, we amended our revolving credit facility to increase the borrowing capacity from $800.0 million to $1.0 billion and extend the maturity date from October 2016 to November 2018. In connection with this amendment, we paid $1.7 million of debt placement fees and wrote off $0.2 million of unamortized debt placement fees associated with the original revolving credit facility. Borrowings under our revolving credit facility are unsecured and bear interest at LIBOR plus a spread ranging from 1.0% to 1.75% based on our credit ratings. At December 31, 2013, our borrowing rate under the facility was LIBOR plus 1.125%. 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, 2013. Borrowings under this facility may be used for general purposes, including capital expenditures. As of December 31, 2013, 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.
	The revolving credit facility described above 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, 2013.
	During the years ending December 31, 2011, 2012 and 2013, total cash payments for interest on all indebtedness, excluding the impact of related interest rate swap agreements, were $111.7 million, $123.3 million and $134.6 million, respectively.

Derivative_Financial_Instrumen

Derivative Financial Instruments

12 Months Ended

Dec. 31, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

'

Derivative Financial Instruments

'

Derivative Financial Instruments

Interest Rate Derivatives

We periodically enter into interest rate derivatives to economically hedge debt, interest or expected debt issuances, and we have historically designated these derivatives as cash flow or fair value hedges for accounting purposes. Adjustments resulting from discontinued hedges continue to be recognized in accordance with their historic hedging relationships.

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 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. The gain was recorded to other comprehensive income and will be recognized into earnings as an adjustment to our periodic interest accruals for the 30 years of hedged interest payments following the expected debt issuance. If management were to determine that it was probable this forecasted transaction would not occur in 2014, the $11.0 million gain we have recorded to other comprehensive income would be reclassified into earnings.

Interest Rate Derivatives Activity During 2011. During 2011, we entered into $100.0 million of interest rate swap agreements, which were accounted for as fair value hedges, to hedge against changes in the fair value of a portion of our $250.0 million of 6.40% notes due 2018. In third quarter 2011, we terminated and settled these interest rate swap agreements and received $5.9 million, which was recorded as an adjustment to long-term debt that is being amortized over the remaining life of the notes into interest expense.

Commodity Derivatives

Hedging Strategies

Our butane blending activities produce gasoline products, and we can reasonably estimate the timing and quantities of sales of these products. We use a combination of forward purchase and sale contracts, NYMEX contracts and butane futures agreements to help manage price changes, which has the effect of locking in most of the product margin realized from our butane blending activities that we choose to hedge.

We account for the forward physical purchase and sale contracts we use in our butane blending and fractionation activities as normal purchases and sales. Forward contracts that qualify for and are elected as normal purchases and sales are accounted for using traditional accrual accounting. As of December 31, 2013, we had commitments under these forward purchase and sale contracts as follows (in millions):

Notional Value

Barrels

Forward purchase contracts

$

122.8

2

Forward sale contracts

$

64.2

0.6

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 are recorded to accumulated other comprehensive income/loss and reclassified to earnings when the forecasted transaction occurs. Ineffectiveness is recognized currently in earnings.

Fair Value Hedge

To hedge against changes in the fair value of a recognized asset or liability.

The effective portion of changes in the value of the hedge are recorded as adjustments to the asset or liability being hedged. Any ineffectiveness is recognized currently in earnings.

Does not Qualify For Hedge Accounting Treatment

Economic Hedge

To effectively serve as either a fair value or a cash flow hedge; however, the derivative agreement does not qualify for hedge accounting treatment or is not designated as a hedge in accordance with 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 considered economic hedges, 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 butane blending and fractionation activities are recognized currently in earnings as adjustments to product sales.

We also use exchange-traded butane futures agreements, which are not designated as hedges for accounting purposes, to hedge against changes in the price of butane we expect to purchase in the future. Period changes in the fair value of these agreements are recognized currently in earnings as adjustments to cost of product sales.

Additionally, we currently hold petroleum product inventories that we obtained from overages on our pipeline systems. We use NYMEX contracts that are not designated as hedges for accounting purposes to help manage price changes related to these overage inventory barrels. Period changes in the fair value of these agreements are recognized currently in earnings as adjustments to operating expense.

As outlined in the table below, our open NYMEX contracts and butane futures agreements at December 31, 2013 were as follows:

Type of Contract/Accounting Methodology

Product Represented by the Contract and Associated Barrels

Maturity Dates

NYMEX - Fair Value Hedges

0.7 million barrels of crude oil

Between January 2014 and November 2016

NYMEX - Economic Hedges

2.2 million barrels of refined products and crude oil

Between January and April 2014

Butane Futures Agreements - Economic Hedges

0.1 million barrels of butane

Between January and April 2014

Energy Commodity Derivatives Contracts and Deposits Offsets

At December 31, 2013, we had made margin deposits of $14.8 million for our NYMEX contracts. We have the right to offset the combined fair values of our open NYMEX contracts and our open butane futures agreements against our margin deposits under a master netting arrangement; however, we have elected to disclose the combined fair values of our open NYMEX and butane futures agreements separately from the related margin deposits on our consolidated balance sheets. Additionally, we have the right to offset the fair values of our NYMEX agreements and butane futures agreements together for each counterparty, which we have elected to do, and we report the combined net balances on our consolidated balance sheets. A schedule of the derivative amounts we have offset and the deposit amounts we could offset under a master netting arrangement are provided below as of December 31, 2012 and 2013 (in thousands):

31-Dec-12

Description

Gross Amounts of Liabilities

Gross Amounts of Assets

Net Amounts of Liabilities Presented in the Consolidated Balance Sheet

Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet

Net Amount

Energy commodity derivatives

$

(9,388

)

$

2,050

$

(7,338

)

$

18,304

$

10,966

31-Dec-13

Description

Gross Amounts of 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 Amount

Energy commodity derivatives

$

(7,167

)

$

2,665

$

(4,502

)

$

14,782

$

10,280

(1) Net amount includes energy commodity derivative contracts classified as current liabilities, net, of $6,737 and noncurrent assets of $2,235.

Impact of Derivatives on Income Statement, Balance Sheet and AOCL

At December 31, 2012 and 2013, we had open NYMEX contracts on 0.7 million barrels of crude oil that were designated as fair value hedges. During 2012, because there was no ineffectiveness recognized on these hedges, the cumulative losses of $5.7 million from the agreements were fully offset by a cumulative increase of $5.5 million to tank bottom inventory and an increase of $0.2 million to other current assets; therefore, there was no net impact from these agreements on income/expense. During 2013, because there was no ineffectiveness recognized on these hedges, the cumulative losses of $8.7 million from the agreements were fully offset by a cumulative increase of $8.9 million to tank bottom inventory and a decrease of $0.2 million to other current assets; therefore, there was no net impact from these agreements on income or expense.

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 and 2013 of the effective portion of derivatives accounted for under ASC 815-30, Derivatives and Hedging—Cash Flow Hedges, that were designated as hedging instruments (in thousands). 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

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

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

)

There was no ineffectiveness recognized on the financial instruments disclosed in the above tables during the years ended December 31, 2012 and 2013. 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, 2011, 2012 and 2013. As of December 31, 2013, the net loss estimated to be classified to interest expense over the next twelve months from AOCL is approximately $0.1 million.

The following table provides a summary of the effect on our consolidated statements of income for the years ended December 31, 2012 and 2013 of derivatives accounted for under ASC 815-10-35; Derivatives and Hedging—Overall—Subsequent Measurement, that were not designated as hedging instruments (in thousands):

Amount of Gain (Loss)

Recognized on Derivative

Year Ended December 31,

Derivative Instrument

Location of Gain (Loss)

2012

2013

Recognized on Derivative

NYMEX commodity contracts

Product sales revenue

$

(36,959

)

$

(6,189

)

NYMEX commodity contracts

Operating expenses

(2,055

)

(3,770

)

Butane futures agreements

Cost of product sales

1,203

2,682

Total

$

(37,811

)

$

(7,277

)

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, 2012 and 2013 (in thousands):

December 31, 2012

Asset Derivatives

Liability Derivatives

Derivative Instrument

Balance Sheet Location

Fair Value

Balance Sheet Location

Fair Value

NYMEX commodity contracts

Energy commodity derivatives contracts, net

$

473

Energy commodity derivatives contracts, net

$

207

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

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, 2012 and 2013 (in thousands):

December 31, 2012

Asset Derivatives

Liability Derivatives

Derivative Instrument

Balance Sheet Location

Fair Value

Balance Sheet Location

Fair Value

NYMEX commodity contracts

Energy commodity derivatives contracts, net

$

227

Energy commodity derivatives contracts, net

$

8,954

Butane futures agreements

Energy commodity derivatives contracts, net

1,350

Energy commodity derivatives contracts, net

227

Total

$

1,577

Total

$

9,181

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

Leases

Leases	12 Months Ended
	Dec. 31, 2013
Leases [Abstract]	'
Leases	'
	Leases
	Leases—Lessee. We lease land, office buildings and terminal equipment at various locations to conduct our business operations. During 2013, we 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 $4.6 million, $4.8 million and $12.0 million for the years ended December 31, 2011, 2012 and 2013, respectively. Future minimum annual rentals under non-cancellable operating leases with initial or remaining terms greater than one year as of December 31, 2013, were as follows (in millions):
	2014	$	16.2
	2015	16.5
	2016	16.1
	2017	16.6
	2018	13.1
	Thereafter	51.5
	Total	$	130
	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, 2013, were as follows (in millions):
	2014	$	240.8
	2015	229.7
	2016	174.6
	2017	111.7
	2018	71.3
	Thereafter	170.5
	Total	$	998.6

LongTerm_Incentive_Plan

Long-Term Incentive Plan	12 Months Ended
	Dec. 31, 2013
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, 2013 total approximately 1.8 million. The compensation committee 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.  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, 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. We account for this portion of the award grants as a liability. 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, 2013.
			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 - 1/1/2013		444,090			$	31.24			58,802			$	24.6			111,025			$	43.19			613,917			$	32.77
	Units granted during 2013		182,798			$	51.49			22,668			$	53.02			45,700			$	51.49			251,166			$	51.63
	Units vested during 2013		(228,058	)		$	29.07			(2,207	)		$	34.02			(57,015	)		$	63.27			(287,280	)		$	35.9
	Units forfeited during 2013		(9,420	)		$	35.98			(4,052	)		$	25			(2,355	)		$	63.27			(15,827	)		$	37.23
	Non-vested units - 12/31/13		389,410			$	41.9			75,211			$	32.87			97,355			$	63.27			561,976			$	44.4
	The table below summarizes the total non-vested unit awards granted by the compensation committee. The award grants have been 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:
	2012 Awards	267,322			39,225			228,097			456,194			12/31/14		$	6
	2013 Awards	228,498			31,869			147,472			344,101			12/31/15		12.4
	Retention Awards:
	2014 Vesting Date	71,849			10,778			—			61,071			12/31/14		0.7
	2015 Vesting Date	444			22			—			422			12/31/15		—
	2016 Vesting Date	13,300			665			—			12,635			12/31/16		0.7
	Total	581,413			82,559			375,569			874,423					$	19.8
	(a) Unrecognized compensation expense will be recognized over the remaining vesting period of the awards.
	Weighted-Average Grant Date Fair Values
	The weighted-average grant-date fair value of award grants issued during 2011, 2012 and 2013 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 2011		281,180			$	28.52			59,880			$	23.96			70,296			$	34.32
	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
	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, 2013. 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
	12/31/11		1,100,276			$	16.5			$	37.9
	12/31/12		751,237			$	17.1			$	32.5
	12/31/13		572,353			$	20.5			$	36.2
	* Represents the amount of the equity-based liabilities settled in January of the year following the vesting date.
	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-11		505,492			$	7.4			$	0.9			$	8.3
	Jan-12		722,766			$	13			$	1.3			$	14.3
	Jan-13		476,682			$	12.3			$	1.1			$	13.4
	Compensation Expense Summary
	Equity-based incentive compensation expense, excluding amounts for directors (discussed below), for 2011, 2012 and 2013 was as follows (in thousands):
		Year Ended December 31, 2011												Year Ended December 31, 2012												Year Ended December 31, 2013
		Equity				Liability				Total				Equity				Liability				Total				Equity			Liability		Total
		Method				Method								Method				Method								Method			Method
	2009 awards	$	4,418			$	4,264			$	8,682			$	—			$	—			$	—			$	—		$	—	$	—
	2010 awards	3,100				1,562				4,662				4,937				3,723				8,660				121			73		194
	2011 awards	2,839				841				3,680				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
	2013 awards	—				—				—				—				—				—				4,726			1,451		6,177
Retention awards	686				—				686				693				—				693				575			—		575
Total	$	11,043			$	6,667			$	17,710			$	14,118			$	6,918			$	21,036			$	15,532		$	8,551	$	24,083
Allocation of LTIP expense on our consolidated statements of income:
G&A expense									$	16,024											$	18,587								$	23,264
Operating expense									1,686												2,449									819
Total									$	17,710											$	21,036								$	24,083
Director Compensation Expense
Pursuant to our LTIP, long-term incentive awards are granted to independent members of the board of directors of our general partner. Most directors elect to defer all or a portion of their compensation. The table below summarizes the phantom limited partner units earned by our independent directors and total equity-based director compensation expense recognized. The phantom unit and compensation amounts below include amounts credited to the directors' accounts for distribution equivalents earned.
		Year Ended December 31,
		2011				2012				2013
Phantom units earned pursuant to the LTIP		20,284				20,054				16,424
(in thousands)
Compensation - phantom unit expense		$	446			$	523			$	533
Distribution equivalents		139				195				267
Changes in market value of phantom units		568				973				2,535
Total value of phantom units		1,153				1,691				3,335
Compensation paid in cash		292				345				422
Compensation paid in our limited partner units		140				170				85
Total director compensation		1,585				2,206				3,842
Distribution equivalents charged to partners' capital		(139		)		(195		)		(267		)
Total director compensation expense		$	1,446			$	2,011			$	3,575

Segment_Disclosures

Segment Disclosures	12 Months Ended
	Dec. 31, 2013
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 in 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 G&A expenses that management does not consider when evaluating the core profitability of our operations.
		Year Ended December 31, 2011
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
		(in thousands)
	Transportation and terminals revenue	$	680,235	$	61,205		$	151,929		$	—		$	893,369
	Product sales revenue	848,902		591			5,035			—			854,528
	Affiliate management fee revenue	—		770			—			—			770
	Total revenue	1,529,137		62,566			156,964			—			1,748,667
	Operating expenses	250,794		(4,898		)	63,438			(2,919		)	306,415
	Cost of product sales	704,313		—			1,957			—			706,270
	Earnings of non-controlled entities	—		(6,761		)	(2		)	—			(6,763		)
	Operating margin	574,030		74,225			91,571			2,919			742,745
	Depreciation and amortization expense	81,876		10,303			26,081			2,919			121,179
	G&A expenses	80,746		1,773			16,150			—			98,669
	Operating profit	$	411,408	$	62,149		$	49,340		$	—		$	522,897
	Additions to long-lived assets	$	130,645	$	45,124		$	38,125					$	213,894
		As of December 31, 2011
	Segment assets	$	2,736,522	$	432,073		$	638,451					$	3,807,046
	Corporate assets												237,955
	Total assets												$	4,045,001
	Goodwill	$	38,369	$	12,082		$	2,809					$	53,260
	Investments in non-controlled entities	$	—	$	24,936		$	10,658					$	35,594
		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

Commitments_and_Contingencies_

Commitments and Contingencies Commitments and Contingencies (Notes)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies Disclosure [Text Block]	'
	Commitments and Contingencies
	Clean Air Act - Section 185 Liability
	Section 185 of the Clean Air Act ("CAA 185") requires states to collect annual fees from major source facilities located in severe or extreme nonattainment ozone areas that did not meet the attainment deadline.  The CAA 185 fees are required annually until the area is redesignated as an attainment area for ozone. The Houston-Galveston region was determined to be a severe nonattainment area that did not meet its 2007 attainment deadline and, as such, would be subject to CAA 185.
	During 2011, the Texas Commission on Environmental Quality (“TCEQ”) had published notices concerning its intention to issue a “Failure to Attain Rule” to implement the requirements of CAA 185. At that time, management believed it was probable that the TCEQ’s Failure to Attain Rule would provide for the collection of annual failure to attain fees for excess emissions for the annual periods from 2008 through 2011.  We have certain facilities in the Houston area that would have been subject to these rules; therefore, we recognized a $10.9 million environmental liability during 2011 as our estimate of excess emission fees we would be required to pay under the rules.
	In June 2013, the TCEQ adopted its Failure to Attain Rule which did not require retroactive assessment of the Section 185 fees for the annual periods of 2008 through 2011.  As a result, during 2013, in accordance with the TCEQ's final rule, we reduced our accrual by $10.6 million.
	Environmental Liabilities
	Liabilities recognized for estimated environmental costs were $48.3 million and $38.5 million at December 31, 2012 and December 31, 2013, respectively. We have classified environmental liabilities as current or noncurrent based on management’s estimates regarding the timing of actual payments. Management estimates that expenditures associated with these environmental liabilities will be 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 $23.1 million, $12.0 million and $(5.2) million for the years ended December 31, 2011, 2012 and 2013, respectively. The higher environmental expense in 2011 was primarily due to the CAA 185 liability accrual and the lower environmental expense for 2013 was primarily due to the $10.6 million favorable adjustment to this accrual, both of which are discussed above.
	Environmental Receivables
	Receivables from insurance carriers and other third parties related to environmental matters at December 31, 2012 were $7.9 million, of which $2.8 million and $5.1 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheet. Receivables from insurance carriers related to environmental matters at December 31, 2013 were $4.8 million, of which $2.1 million and $2.7 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheet. Amounts received from insurance carriers and other third parties related to environmental matters during 2011, 2012 and 2013 were $0.5 million, $1.2 million and $4.2 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, 2013
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):
	2012	First		Second		Third		Fourth
		Quarter		Quarter		Quarter		Quarter
	Revenue	$	493,483	$	449,527	$	325,869	$	503,195
	Total costs and expenses	$	372,318	$	283,724	$	248,334	$	318,601
	Operating margin	$	178,067	$	224,181	$	138,527	$	248,698
	Net income	$	93,524	$	137,821	$	50,522	$	153,803
	Basic and diluted net income per limited partner unit	$	0.41	$	0.61	$	0.22	$	0.68
	2013
	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
	In mid-April 2013, we began making deliveries of crude oil from our Longhorn pipeline, which significantly benefited our operations. Further, during 2013, we completed the acquisition of the New Mexico/Texas and Rocky Mountain pipeline systems from Plains, which benefited our results of operations for the year, particularly in the fourth quarter. Also, second quarter 2013 results were benefited by the $10.6 million accrual reversal related to the Section 185 CAA liability (see Note 17--Commitments and Contingencies for further discussion of this matter).

Fair_Value_Disclosures

Fair Value Disclosures	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Disclosures	'
	Fair Value Disclosures
	Fair Value Methods and Assumptions - Financial Assets and Liabilities
	We used the following methods and assumptions in estimating fair value for our financial assets and liabilities:
	•	Cash and cash equivalents. Cash equivalents include money market and mutual fund accounts and commercial paper. The carrying amounts reported on our consolidated balance sheets approximate fair value due to the short-term maturity or variable rates of these instruments.
	•	Energy commodity derivatives deposits. This asset represents short-term deposits we have made associated with our energy commodity derivatives contracts. The carrying amount reported on our consolidated balance sheets approximates fair value as the deposits change daily in relation to the associated contracts which are held in separate accounts.
	•	Energy commodity derivatives contracts. These include NYMEX futures and exchange-traded butane futures agreements related to petroleum products. These contracts are carried at fair value on our consolidated balance sheets and are valued based on quoted prices in active markets. See Note 13 – Derivative Financial Instruments for further disclosures regarding these contracts.
	•	Long-term receivables. These are primarily insurance receivables, whose fair value was determined by estimating the present value of future cash flows using a risk-free rate of interest derived from U.S. treasury rates.
	•	Debt. The fair value of our publicly traded notes was based on the prices of those notes at December 31, 2012 and 2013; however, where recent observable market trades were not available, prices were determined using adjustments to the last traded value for that debt issuance or by adjustments to the prices of similar debt instruments of peer entities that are actively traded. The carrying amount of borrowings, if any, under our revolving credit facility approximates fair value due to the variable rates of that instrument.
	Fair Value Measurements - Financial Assets and Liabilities
	The following tables summarize the carrying amounts, fair values and recurring fair value measurements recorded or disclosed as of December 31, 2012 and 2013, based on the three levels established by ASC 820; Fair Value Measurements. The carrying values of cash and cash equivalents (classified as Level 1) and energy commodity derivatives deposits approximate fair value because of the short-term nature or variable rates of these instruments; therefore, these items are not presented in the following tables (in thousands):
									Fair Value Measurements as of
									December 31, 2012 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)		$	(7,338	)	$	(7,338	)	$	(7,338	)	$	—		$	—
	Long-term receivables		$	5,135		$	5,108		$	—		$	—		$	5,108
	Debt		$	(2,393,408	)	$	(2,721,985	)	$	(2,721,985	)	$	—		$	—
									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	)	$	—
	During 2013, we re-evaluated the market in which our debt securities trade.  Based on that review, we determined that this market no longer included sufficient market activity to qualify as an active market, as defined in ASC 820, Fair Value Measurements.  As a result, we transferred the hierarchical reporting level of the fair value measurement of our debt securities from Level 1 to Level 2.  Our policy is to effect transfers between hierarchical reporting levels at the end of the reporting period where it has been determined that a change is required.

Distributions

Distributions	12 Months Ended
	Dec. 31, 2013
Distributions Made to Members or Limited Partners [Abstract]	'
Distributions	'
		Distributions
	Distributions we paid during 2011, 2012 and 2013 were as follows (in thousands, except per unit amount):
	Payment Date		Per Unit Cash Distribution Amount		Total Cash Distribution
	2/14/11		$	0.37875	$	85,398
	5/13/11		0.385		86,807
	8/12/11		0.3925		88,498
	11/14/11		0.4		90,189
	Total		$	1.55625	$	350,892
	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

Owners_Equity

Owners' Equity	12 Months Ended
	Dec. 31, 2013
Stockholders' Equity Note [Abstract]	'
Owners' Equity	'
	Owners’ Equity
	The following table details the changes in the number of our limited partner units outstanding from January 1, 2011 through December 31, 2013:
	Limited partner units outstanding on January 1, 2011	224,962,698
	01/11—Settlement of 2008 award grants	505,492
	01/11—Other(a)	4,952
	Limited partner units outstanding on December 31, 2011	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
	(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, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	Subsequent Events
	Recognizable events
	No recognizable events have occurred subsequent to December 31, 2013.
	Non-recognizable events
	On February 3, 2014, 178,184 phantom unit awards were issued pursuant to our long-term incentive plan. These grants included both performance-based and retention awards and have a three-year vesting period that will end on December 31, 2016.
	On February 3, 2014, we issued 388,819 limited partner units, of which 387,216 were issued to settle unit award grants to certain employees that vested on December 31, 2013 and 1,603 were issued to settle the equity-based retainer paid to one of the directors of our general partner.
	On February 14, 2014, we paid cash distributions of $0.585 per unit on our outstanding limited partner units to unitholders of record at the close of business on February 7, 2014. The total distributions paid were $132.8 million.

Summary_Of_Significant_Account1

Summary Of Significant Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2013
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 ownership interests, except four 50%-owned investments that we do not control and which we have determined are not variable interest entities. Accordingly, we apply the equity method of accounting for the following entities: (i) Osage; (ii) Texas Frontera; (iii) Double Eagle; and (iv) BridgeTex. 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 highly marketable securities or 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, 2012 and 2013, 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 non-affiliated customers. We recognize accounts receivable when we sell products or render services, except tariff-related transportation services of our refined products pipeline, which we recognize when our customers' product enters our system, 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, crude oil and additives, 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 depreciate most of our assets individually on a straight-line basis over their useful lives; however, we group the individual components of certain assets, such as some of our older tanks, together into a composite asset, and we depreciate those assets using a composite rate. 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 associated with existing assets when they improve the productivity or increase the useful life 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.
Asset Retirement Obligation	'
	Asset Retirement Obligation.  We record the fair value of a liability related to the retirement of long-lived assets at the time we incur a legal obligation if the liability can be reasonably estimated.  When we initially record the liability, we increase the carrying amount of the related asset by the amount of the liability. Over time, we accrete the liability to its future value and record the accretion amount to operating expense.
	Our operating assets generally consist of underground pipelines and related components along rights-of-way and above ground storage tanks and related facilities.  Our right-of-way agreements typically do not require the dismantling, removal and reclamation of the right-of-way upon permanent cessation of pipeline service.  Additionally, management is unable to predict when, or if, our pipelines, storage tanks and related facilities would become completely obsolete and require decommissioning.
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, plus equity in earnings or losses since acquisition or formation, plus interest capitalized, less distributions received and amortization of excess net investment. Excess net investment is the amount by which our initial investment exceeded our proportionate share of the book value of the net assets of the investment. We amortize excess net investment over the weighted-average depreciable asset lives of the equity investee. Our unamortized excess net investment was $15.8 million and $15.1 million at December 31, 2012 and 2013, respectively. We evaluate equity method investments for impairment annually or 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 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, 2012 and 2013. Our reported goodwill at December 31, 2013 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.
	We base our determination of whether goodwill is impaired on management's estimate of the fair value of our reporting units using a discounted future cash flow (“DFCF”) model as compared to their carrying values. Critical assumptions used in our DFCF model included: (i) time horizon of 20 years, (ii) operating margin growth of 2.5%, (iii) annual maintenance capital spending growth of 2.5% and (iv) 11.0 times earnings before interest, taxes and depreciation and amortization ("EBITDA") multiple for terminal value. Management believes an 11.0 times EBITDA multiple is conservative and reasonable for determining terminal value because market participants in the energy industry community use EBITDA multiples ranging from 11.0 to 14.0, and higher, to determine fair value for assets being acquired or sold. We use October 1 as our impairment measurement test date and have determined that our goodwill was not impaired as of October 1, 2011, 2012 or 2013. If impairment were to occur, we would charge the amount of the impairment against earnings in the period in which the impairment occurred. The amount of the impairment would be determined by subtracting the implied fair value of the reporting unit goodwill from the carrying amount of the goodwill.
	Judgments and assumptions are inherent in management's estimates used to determine the fair value of our operating segments and are consistent with what management believes would be utilized by the primary market participant. The use of alternate judgments and assumptions could result in the recognition of different levels of impairment charges in our financial statements.
	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, 2013 was approximately 7 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 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 Bottom Inventory	'
	Tank Bottom Inventory. 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 as described below.
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, 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, rates of increase in health care costs, 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 have recorded or may record.
Paid-Time Off Benefits	'
	Paid-Time Off Benefits. We recognize liabilities for paid-time off benefits when earned.
Derivative Financial Instruments	'
	Derivative Financial Instruments. We record derivative instruments on our balance sheets at fair value as either assets or liabilities. We account for derivatives that qualify for and are elected for treatment as normal purchases and sales using traditional accrual accounting.
	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 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 either do not qualify for hedge accounting or 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. 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 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 or liabilities being hedged and the ineffective portions 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 or forecasted butane purchases. We record the change in fair value of those agreements in operating expenses and cost of product sales, respectively.
	We use interest rate derivatives to help manage interest rate risk. We record any ineffectiveness on derivatives designated as hedging instruments 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 when shipments are complete. 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, shipments are complete when 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, shipments are complete when the product arrives at the customer-designated delivery point. We recognize injection service fees associated with customer proprietary 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. We increase or decrease, as appropriate, product sales for gains and losses associated with the period change in fair value of our NYMEX agreements that we do not designate as hedges, except for those undesignated agreements that economically hedge the inventories associated with our pipeline system overages (which are recorded as adjustments to operating expense), and for the ineffective portion of our NYMEX agreements that we designate as cash flow hedges. When the physical sale of hedged refined products occurs, we increase or decrease, as appropriate, product sales for the effective portion of the gains and losses of the associated derivative agreement. 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 Revenues 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 production 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 shippers' inventories (as adjusted for tender deductions).  To the extent that the product volumes in our pipeline system exceeds the volumes of our shippers' book inventories, we increase our product inventories and recognize a gain and to the extent the product in our pipeline system is less than our shippers' book inventories, we record a liability (for product owed to our shippers) 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 Awards. 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 contain 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 equity awards is the closing price of our limited partner units on the grant date. 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 from 0% up to 250% of the amount of the award. Additionally, certain of these awards are also subject to personal and other performance components, which could increase or decrease the payout of the number of limited partner units by as much as 20%. 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 participant. Retention awards contain no provisions which would provide for a payout to the participant of anything other than the original number of units awarded and the associated distribution equivalents.
	The vesting period of the performance-based awards is three years. The vesting period for retention awards generally does not exceed three years; however, certain retention awards with a four-year vesting period have been granted. We settle vested non-director award grants by issuing new units, except for the associated 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. Environmental expenditures are charged to operating expense or capitalized based on the nature of the expenditures. We expense expenditures that relate to an existing condition caused by past operations that do not contribute to current or future revenue generation. 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. 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.
	The amounts recognized as provision for income taxes in our results of operations reflects 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 the limited partners' allocation of 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 our derivative hedging transactions, related amortization of realized gains/losses and adjustments to record 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 February 2013, the Financial Accounting Standards Board ("FASB") issued ASU 2013-02, Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. The amendments in ASU 2013-02 do not change the current requirements for reporting net income or other comprehensive income in financial statements. However, the amendments require an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to present, either on the face of the statement where net income is presented or in the notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under U.S. GAAP to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures required under U.S. GAAP that provide additional detail about those amounts. ASU 2013-02 became effective for annual and interim periods beginning after December 15, 2012 and was to be applied prospectively. Our adoption of this standard in the first quarter of 2013 did not have a material impact on our results of operations, financial position or cash flows.
	In December 2011, the FASB issued ASU 2011-11, Disclosures about Offsetting Assets and Liabilities. This ASU requires entities that have financial instruments and derivatives that are either: (i) offset in accordance with ASC Topic 210 or Topic 815 or (ii) are subject to an enforceable master netting arrangement or similar agreement to make additional disclosures of the gross and net amounts of those assets and liabilities, the amounts offset in accordance with ASC Topics 210 and 815, as well as qualitative disclosures of the entity's master netting arrangement or similar agreement. In January 2013, the FASB issued ASU 2013-01, Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities. The amendments in ASU 2013-01 clarify that the scope of ASU 2011-11 applies to derivatives accounted for in accordance with ASC Topic 815, Derivatives and Hedging. ASU 2011-11 must be applied retrospectively and became effective for fiscal years beginning on or after January 1, 2013. We adopted these standards in the first quarter of 2013 and their adoption 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, 2013
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(3)
	Balance, January 1, 2011	$	3,325		$	(14,421	)	$	(11,096	)
	Derivative activity:
	Net gain on cash flow hedges(1)	7,739			—			7,739
	Reclassification of net gain on cash flow hedges to income(1)	(7,903		)	—			(7,903		)
	Changes in employee benefit plan assets and benefit obligations recognized in other comprehensive income:
	Net actuarial loss(2)	—			(37,058		)	(37,058		)
	Amortization of actuarial loss(2)	—			1,591			1,591
	Amortization of prior service credit(2)	—			(544		)	(544		)
	Settlement cost(2)	—			70			70
	Balance, December 31, 2011	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 actuarial loss(2)	—			4,626			4,626
	Amortization of prior service credit(2)	—			(1,664		)	(1,664		)
	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 actuarial loss(2)	—			5,369			5,369
	Amortization of prior service credit(2)	—			(3,405		)	(3,405		)
	Balance, December 31, 2013	$	13,627		$	(33,131	)	$	(19,504	)
	(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).
	(3) Includes amounts allocated to the non-controlling owners' interest.

Consolidated_Statements_Of_Cas1

Consolidated Statements Of Cash Flows - Supplemental Disclosures (Tables)	12 Months Ended
	Dec. 31, 2013
Supplemental Cash Flow Information [Abstract]	'
Consolidated Statement Of Cash Flows	'
		Year Ended December 31,
		2011			2012			2013
	Restricted cash	$	14,379		$	—		$	—
	Trade accounts receivable and other accounts receivable	5,791			(10,867		)	(19,314		)
	Inventory	(42,452		)	36,972			34,664
	Energy commodity derivatives contracts, net of derivatives deposits	(19,782		)	16,097			534
	Accounts payable	20,226			(11,175		)	2,002
	Accrued payroll and benefits	(2,209		)	2,250			9,809
	Accrued interest payable	4,069			1,512			2,876
	Accrued taxes other than income	617			5,519			5,485
	Accrued product purchases	12,476			12,249			(9,016		)
	Deferred revenue	5,250			6,388			16,793
	Current and noncurrent environmental liabilities	16,861			(1,372		)	(12,247		)
	Other current and noncurrent assets and liabilities	(740		)	(14,874		)	(15,878		)
	Total	$	14,486		$	42,699		$	15,708

Investments_in_NonControlled_E1

Investments in Non-Controlled Entities Investments in Non-Controlled Entities (Tables)	12 Months Ended
	Dec. 31, 2013
Equity Method Investments and Joint Ventures [Abstract]	'
Equity Method Investments [Table Text Block]	'
	A summary of our investments in non-controlled entities follows (in thousands):
		Texas Frontera		Osage			Double Eagle		BridgeTex			Consolidated
	Investment at December 31, 2012	$	15,728	$	18,888		$	40,840	$	31,900		$	107,356
	Additional investment	—		—			35,500		214,995			250,495
	Earnings (losses) of non-controlled entities:
	Proportionate share of earnings (losses)	2,494		4,383			82		(20		)	6,939
	Amortization of excess investment	—		(664		)	—		—			(664		)
	Earnings (losses) of non-controlled entities	2,494		3,719			82		(20		)	6,275
	Less:
	Distributions of earnings from investments in non-controlled entities	2,494		—			—		—			2,494
	Distributions in excess of earnings of non-controlled entities	780		—			—		—			780
	Investment at December 31, 2013	$	14,948	$	22,607		$	76,422	$	246,875		$	360,852

Business_Combinations_Tables

Business Combinations (Tables)	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Schedule of Business Acquisitions, by Acquisition [Table Text Block]	'
	The purchase price and initial 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 our business combination were included in our operating results since the date of acquisition through December 31, 2013 (in thousands):
	Revenue	$	12,661
	Operating profit	$	6,400
Business Acquisition, Pro Forma Information [Table Text Block]	'
	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, 2013
Inventory Disclosure [Abstract]	'
Inventory	'
		2012		2013
	Refined petroleum products	$	88,630	$	77,144
	Liquefied petroleum gases	45,657		23,476
	Transmix	63,026		72,156
	Crude oil	17,443		7,188
	Additives	7,132		7,260
	Total inventory	$	221,888	$	187,224

Product_Sales_Revenue_Tables

Product Sales Revenue (Tables)	12 Months Ended
	Dec. 31, 2013
Product Sales Revenue [Abstract]	'
Disclosure Of Product Sales Revenue	'
	For the years ended December 31, 2011, 2012 and 2013, product sales revenue included the following (in thousands):
		Year Ended December 31,
		2011			2012			2013
	Physical sale of refined products	$	870,007		$	833,581		$	755,266
	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)	(4,330		)	(30,270		)	(10,586		)
	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)	(11,149		)	(3,940		)	—
	Other	—			11			(11		)
	Total NYMEX contract adjustments	(15,479		)	(34,199		)	(10,597		)
	Total product sales revenue	$	854,528		$	799,382		$	744,669
	(1) The associated refined 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, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment	'
	Property, plant and equipment consisted of the following (in thousands):
		December 31,				Estimated Depreciable
		2012		2013		Lives
	Construction work-in-progress	$	247,571	$	165,129
	Land and rights-of-way	83,014		78,405
	Carrier property	1,835,265		2,135,905		7 to 59 years
	Buildings	37,672		41,383		20 to 55 years
	Storage tanks	975,277		1,141,271		10 to 40 years
	Pipeline and station equipment	479,531		593,396		3 to 59 years
	Processing equipment	645,140		716,103		3 to 56 years
	Other	105,080		115,158		3 to 48 years
	Property, Plant and Equipment, Gross	$	4,408,550	$	4,986,750

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2013
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, 2012 and 2013 (in thousands):
			Pension Benefits							Other Postretirement
										Benefits
			2012				2013			2012				2013
	Change in benefit obligation:
	Benefit obligation at beginning of year		$	113,914			$	142,703		$	23,786			$	13,195
	Service cost		12,222				13,901			396				288
	Interest cost		4,862				5,368			821				412
	Plan participants’ contributions		—				—			221				248
	Actuarial loss (gain)		15,975				(14,121		)	4,751				(2,675		)
	Benefits paid		(4,270		)		(5,541		)	(760		)		(1,050		)
	Plan amendment		—				—			(16,020		)		—
	Benefit obligation at end of year		142,703				142,310			13,195				10,418
	Change in plan assets:
	Fair value of plan assets at beginning of year		70,052				87,106			—				—
	Employer contributions		13,336				15,470			539				802
	Plan participants’ contributions		—				—			221				248
	Actual return on plan assets		7,988				3,521			—				—
	Benefits paid		(4,270		)		(5,541		)	(760		)		(1,050		)
	Fair value of plan assets at end of year		87,106				100,556			—				—
	Funded status at end of year		$	(55,597	)		$	(41,754	)	$	(13,195	)		$	(10,418	)
	Accumulated benefit obligation		$	101,233			$	103,466
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
			2012				2013			2012				2013
	Amounts recognized in consolidated balance sheet:
	Current accrued benefit cost		$	—			$	—		$	(658	)		$	(535	)
	Long-term pension and benefit cost		(55,597		)		(41,754		)	(12,537		)		(9,883		)
			(55,597		)		(41,754		)	(13,195		)		(10,418		)
	Accumulated other comprehensive loss:
	Net actuarial loss		51,899				36,151			11,418				7,708
	Prior service cost (credit)		340				33			(14,473		)		(10,761		)
			52,239				36,184			(3,055		)		(3,053		)
	Net amount recognized in consolidated balance sheet		$	(3,358	)		$	(5,570	)	$	(16,250	)		$	(13,471	)
Consolidated Net Periodic Benefit Costs	'
	Net periodic benefit expense for the years ended December 31, 2011, 2012 and 2013 were as follows (in thousands):
			Pension Benefits											Other Postretirement Benefits
			2011				2012			2013				2011			2012			2013
	Components of net periodic pension and postretirement benefit expense:
	Service cost		$	9,628			$	12,222		$	13,901			$	430		$	396		$	288
	Interest cost		4,343				4,862			5,368				999			821			412
	Expected return on plan assets		(4,357		)		(5,066		)	(6,228		)		—			—			—
	Amortization of prior service cost (credit)		307				307			307				(851		)	(1,971		)	(3,712		)
	Amortization of actuarial loss		1,424				3,605			4,334				167			1,021			1,035
	Settlement cost		70				—			—				—			—			—
	Net periodic expense (credit)		$	11,415			$	15,930		$	17,682			$	745		$	267		$	(1,977	)
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 2012 and 2013 were as follows (in thousands):
			Pension Benefits							Other Postretirement
										Benefits
			2012				2013			2012				2013
	Other changes in plan assets and benefit obligations recognized in other comprehensive loss:
	Net actuarial loss (gain)		$	13,053			$	(11,414	)	$	4,751			$	(2,675	)
	Plan amendment		—				—			(16,020		)		—
	Amortization of actuarial loss		(3,605		)		(4,334		)	(1,021		)		(1,035		)
	Amortization of prior service credit (cost)		(307		)		(307		)	1,971				3,712
	Total recognized in other comprehensive loss		9,141				(16,055		)	(10,319		)		2
	Net periodic expense (credit)		15,930				17,682			267				(1,977		)
	Total recognized in net periodic benefit cost and other comprehensive loss		$	25,071			$	1,627		$	(10,052	)		$	(1,975	)
Weighted-Average Rate Assumptions Used For Benefit Obligations	'
	The weighted-average rate assumptions used to determine benefit obligations as of December 31, 2012 and 2013 were as follows:
			Pension Benefits				Other
							Postretirement Benefits
			2012		2013		2012		2013
	Discount rate—Salaried plan		4.00%		4.89%		n/a		n/a
	Discount rate—USW plan		3.39%		4.26%		n/a		n/a
	Discount rate—IUOE plan		3.99%		4.89%		n/a		n/a
	Discount rate—Other Postretirement Benefits		n/a		n/a		3.58%		4.52%
	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, 2011, 2012 and 2013 were as follows:
			Pension Benefits						Other
									Postretirement Benefits
			2011		2012		2013		2011	2012			2013
	Discount rate—Salaried plan		5.54%		4.39%		4.00%		n/a	n/a			n/a
	Discount rate—USW plan		5.07%		4.00%		3.39%		n/a	n/a			n/a
	Discount rate—IUOE plan		5.52%		4.37%		3.99%		n/a	n/a			n/a
	Discount rate—Other Postretirement Benefits		n/a		n/a		n/a		5.56%	3.75	%		3.58	%
	Rate of compensation increase—Salaried plan		5.00%		5.00%		5.00%		n/a	n/a			n/a
	Rate of compensation increase—USW plan		4.50%		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%		6.80%		n/a	n/a			n/a
	Expected rate of return on plan assets—USW plan		6.80%		6.80%		6.80%		n/a	n/a			n/a
	Expected rate of return on plan assets—IUOE plan		3.25%		6.80%		6.80%		n/a	n/a			n/a
Changes In Assumed Health Care Cost Trend Rates	'
	As of December 31, 2013, 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		$	39			$	35
	Change in postretirement benefit obligation		$	533			$	486
Fair Value, Assets Measured on Recurring Basis [Table Text Block]	'
	The fair value of the pension plan assets at December 31, 2012 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		$	1,726			$	1,726		$	—			$	—
	Mid-cap fund		1,708				1,708			—				—
	Large-cap fund		12,810				12,810			—				—
	International equity fund		8,019				8,019			—				—
	Fixed Income Securities(a):
	Short-term bond funds		2,824				2,824			—				—
	Intermediate-term bond funds		16,677				16,677			—				—
	Long-term investment grade bond fund		40,370				40,370			—				—
	Other:
	Short-term investment fund		2,614				2,614			—				—
	Group annuity contract		358				—			—				358
	Fair value of plan assets		$	87,106			$	86,748		$	—			$	358
	(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, 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 funds		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.
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, 2012 and 2013 were as follows (in thousands):
		2012				2013
	Beginning balance	$	400			$	358
	Actual return on plan assets:
	Relating to assets still held at the reporting date	16				(7		)
	Purchases, issuances, sales and settlements:
	Settlements	(58		)		(54		)
	Ending balance	$	358			$	297
Fair Value Of Pension Plan Assets	'
	The target allocation and actual weighted-average asset allocation percentages at December 31, 2012 and 2013 were as follows:
			2012				2013
			Actual(a)		Target		Actual(a)		Target
	Equity securities		28%		30%		35%		30%
	Debt securities		69%		67%		62%		67%
	Other		3%		3%		3%		3%
	(a)	Cash contributions of $13.3 million and $15.5 million were made to the pension plans during 2012 and 2013, respectively. Amounts contributed in 2012 and 2013 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, 2012 and 2013 scheduled for investment in accordance with the target. Excluding these uninvested cash amounts, the actual allocation percentages at December 31, 2012 would have been 29% equity securities and 71% debt securities and at December 31, 2013, would have been 36% equity securities and 64% debt securities. In 2014, 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, 2013, the benefit amounts we expect to pay through December 31, 2023 were as follows (in thousands):
			Pension				Other
			Benefits				Postretirement
							Benefits
	2014		$	5,207			$	535
	2015		$	5,507			$	590
	2016		$	6,282			$	578
	2017		$	9,267			$	627
	2018		$	9,032			$	665
	2019 through 2023		$	58,108			$	4,205

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Consolidated Debt	'
							Weighted-Average Interest Rate at December 31, 2013 (a)
			December 31,
			2012		2013
	Revolving credit facility		$	—	$	—	—%
	$250.0 million of 6.45% Notes due 2014		249,905		249,971		6.30%
	$250.0 million of 5.65% Notes due 2016		251,609		251,183		5.70%
	$250.0 million of 6.40% Notes due 2018		261,411		259,346		5.40%
	$550.0 million of 6.55% Notes due 2019		575,065		571,515		5.70%
	$550.0 million of 4.25% Notes due 2021		558,088		557,213		4.00%
	$250.0 million of 6.40% Notes due 2037		248,981		248,998		6.40%
	$250.0 million of 4.20% Notes due 2042		248,349		248,377		4.20%
	$300.0 million of 5.15% Notes due 2043		—		298,684		5.20%
	Total debt		$	2,393,408	$	2,685,287	5.20%
	(a)	Weighted-average interest rate includes the amortization/accretion of discounts and premiums and the amortization/accretion of gains and losses realized on historical cash flow and fair value hedges on interest expense.

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule Of Forward Purchase And Sales Contracts	'
	As of December 31, 2013, we had commitments under these forward purchase and sale contracts as follows (in millions):
		Notional Value				Barrels
	Forward purchase contracts	$	122.8			2
	Forward sale contracts	$	64.2			0.6
Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements	'
	As outlined in the table below, our open NYMEX contracts and butane futures agreements at December 31, 2013 were as follows:
	Type of Contract/Accounting Methodology		Product Represented by the Contract and Associated Barrels		Maturity Dates
	NYMEX - Fair Value Hedges		0.7 million barrels of crude oil		Between January 2014 and November 2016
	NYMEX - Economic Hedges		2.2 million barrels of refined products and crude oil		Between January and April 2014
	Butane Futures Agreements - Economic Hedges		0.1 million barrels of butane		Between January and April 2014
Derivatives and Offset Amounts [Table Text Block]	'
	A schedule of the derivative amounts we have offset and the deposit amounts we could offset under a master netting arrangement are provided below as of December 31, 2012 and 2013 (in thousands):
			31-Dec-12
	Description		Gross Amounts of Liabilities				Gross Amounts of Assets				Net Amounts of Liabilities Presented in the Consolidated Balance Sheet				Margin Deposit Amounts Not Offset in the Consolidated Balance Sheet		Net Amount
	Energy commodity derivatives		$	(9,388	)		$	2,050			$	(7,338	)		$	18,304	$	10,966
			31-Dec-13
	Description		Gross Amounts of 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 Amount
	Energy commodity derivatives		$	(7,167	)		$	2,665			$	(4,502	)		$	14,782	$	10,280
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 and 2013 of the effective portion of derivatives accounted for under ASC 815-30, Derivatives and Hedging—Cash Flow Hedges, that were designated as hedging instruments (in thousands). 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
	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
	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	)
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 and 2013 of derivatives accounted for under ASC 815-10-35; Derivatives and Hedging—Overall—Subsequent Measurement, that were not designated as hedging instruments (in thousands):
					Amount of Gain (Loss)
					Recognized on Derivative
					Year Ended December 31,
	Derivative Instrument		Location of Gain (Loss)		2012				2013
			Recognized on Derivative
	NYMEX commodity contracts		Product sales revenue		$	(36,959	)		$	(6,189	)
	NYMEX commodity contracts		Operating expenses		(2,055		)		(3,770		)
	Butane futures agreements		Cost of product sales		1,203				2,682
			Total		$	(37,811	)		$	(7,277	)
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, 2012 and 2013 (in thousands):
			December 31, 2012
			Asset Derivatives						Liability Derivatives
	Derivative Instrument		Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
	NYMEX commodity contracts		Energy commodity derivatives contracts, net		$	473			Energy commodity derivatives contracts, net		$	207
			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
Derivatives And Hedging-Nondesignated	'
	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, 2012 and 2013 (in thousands):
			December 31, 2012
			Asset Derivatives						Liability Derivatives
	Derivative Instrument		Balance Sheet Location		Fair Value				Balance Sheet Location		Fair Value
	NYMEX commodity contracts		Energy commodity derivatives contracts, net		$	227			Energy commodity derivatives contracts, net		$	8,954
	Butane futures agreements		Energy commodity derivatives contracts, net		1,350				Energy commodity derivatives contracts, net		227
			Total		$	1,577			Total		$	9,181
			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

Leases_Tables

Leases (Tables)	12 Months Ended
	Dec. 31, 2013
Leases [Abstract]	'
Lessee, Future Minimum Rental Payments	'
	2014	$	16.2
	2015	16.5
	2016	16.1
	2017	16.6
	2018	13.1
	Thereafter	51.5
	Total	$	130
Lessor, Future Minimum Payments Receivable	'
	2014	$	240.8
	2015	229.7
	2016	174.6
	2017	111.7
	2018	71.3
	Thereafter	170.5
	Total	$	998.6

LongTerm_Incentive_Plan_Tables

Long-Term Incentive Plan (Tables)	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Changes In Non-Vested Unit Awards	'
			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 - 1/1/2013		444,090			$	31.24			58,802			$	24.6			111,025			$	43.19			613,917			$	32.77
	Units granted during 2013		182,798			$	51.49			22,668			$	53.02			45,700			$	51.49			251,166			$	51.63
	Units vested during 2013		(228,058	)		$	29.07			(2,207	)		$	34.02			(57,015	)		$	63.27			(287,280	)		$	35.9
	Units forfeited during 2013		(9,420	)		$	35.98			(4,052	)		$	25			(2,355	)		$	63.27			(15,827	)		$	37.23
	Non-vested units - 12/31/13		389,410			$	41.9			75,211			$	32.87			97,355			$	63.27			561,976			$	44.4
Total Non-Vested Unit Awards	'
	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:
	2012 Awards	267,322			39,225			228,097			456,194			12/31/14		$	6
	2013 Awards	228,498			31,869			147,472			344,101			12/31/15		12.4
	Retention Awards:
	2014 Vesting Date	71,849			10,778			—			61,071			12/31/14		0.7
	2015 Vesting Date	444			22			—			422			12/31/15		—
	2016 Vesting Date	13,300			665			—			12,635			12/31/16		0.7
	Total	581,413			82,559			375,569			874,423					$	19.8
	(a) Unrecognized compensation expense will be recognized over the remaining vesting period of the awards.
Weighted-Average Grant Date Fair Values	'
			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 2011		281,180			$	28.52			59,880			$	23.96			70,296			$	34.32
	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
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, 2013. 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
	12/31/11		1,100,276			$	16.5			$	37.9
	12/31/12		751,237			$	17.1			$	32.5
	12/31/13		572,353			$	20.5			$	36.2
	* Represents the amount of the equity-based liabilities settled in January of the year following the vesting date.
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-11		505,492			$	7.4			$	0.9			$	8.3
	Jan-12		722,766			$	13			$	1.3			$	14.3
	Jan-13		476,682			$	12.3			$	1.1			$	13.4
Equity-Based Incentive Compensation Expense	'
	Equity-based incentive compensation expense, excluding amounts for directors (discussed below), for 2011, 2012 and 2013 was as follows (in thousands):
		Year Ended December 31, 2011												Year Ended December 31, 2012												Year Ended December 31, 2013
		Equity				Liability				Total				Equity				Liability				Total				Equity			Liability		Total
		Method				Method								Method				Method								Method			Method
	2009 awards	$	4,418			$	4,264			$	8,682			$	—			$	—			$	—			$	—		$	—	$	—
	2010 awards	3,100				1,562				4,662				4,937				3,723				8,660				121			73		194
	2011 awards	2,839				841				3,680				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
	2013 awards	—				—				—				—				—				—				4,726			1,451		6,177
	Retention awards	686				—				686				693				—				693				575			—		575
	Total	$	11,043			$	6,667			$	17,710			$	14,118			$	6,918			$	21,036			$	15,532		$	8,551	$	24,083
	Allocation of LTIP expense on our consolidated statements of income:
	G&A expense									$	16,024											$	18,587								$	23,264
	Operating expense									1,686												2,449									819
	Total									$	17,710											$	21,036								$	24,083
Director Equity-Based Compensation Expense	'
			Year Ended December 31,
			2011				2012				2013
	Phantom units earned pursuant to the LTIP		20,284				20,054				16,424
	(in thousands)
	Compensation - phantom unit expense		$	446			$	523			$	533
	Distribution equivalents		139				195				267
	Changes in market value of phantom units		568				973				2,535
	Total value of phantom units		1,153				1,691				3,335
	Compensation paid in cash		292				345				422
	Compensation paid in our limited partner units		140				170				85
	Total director compensation		1,585				2,206				3,842
	Distribution equivalents charged to partners' capital		(139		)		(195		)		(267		)
	Total director compensation expense		$	1,446			$	2,011			$	3,575

Segment_Disclosures_Tables

Segment Disclosures (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segment Reporting Information By Segment	'
		Year Ended December 31, 2011
		Refined Products		Crude Oil			Marine Storage			Intersegment			Total
										Eliminations
		(in thousands)
	Transportation and terminals revenue	$	680,235	$	61,205		$	151,929		$	—		$	893,369
	Product sales revenue	848,902		591			5,035			—			854,528
	Affiliate management fee revenue	—		770			—			—			770
	Total revenue	1,529,137		62,566			156,964			—			1,748,667
	Operating expenses	250,794		(4,898		)	63,438			(2,919		)	306,415
	Cost of product sales	704,313		—			1,957			—			706,270
	Earnings of non-controlled entities	—		(6,761		)	(2		)	—			(6,763		)
	Operating margin	574,030		74,225			91,571			2,919			742,745
	Depreciation and amortization expense	81,876		10,303			26,081			2,919			121,179
	G&A expenses	80,746		1,773			16,150			—			98,669
	Operating profit	$	411,408	$	62,149		$	49,340		$	—		$	522,897
	Additions to long-lived assets	$	130,645	$	45,124		$	38,125					$	213,894
		As of December 31, 2011
	Segment assets	$	2,736,522	$	432,073		$	638,451					$	3,807,046
	Corporate assets												237,955
	Total assets												$	4,045,001
	Goodwill	$	38,369	$	12,082		$	2,809					$	53,260
	Investments in non-controlled entities	$	—	$	24,936		$	10,658					$	35,594
		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

Quarterly_Financial_Data_Table

Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Quarterly Financial Data	'
	Summarized quarterly financial data is as follows (in thousands, except per unit amounts):
	2012	First		Second		Third		Fourth
		Quarter		Quarter		Quarter		Quarter
	Revenue	$	493,483	$	449,527	$	325,869	$	503,195
	Total costs and expenses	$	372,318	$	283,724	$	248,334	$	318,601
	Operating margin	$	178,067	$	224,181	$	138,527	$	248,698
	Net income	$	93,524	$	137,821	$	50,522	$	153,803
	Basic and diluted net income per limited partner unit	$	0.41	$	0.61	$	0.22	$	0.68
	2013
	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

Fair_Value_Disclosures_Tables

Fair Value Disclosures (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Recurring Fair Value Measurements Of Our Commodity Contracts And Interest Rate Swaps	'
	The carrying values of cash and cash equivalents (classified as Level 1) and energy commodity derivatives deposits approximate fair value because of the short-term nature or variable rates of these instruments; therefore, these items are not presented in the following tables (in thousands):
								Fair Value Measurements as of
								December 31, 2012 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)	$	(7,338	)	$	(7,338	)	$	(7,338	)	$	—		$	—
	Long-term receivables	$	5,135		$	5,108		$	—		$	—		$	5,108
	Debt	$	(2,393,408	)	$	(2,721,985	)	$	(2,721,985	)	$	—		$	—
								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	)	$	—

Distributions_Tables

Distributions (Tables)	12 Months Ended
	Dec. 31, 2013
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 2011, 2012 and 2013 were as follows (in thousands, except per unit amount):
	Payment Date	Per Unit Cash Distribution Amount		Total Cash Distribution
	2/14/11	$	0.37875	$	85,398
	5/13/11	0.385		86,807
	8/12/11	0.3925		88,498
	11/14/11	0.4		90,189
	Total	$	1.55625	$	350,892
	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

Owners_Equity_Tables

Owners' Equity (Tables)	12 Months Ended
	Dec. 31, 2013
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, 2011 through December 31, 2013:
	Limited partner units outstanding on January 1, 2011	224,962,698
	01/11—Settlement of 2008 award grants	505,492
	01/11—Other(a)	4,952
	Limited partner units outstanding on December 31, 2011	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
	(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, 2013
	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	450
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 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]	'
Storage Capacity	18,000,000
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	450
Equity Method Investment, Ownership Percentage	50.00%
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] | Cushing, Oklahoma [Member]	'
Organization and Description of Business [Line Items]	'
Leaseable Storage Capacity	10,000,000
Crude Oil Pipeline and Terminals Segment [Member] | Crude Oil Transportation Services [Member]	'
Organization and Description of Business [Line Items]	'
Pipeline, Length	1,100
Crude Oil Pipeline and Terminals Segment [Member] | Crude Oil Transportation Services [Member] | Crane, Texas [Member]	'
Organization and Description of Business [Line Items]	'
Pipeline, Length	450
Crude Oil Pipeline and Terminals Segment [Member] | Crude Oil Transportation Services [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 $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	number_of_equity_investment
Summary of Significant Accounting Policies [Line Items]	'	'	'
Deferred Cost Multiplier	0.5	'	'
Number of equity method ownership interests of 50% or less	4	'	'
Anticipated tank liner replacements	$4,200,000	'	'
Equity investments, unamortized excess net investment	15,100,000	15,800,000	'
Goodwill	53,260,000	53,260,000	53,260,000
Goodwill, Impaired, Method for Fair Value Determination, Time Horizon	'20 years	'	'
Goodwill, Impaired, Method for Fair Value Determination, Operating Margin Growth	2.50%	'	'
Goodwill, Impaired, Method for Fair Value Determination, Maint Capital Growth	2.50%	'	'
Goodwill, Impaired, Method for Fair Value Determination	11	'	'
Intangible asset estimated useful life	'7 years	'	'
Other intangible assets, amortization	6,000,000	1,900,000	2,800,000
Tank bottom inventory	61,915,000	58,493,000	'
Interest capitalization threshold for construction in process	500,000	'	'
Paid-time off liabilities	14,300,000	12,800,000	'
Equity-based compensation, award payout percentage, minimum	0.00%	'	'
Equity-based compensation, award payout percentage, maximum	250.00%	'	'
Equity-based compensation, award payout, potential fluctuation in the payout amount of limited partner units awarded	20.00%	'	'
Fully Amortized Intangible Asset	13,900,000	'	'
Refined Products Segment [Member]	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'
Goodwill	38,400,000	'	'
Crude Oil Pipeline and Terminals Segment [Member]	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'
Goodwill	12,100,000	'	'
Marine Storage Segment [Member]	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'
Goodwill	2,800,000	'	'
Other Inventory, Noncurrent [Member]	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'
Tank bottom inventory, barrels	700,000	'	'
Fair value hedges against price changes in tank bottom inventory, barrels	700,000	'	'
Minimum [Member]	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'
Goodwill, Impaired, Method for Fair Value Determination, Market, Times Earnings	11	'	'
Intangible asset estimated useful life	'5 years	'	'
Maximum [Member]	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'
Goodwill, Impaired, Method for Fair Value Determination, Market, Times Earnings	14	'	'
Intangible asset estimated useful life	'25 years	'	'
Performance-Based Awards [Member]	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	'3 years	'	'
Retention Awards [Member] | Maximum [Member]	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'
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	600,000
Fair Value Hedging [Member] | Commodity Contract [Member]	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'
Unrealized (Gain) Loss From Fair Value Hedge Agreements	8,700,000	5,700,000	'
Fair Value Hedging [Member] | Commodity Contract [Member] | Other Noncurrent Assets [Member]	'	'	'
Summary of Significant Accounting Policies [Line Items]	'	'	'
Unrealized (Gain) Loss From Fair Value Hedge Agreements	$8,900,000	$5,500,000	'

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, 2013		Dec. 31, 2012		Dec. 31, 2011
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'
Balance, Beginning	($35,058)	[1]	($47,201)	[1]	($11,096)	[1]
Net gain (loss) on cash flow hedges(1)	-4,744	[1],[2]	13,889	[1],[2]	7,739	[1],[2]
Reclassification of net loss (gain) on cash flow hedges to income(1)	4,245	[1],[2]	-2,924	[1],[2]	-7,903	[1],[2]
Net actuarial loss(2)	14,089	[1],[3]	-17,804	[1],[3]	-37,058	[1],[3]
Plan amendment	0	[3]	16,020	[1],[3]	0	[3]
Amortization of actuarial loss(2)	5,369	[1],[3]	4,626	[1],[3]	1,591	[1],[3]
Amortization of prior service credit(2)	-3,405	[1],[3]	-1,664	[1],[3]	-544	[1],[3]
Settlement cost(2)	0	[3]	0	[3]	70	[1],[3]
Balance, Ending	-19,504	[1]	-35,058	[1]	-47,201	[1]
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]	'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'
Balance, Beginning	14,126		3,161		3,325
Net gain (loss) on cash flow hedges(1)	-4,744	[4]	13,889	[4]	7,739	[4]
Reclassification of net loss (gain) on cash flow hedges to income(1)	4,245	[4]	-2,924	[4]	-7,903	[4]
Balance, Ending	13,627		14,126		3,161
Accumulated Defined Benefit Plans Adjustment [Member]	'		'		'
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]	'		'		'
Balance, Beginning	-49,184		-50,362		-14,421
Net actuarial loss(2)	14,089	[5]	-17,804	[5]	-37,058	[5]
Plan amendment	'		16,020	[5]	'
Amortization of actuarial loss(2)	5,369	[5]	4,626	[5]	1,591	[5]
Amortization of prior service credit(2)	-3,405	[5]	-1,664	[5]	-544	[5]
Settlement cost(2)	'		'		70	[5]
Balance, Ending	($33,131)		($49,184)		($50,362)
[1]	Includes amounts allocated to the non-controlling owners' interest.
[2]	(1) See Note 13–Derivative Financial Instruments for details of the amount of gain/loss recognized in AOCL on derivatives and the amount of gain/loss reclassified from AOCL into income.
[3]	(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).
[4]	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.
[5]	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_Cas2

Consolidated Statements Of Cash Flows - Supplemental Disclosures (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Supplemental Cash Flow Information [Abstract]	'	'	'
Increase (decrease) in long-term pension and benefits liability	($14.10)	$1.80	$37.10

Consolidated_Statements_Of_Cas3

Consolidated Statements Of Cash Flows - Supplemental Disclosures (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Supplemental Cash Flow Information [Abstract]	'	'	'
Restricted cash	$0	$0	$14,379
Trade accounts receivable and other accounts receivable	-19,314	-10,867	5,791
Inventory	34,664	36,972	-42,452
Increase (Decrease) in Commodity Contract Assets and Liabilities	534	16,097	-19,782
Accounts payable	2,002	-11,175	20,226
Accrued payroll and benefits	9,809	2,250	-2,209
Accrued interest payable	2,876	1,512	4,069
Accrued taxes other than income	5,485	5,519	617
Accrued product purchases	-9,016	12,249	12,476
Increase (Decrease) in Deferred Revenue	16,793	6,388	5,250
Current and noncurrent environmental liabilities	-12,247	-1,372	16,861
Other current and noncurrent assets and liabilities	-15,878	-14,874	-740
Changes in components of operating assets and liabilities	$15,708	$42,699	$14,486

Investments_in_NonControlled_E2

Investments in Non-Controlled Entities Investments in Non-Controlled Entities (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Change in Equity Method Investments [Roll Forward]	'	'	'
Equity Method Investments, Beginning Balance	$107,356,000	$35,594,000	'
Payments to Acquire Equity Method Investments	250,495,000	74,934,000	8,094,000
Proportionate Share of Equity Earnings	6,939,000	'	'
Amortization of Excess Investment	-664,000	'	'
Income (Loss) from Equity Method Investments	6,275,000	2,961,000	6,763,000
Distributions from investments in non-controlled entities	2,494,000	2,961,000	5,598,000
Distributions in excess of earnings of non-controlled entities	780,000	4,832,000	0
Equity Method Investments, Ending Balance	360,852,000	107,356,000	35,594,000
Equity Method Investments Unamortized Excess Investment Net	15,100,000	15,800,000	'
Marine Storage Segment [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Storage Capacity	26,000,000	'	'
Crude Oil Pipeline and Terminals Segment [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Storage Capacity	18,000,000	'	'
Texas Frontera Llc [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investment, Ownership Percentage	50.00%	'	'
Storage Capacity	1,000,000	'	'
Texas Frontera Llc [Member] | Marine Storage Segment [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investment, Ownership Percentage	50.00%	'	'
Storage Capacity	1,000,000	'	'
Change in Equity Method Investments [Roll Forward]	'	'	'
Equity Method Investments, Beginning Balance	15,728,000	'	'
Payments to Acquire Equity Method Investments	0	'	'
Proportionate Share of Equity Earnings	2,494,000	'	'
Amortization of Excess Investment	0	'	'
Income (Loss) from Equity Method Investments	2,494,000	'	'
Distributions from investments in non-controlled entities	2,494,000	'	'
Distributions in excess of earnings of non-controlled entities	780,000	'	'
Equity Method Investments, Ending Balance	14,948,000	'	'
Osage Pipeline Co [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investment, Ownership Percentage	50.00%	'	'
Pipeline, Length	135	'	'
Osage Pipeline Co [Member] | Crude Oil Pipeline and Terminals Segment [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investment, Ownership Percentage	50.00%	'	'
Pipeline, Length	135	'	'
Change in Equity Method Investments [Roll Forward]	'	'	'
Equity Method Investments, Beginning Balance	18,888,000	'	'
Payments to Acquire Equity Method Investments	0	'	'
Proportionate Share of Equity Earnings	4,383,000	'	'
Amortization of Excess Investment	-664,000	'	'
Income (Loss) from Equity Method Investments	3,719,000	'	'
Distributions from investments in non-controlled entities	0	'	'
Distributions in excess of earnings of non-controlled entities	0	'	'
Equity Method Investments, Ending Balance	22,607,000	'	'
Equity Method Investments Excess Investment Gross	21,700,000	'	'
Equity Method Investments Unamortized Excess Investment Net	15,100,000	'	'
Double Eagle Pipeline Llc [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investment, Ownership Percentage	50.00%	'	'
Pipeline, Length	195	'	'
Related Party Transaction, Other Revenues from Transactions with Related Party	1,400,000	'	'
Accounts Receivable, Related Parties, Current	200,000	'	'
Double Eagle Pipeline Llc [Member] | Crude Oil Pipeline and Terminals Segment [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investment, Ownership Percentage	50.00%	'	'
Pipeline, Length	195	'	'
Change in Equity Method Investments [Roll Forward]	'	'	'
Equity Method Investments, Beginning Balance	40,840,000	'	'
Payments to Acquire Equity Method Investments	35,500,000	'	'
Proportionate Share of Equity Earnings	82,000	'	'
Amortization of Excess Investment	0	'	'
Income (Loss) from Equity Method Investments	82,000	'	'
Distributions from investments in non-controlled entities	0	'	'
Distributions in excess of earnings of non-controlled entities	0	'	'
Equity Method Investments, Ending Balance	76,422,000	'	'
BridgeTex [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investment, Ownership Percentage	50.00%	'	'
Pipeline, Length	450	'	'
BridgeTex [Member] | Sale of Emission Reduction Credits [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Related Party Transaction, Amounts of Transaction	-4,800,000	'	'
BridgeTex [Member] | Sale of Easement Rights [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Related Party Transaction, Amounts of Transaction	-1,400,000	'	'
BridgeTex [Member] | Sale of Easement Rights [Member] | Income Statement [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Related Party Transaction, Amounts of Transaction	-700,000	'	'
BridgeTex [Member] | Sale of Easement Rights [Member] | Deferred Income [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Related Party Transaction, Amounts of Transaction	-700,000	'	'
BridgeTex [Member] | Crude Oil Pipeline and Terminals Segment [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity Method Investment, Ownership Percentage	50.00%	'	'
Pipeline, Length	450	'	'
Change in Equity Method Investments [Roll Forward]	'	'	'
Equity Method Investments, Beginning Balance	31,900,000	'	'
Payments to Acquire Equity Method Investments	214,995,000	'	'
Proportionate Share of Equity Earnings	-20,000	'	'
Amortization of Excess Investment	0	'	'
Income (Loss) from Equity Method Investments	-20,000	'	'
Distributions from investments in non-controlled entities	0	'	'
Distributions in excess of earnings of non-controlled entities	0	'	'
Equity Method Investments, Ending Balance	$246,875,000	'	'

Business_Combinations_Narrativ

Business Combinations (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Business Acquisition [Line Items]	'	'	'
Acquisition of business	$192,000,000	$0	$0
Business Acquisition, Transaction Costs	2,800,000	'	'
New Mexico/Texas [Member] | Plains Pipeline Acquisition [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Pipeline, Length	250	'	'
Acquisition of business	57,000,000	'	'
Rocky Mountains [Member] | Plains Pipeline Acquisition [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Pipeline, Length	550	'	'
Acquisition of business	$135,000,000	'	'
Number of Pipeline Terminals	4	'	'
Storage Capacity	1,700,000	'	'

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, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Revenues	$577,438	$443,835	$443,912	$432,421	$503,195	$325,869	$449,527	$493,483	$1,897,606	$1,772,074	$1,748,667
Operating Income (Loss)	'	'	'	'	'	'	'	'	705,056	552,058	522,897
Plains Pipeline Acquisition [Member]	'	'	'	'	'	'	'	'	'	'	'
Business 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	'	'
Plains Pipeline Acquisition [Member] | Refined Products Segment [Member]	'	'	'	'	'	'	'	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Revenues	'	'	'	'	'	'	'	'	12,661	'	'
Operating Income (Loss)	'	'	'	'	'	'	'	'	$6,400	'	'

Business_Combinations_Business

Business Combinations Business Acquisition Proforma Information (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Business Combinations [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Revenues	$577,438	$443,835	$443,912	$432,421	$503,195	$325,869	$449,527	$493,483	$1,897,606	$1,772,074	$1,748,667
Income (Loss), Including Portion Attributable to Noncontrolling Interest	190,007	125,623	153,640	112,967	153,803	50,522	137,821	93,524	582,237	435,670	413,566
Business Acquisition, Pro Forma Revenue	'	'	'	'	'	'	'	'	1,924,316	1,812,635	'
Business Acquisition, Pro Forma Net Income (Loss)	'	'	'	'	'	'	'	'	$591,377	$442,096	'

Inventory_Inventory_Details

Inventory (Inventory) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Refined petroleum products	$77,144	$88,630
Liquefied petroleum gases	23,476	45,657
Transmix	72,156	63,026
Crude oil	7,188	17,443
Additives	7,260	7,132
Total inventory	$187,224	$221,888

Product_Sales_Revenue_Disclosu

Product Sales Revenue (Disclosure Of Product Sales Revenue) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Product Sales Revenue [Line Items]	'		'		'
Physical sale of petroleum products	$755,266		$833,581		$870,007
NYMEX Adjustments Included in Product Sales	-10,597		-34,199		-15,479
Total product sales revenues	744,669		799,382		854,528
Petroleum Products Blending And Fractionation Activities [Member]	'		'		'
Product Sales Revenue [Line Items]	'		'		'
NYMEX Adjustments Included in Product Sales	-10,586	[1]	-30,270	[1]	-4,330	[1]
Houston-To-El Paso Pipeline Section Line Fill And Working Inventory [Member]	'		'		'
Product Sales Revenue [Line Items]	'		'		'
NYMEX Adjustments Included in Product Sales	0	[1]	-3,940	[1]	-11,149	[1]
Other Product Sale Revenue [Member]	'		'		'
Product Sales Revenue [Line Items]	'		'		'
NYMEX Adjustments Included in Product Sales	($11)		$11		$0
[1]	The associated refined 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, 2013	Dec. 31, 2012	Dec. 31, 2011
Property, Plant and Equipment [Line Items]	'	'	'
Property, Plant and Equipment, Gross	$4,986,750,000	$4,408,550,000	'
Depreciation expense	136,400,000	126,700,000	118,900,000
Property, Plant and Equipment, Other Types [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, Plant and Equipment, Gross	115,158,000	105,080,000	'
Capitalized Interest [Member] | Property, Plant and Equipment, Other Types [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, Plant and Equipment, Gross	$33,200,000	$24,300,000	'

Property_Plant_And_Equipment_P

Property, Plant And Equipment (Property, Plant And Equipment) (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

In Thousands, unless otherwise specified

Construction in Progress [Member]

Construction in Progress [Member]

Land [Member]

Land [Member]

Carrier Property [Member]

Carrier Property [Member]

Building and Building Improvements [Member]

Building and Building Improvements [Member]

Storage Tanks [Member]

Storage Tanks [Member]

Pipelines [Member]

Pipelines [Member]

Processing Equipment [Member]

Processing Equipment [Member]

Property, Plant and Equipment, Other Types [Member]

Property, Plant and Equipment, Other Types [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Carrier Property [Member]

Building and Building Improvements [Member]

Storage Tanks [Member]

Pipelines [Member]

Processing Equipment [Member]

Property, Plant and Equipment, Other Types [Member]

Carrier Property [Member]

Building and Building Improvements [Member]

Storage Tanks [Member]

Pipelines [Member]

Processing Equipment [Member]

Property, Plant and Equipment, Other Types [Member]

Property, Plant and Equipment [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Property, Plant and Equipment, Gross

$4,986,750

$4,408,550

$165,129

$247,571

$78,405

$83,014

$2,135,905

$1,835,265

$41,383

$37,672

$1,141,271

$975,277

$593,396

$479,531

$716,103

$645,140

$115,158

$105,080

'

'

'

'

'

'

'

'

'

'

'

'

Estimated depreciable life, years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'7 years

'20 years

'10 years

'3 years

'3 years

'3 years

'59 years

'55 years

'40 years

'59 years

'56 years

'48 years

Major_Customers_and_Concentrat1

Major Customers and Concentration Of Risks (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Concentration Risk [Line Items]	'	'	'
Number of employees	1,459	'	'
Customer Concentration Risk [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	'	14.00%	21.00%
Concentration Risk, Benchmark Percentage	10.00%	'	'
Refined Products Segment [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Number of employees	842	'	'
Refined Products Segment [Member] | Unionized Employees Concentration Risk [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	26.00%	'	'
Crude Oil Pipeline and Terminals Segment [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Number of employees	51	'	'
Crude Oil Pipeline and Terminals Segment [Member] | Unionized Employees Concentration Risk [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	0.00%	'	'
Marine Storage Segment [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Number of employees	171	'	'
Marine Storage Segment [Member] | Unionized Employees Concentration Risk [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Percentage	16.00%	'	'

Employee_Benefit_Plans_Narrati

Employee Benefit Plans (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	pension_plan
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Number of Union Pension Plans	2	'	'
Defined Benefit Plan, Fair Value of Plan Assets	$100,556,000	$87,106,000	'
Defined contribution plan, expenses	7,100,000	6,500,000	6,200,000
Defined benefit plan, assumed rate of increase in health care cost trend rate for 2013	6.00%	'	'
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	4.70%	'	'
Pension Benefits [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Accumulated Benefit Obligation	103,466,000	101,233,000	'
Defined Benefit Plan, Fair Value of Plan Assets	100,556,000	87,106,000	70,052,000
Actuarial loss	-14,121,000	15,975,000	'
Plan amendment	0	0	'
Defined Benefit Plan, Future Amortization of Gain (Loss)	2,500,000	'	'
Defined Benefit Plan, Future Amortization of Prior Service Cost (Credit)	100,000	'	'
Contributions estimated to be paid	19,800,000	'	'
Other Postretirement Benefits [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	0
Actuarial loss	-2,675,000	4,751,000	'
Plan amendment	0	16,020,000	'
Defined Benefit Plan, Future Amortization of Gain (Loss)	800,000	'	'
Defined Benefit Plan, Future Amortization of Prior Service Cost (Credit)	-3,700,000	'	'
Contributions estimated to be paid	500,000	'	'
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 Benefits [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
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, 2013	Dec. 31, 2012	Dec. 31, 2011
Change in plan assets:	'	'	'
Beginning balance	$87,106	'	'
Employer contributions	15,500	13,300	'
Fair value of plan assets at end of year	100,556	87,106	'
Pension Benefits [Member]	'	'	'
Change in benefit obligation:	'	'	'
Benefit obligation at beginning of year	142,703	113,914	'
Service cost	13,901	12,222	9,628
Interest cost	5,368	4,862	4,343
Plan participants’ contributions	0	0	'
Actuarial loss	-14,121	15,975	'
Benefits paid	-5,541	-4,270	'
Plan amendment	0	0	'
Benefit obligation at end of year	142,310	142,703	113,914
Change in plan assets:	'	'	'
Beginning balance	87,106	70,052	'
Employer contributions	15,470	13,336	'
Plan participants’ contributions	0	0	'
Actual return on plan assets	3,521	7,988	'
Benefits paid	-5,541	-4,270	'
Fair value of plan assets at end of year	100,556	87,106	70,052
Funded status at end of year	-41,754	-55,597	'
Accumulated benefit obligation	103,466	101,233	'
Other Postretirement Benefits [Member]	'	'	'
Change in benefit obligation:	'	'	'
Benefit obligation at beginning of year	13,195	23,786	'
Service cost	288	396	430
Interest cost	412	821	999
Plan participants’ contributions	248	221	'
Actuarial loss	-2,675	4,751	'
Benefits paid	-1,050	-760	'
Plan amendment	0	-16,020	'
Benefit obligation at end of year	10,418	13,195	23,786
Change in plan assets:	'	'	'
Beginning balance	0	0	'
Employer contributions	802	539	'
Plan participants’ contributions	248	221	'
Actual return on plan assets	0	0	'
Benefits paid	-1,050	-760	'
Fair value of plan assets at end of year	0	0	0
Funded status at end of year	($10,418)	($13,195)	'

Employee_Benefit_Plans_Amounts

Employee Benefit Plans (Amounts Recognized In Consolidated Balance Sheets) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Amounts recognized in consolidated balance sheet:	'	'
Long-term pension and benefit cost	($51,637)	($68,134)
Pension Benefits [Member]	'	'
Amounts recognized in consolidated balance sheet:	'	'
Current accrued benefit cost	0	0
Long-term pension and benefit cost	-41,754	-55,597
Total pension and benefit costs recognized in consolidated balance sheet	-41,754	-55,597
Accumulated other comprehensive loss:	'	'
Net actuarial loss	36,151	51,899
Prior service cost (credit)	33	340
Total pension and benefit costs included in accumulated other comprehensive loss	36,184	52,239
Net amount recognized in consolidated balance sheet	-5,570	-3,358
Other Postretirement Benefits [Member]	'	'
Amounts recognized in consolidated balance sheet:	'	'
Current accrued benefit cost	-535	-658
Long-term pension and benefit cost	-9,883	-12,537
Total pension and benefit costs recognized in consolidated balance sheet	-10,418	-13,195
Accumulated other comprehensive loss:	'	'
Net actuarial loss	7,708	11,418
Prior service cost (credit)	-10,761	-14,473
Total pension and benefit costs included in accumulated other comprehensive loss	-3,053	-3,055
Net amount recognized in consolidated balance sheet	($13,471)	($16,250)

Employee_Benefit_Plans_Consoli

Employee Benefit Plans (Consolidated Net Periodic Benefit Costs) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pension Benefits [Member]	'	'	'
Components of net periodic pension and postretirement benefit expense:	'	'	'
Service cost	$13,901	$12,222	$9,628
Interest cost	5,368	4,862	4,343
Expected return on plan assets	-6,228	-5,066	-4,357
Amortization of prior service cost (credit)	307	307	307
Amortization of net actuarial loss	4,334	3,605	1,424
Settlement	0	0	70
Net periodic expense (credit)	17,682	15,930	11,415
Other Postretirement Benefits [Member]	'	'	'
Components of net periodic pension and postretirement benefit expense:	'	'	'
Service cost	288	396	430
Interest cost	412	821	999
Expected return on plan assets	0	0	0
Amortization of prior service cost (credit)	-3,712	-1,971	-851
Amortization of net actuarial loss	1,035	1,021	167
Settlement	0	0	0
Net periodic expense (credit)	($1,977)	$267	$745

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, 2013		Dec. 31, 2012		Dec. 31, 2011
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	($14,089)	[1],[2]	$17,804	[1],[2]	$37,058	[1],[2]
Plan amendment	0	[2]	-16,020	[1],[2]	0	[2]
Other Comprehensive Income (Loss), Reclassification, Pension and Other Postretirement Benefit Plans, Net Gain (Loss) Recognized in Net Periodic Benefit Cost, Net of Tax	-5,369	[1],[2]	-4,626	[1],[2]	-1,591	[1],[2]
Amortization of prior service (credit) cost(2)	3,405	[1],[2]	1,664	[1],[2]	544	[1],[2]
Pension 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	-11,414		13,053		'
Plan amendment	0		0		'
Other Comprehensive Income (Loss), Reclassification, Pension and Other Postretirement Benefit Plans, Net Gain (Loss) Recognized in Net Periodic Benefit Cost, Net of Tax	-4,334		-3,605		'
Amortization of prior service (credit) cost(2)	-307		-307		'
Other Comprehensive Income (Loss) Employee Benefit Plans	-16,055		9,141		'
Net periodic expense (credit)	17,682		15,930		11,415
Total recognized in net periodic benefit cost and other comprehensive loss	1,627		25,071		'
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	-2,675		4,751		'
Plan amendment	0		-16,020		'
Other Comprehensive Income (Loss), Reclassification, Pension and Other Postretirement Benefit Plans, Net Gain (Loss) Recognized in Net Periodic Benefit Cost, Net of Tax	-1,035		-1,021		'
Amortization of prior service (credit) cost(2)	3,712		1,971		'
Other Comprehensive Income (Loss) Employee Benefit Plans	2		-10,319		'
Net periodic expense (credit)	-1,977		267		745
Total recognized in net periodic benefit cost and other comprehensive loss	($1,975)		($10,052)		'
[1]	Includes amounts allocated to the non-controlling owners' interest.
[2]	(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).

Employee_Benefit_Plans_Weighte

Employee Benefit Plans (Weighted-Average Rate Assumptions Used For Benefit Obligations) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pension Benefits [Member] | Salaried Plan [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.89%	4.00%	'
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	4.00%	4.39%	5.54%
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	6.80%	6.80%	6.80%
Pension Benefits [Member] | USW Plan [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.26%	3.39%	'
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	3.39%	4.00%	5.07%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	3.50%	3.50%	4.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	6.80%	6.80%	6.80%
Pension Benefits [Member] | IUOE Plan [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.89%	3.99%	'
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	3.99%	4.37%	5.52%
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	6.80%	6.80%	3.25%
Other Postretirement Benefits [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.52%	3.58%	'
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	3.58%	3.75%	5.56%

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, 2013
Compensation and Retirement Disclosure [Abstract]	'
Change in total service and interest cost components, 1% increase	$39
Change in total service and interest cost components, 1% decrease	35
Change in postretirement benefit obligation, 1% increase	533
Change in postretirement benefit obligation, 1% decrease	$486

Employee_Benefit_Plans_Fair_Va

Employee Benefit Plans (Fair Value Of Pension Plan Assets) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
In Thousands, unless otherwise specified
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets	$100,556		$87,106		'
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	100,259		86,748		'
Significant Unobservable Inputs (Level 3) [Member]	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets	297		358		'
Small-Cap Fund [Member]	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets	2,480	[1]	1,726	[1]	'
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	2,480	[1]	1,726	[1]	'
Mid-Cap Fund [Member]	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets	2,465	[1]	1,708	[1]	'
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	2,465	[1]	1,708	[1]	'
Large-Cap Fund [Member]	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets	18,642	[1]	12,810	[1]	'
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	18,642	[1]	12,810	[1]	'
International Equity Fund [Member]	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets	11,793	[1]	8,019	[1]	'
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	11,793	[1]	8,019	[1]	'
Short-Term Bond Fund [Member]	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets	3,243	[1]	2,824	[1]	'
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	3,243	[1]	2,824	[1]	'
Intermediate-Term Bond Funds [Member]	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets	12,492	[1]	16,677	[1]	'
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	12,492	[1]	16,677	[1]	'
Long-Term Investment Grade Bond Fund [Member]	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets	45,900	[1]	40,370	[1]	'
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	45,900	[1]	40,370	[1]	'
Short-Term Investment Fund [Member]	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets	3,244		2,614		'
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	3,244		2,614		'
Group Annuity Contract [Member]	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets	297		358		'
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		'
Group Annuity Contract [Member] | Significant Unobservable Inputs (Level 3) [Member]	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets	$297		$358		$400
[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) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Purchases, issuances, sales and settlements:	'	'
Fair value of plan assets at end of year	$100,556	$87,106
Significant Unobservable Inputs (Level 3) [Member]	'	'
Purchases, issuances, sales and settlements:	'	'
Fair value of plan assets at end of year	297	358
Group Annuity Contract [Member]	'	'
Purchases, issuances, sales and settlements:	'	'
Fair value of plan assets at end of year	297	358
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	358	400
Actual return on plan assets:	'	'
Relating to assets still held at the reporting date	-7	16
Purchases, issuances, sales and settlements:	'	'
Settlements	-54	-58
Fair value of plan assets at end of year	$297	$358

Employee_Benefit_Plans_Investm

Employee Benefit Plans (Investment Strategies) (Details)	12 Months Ended
	Dec. 31, 2013
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	'Seek 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	'Seek 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	'Seek 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	'Invest 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, 2013		Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]	'		'
Defined Benefit Plan, Contributions by Employer	$15,500		$13,300
Equity Securities [Member]	'		'
Defined Benefit Plan Disclosure [Line Items]	'		'
Actual plan asset allocation	35.00%	[1]	28.00%	[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]	69.00%	[1]
Target plan asset allocation	67.00%		67.00%
Cash and Cash Equivalents [Member]	'		'
Defined Benefit Plan Disclosure [Line Items]	'		'
Actual plan asset allocation	3.00%	[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	36.00%		29.00%
Pro Forma [Member] | Debt Securities [Member]	'		'
Defined Benefit Plan Disclosure [Line Items]	'		'
Actual plan asset allocation	64.00%		71.00%
[1]	Cash contributions of $13.3 million and $15.5 million were made to the pension plans during 2012 and 2013, respectively. Amounts contributed in 2012 and 2013 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, 2012 and 2013 scheduled for investment in accordance with the target. Excluding these uninvested cash amounts, the actual allocation percentages at December 31, 2012 would have been 29% equity securities and 71% debt securities and at December 31, 2013, would have been 36% equity securities and 64% debt securities. In 2014, 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, 2013
In Thousands, unless otherwise specified
Pension Benefits [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
2014	$5,207
2015	5,507
2016	6,282
2017	9,267
2018	9,032
2019 through 2023	58,108
Other Postretirement Benefits [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
2014	535
2015	590
2016	578
2017	627
2018	665
2019 through 2023	$4,205

Related_Party_Transactions_Nar

Related Party Transactions (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Targa Resource Partners L P [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Accounts Payable, Related Parties	'	$0.10	'
Related Party Transaction, Expenses from Transactions with Related Party	30.4	27.4	11.7
Consulting Fee [Member] | Consultant [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Related Party Transaction, Expenses from Transactions with Related Party	'	'	0.3
Share Based Compensation [Member] | Consultant [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Related Party Transaction, Expenses from Transactions with Related Party	'	$0.50	$2.10

Debt_Narrative_Details

Debt (Narrative) (Details) (USD $)	12 Months Ended						12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2013
				Senior Notes [Member]	Revolving Credit Facility [Member]	Revolving Credit Facility [Member]	Revolving Credit Facility [Member]	Revolving Credit Facility [Member]
				5.15% Notes Due 2043 [Member]			Maximum [Member]	Minimum [Member]
Debt Instrument [Line Items]	'	'	'	'	'	'	'	'
Debt Instrument, Face Amount	$2,700,000,000	$2,400,000,000	'	$300,000,000	'	'	'	'
Debt Instrument, Interest Rate, Stated Percentage	'	'	'	5.15%	'	'	'	'
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	250,000,000	'	'	'	'	'	'	'
Long-term Debt, Maturities, Repayments of Principal in Year Two	0	'	'	'	'	'	'	'
Long-term Debt, Maturities, Repayments of Principal in Year Three	250,000,000	'	'	'	'	'	'	'
Long-term Debt, Maturities, Repayments of Principal in Year Four	0	'	'	'	'	'	'	'
Long-term Debt, Maturities, Repayments of Principal in Year Five	250,000,000	'	'	'	'	'	'	'
Long-term Debt, Maturities, Repayments of Principal after Year Five	1,900,000,000	'	'	'	'	'	'	'
Notes At Price	'	'	'	99.60%	'	'	'	'
After Underwriting Discounts	'	'	'	295,600,000	'	'	'	'
Payments of Debt Issuance Costs	4,849,000	2,552,000	4,575,000	3,100,000	1,700,000	'	'	'
Write off of Deferred Debt Issuance Cost	'	'	'	'	200,000	'	'	'
Line of Credit Facility, Maximum Borrowing Capacity	'	'	'	'	1,000,000,000	800,000,000	'	'
Debt Instrument, Basis Spread on Variable Rate	'	'	'	'	1.13%	'	1.75%	1.00%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	'	'	'	'	0.13%	'	0.28%	0.10%
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	'	'	'
Cash Payments for Interest	$134,600,000	$123,300,000	$111,700,000	'	'	'	'	'

Debt_Consolidated_Debt_Details

Debt (Consolidated Debt) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]	'	'
Long-term Debt	$2,685,287,000	$2,393,408,000
Long-term Debt, Weighted Average Interest Rate	5.20%	'
Debt Instrument, Face Amount	2,700,000,000	2,400,000,000
Revolving Credit Facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term Debt	0	0
Long-term Debt, Weighted Average Interest Rate	0.00%	'
6.45% Notes Due 2014 [Member] | Senior Notes [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term Debt	249,971,000	249,905,000
Long-term Debt, Weighted Average Interest Rate	6.30%	'
Debt Instrument, Face Amount	250,000,000	'
Debt Instrument, Interest Rate, Stated Percentage	6.45%	'
5.65% Notes Due 2016 [Member] | Senior Notes [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term Debt	251,183,000	251,609,000
Long-term Debt, Weighted Average Interest Rate	5.70%	'
Debt Instrument, Face Amount	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	259,346,000	261,411,000
Long-term Debt, Weighted Average Interest Rate	5.40%	'
Debt Instrument, Face Amount	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	571,515,000	575,065,000
Long-term Debt, Weighted Average Interest Rate	5.70%	'
Debt Instrument, Face Amount	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	557,213,000	558,088,000
Long-term Debt, Weighted Average Interest Rate	4.00%	'
Debt Instrument, Face Amount	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	248,998,000	248,981,000
Long-term Debt, Weighted Average Interest Rate	6.40%	'
Debt Instrument, Face Amount	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	248,377,000	248,349,000
Long-term Debt, Weighted Average Interest Rate	4.20%	'
Debt Instrument, Face Amount	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	298,684,000	'
Long-term Debt, Weighted Average Interest Rate	5.20%	'
Debt Instrument, Face Amount	$300,000,000	'
Debt Instrument, Interest Rate, Stated Percentage	5.15%	'

Derivative_Financial_Instrumen2

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

12 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Oct. 03, 2013

Nov. 15, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Sep. 15, 2011

Dec. 31, 2013

Dec. 31, 2013

Commodity Contract [Member]

Commodity Contract [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Fair Value Hedging [Member]

Fair Value Hedging [Member]

Fair Value Hedging [Member]

Fair Value Hedging [Member]

Fair Value Hedging [Member]

Fair Value Hedging [Member]

Fair Value Hedging [Member]

Fair Value Hedging [Member]

Interest Expense [Member]

6.45% Notes Due 2014 [Member]

Interest Rate Contract [Member]

Interest Rate Contract [Member]

bbl

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Commodity Contract [Member]

Interest Rate Swap [Member]

Senior Notes [Member]

bbl

bbl

Other Noncurrent Assets [Member]

Other Noncurrent Assets [Member]

Other Current Assets [Member]

Other Current Assets [Member]

Derivative [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Notional Amount

'

'

'

'

'

'

'

$150,000,000

$250,000,000

'

'

'

'

'

'

'

$100,000,000

'

'

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

-4,744,000

[1],[2]

13,889,000

[1],[2]

7,739,000

[1],[2]

-4,560,000

2,912,000

-184,000

10,977,000

-200,000

11,000,000

'

'

'

'

'

'

'

'

'

'

Unrealized Gain Loss From Fair Value Hedge Agreements

'

'

'

'

'

'

'

'

'

'

-8,700,000

-5,700,000

-8,900,000

-5,500,000

200,000

-200,000

5,900,000

'

'

Debt Instrument, Face Amount

2,700,000,000

2,400,000,000

'

'

'

'

'

'

250,000,000

'

'

'

'

'

'

'

250,000,000

'

250,000,000

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

'

'

'

6.45%

'

'

'

'

'

'

'

6.40%

'

6.45%

Energy commodity derivatives deposits

14,782,000

18,304,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Nonmonetary Notional Amount

'

'

'

'

'

'

'

'

'

700,000

700,000

700,000

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$100,000

'

[1]

Includes amounts allocated to the non-controlling owners' interest.

[2]

(1) See Note 13–Derivative Financial Instruments for details of the amount of gain/loss recognized in 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, 2013
In Millions, unless otherwise specified	bbl
Forward Contracts [Member]	'
Derivative [Line Items]	'
Purchase Commitment, Remaining Minimum Amount Committed	$122.80
Barrels Accounted for Forward Purchase Contract for Product Purchases	2,000,000
Supply Commitment, Remaining Minimum Amount Committed	$64.20
Barrels Accounted for Forward Sale Contract for Product Sales	600,000

Derivative_Financial_Instrumen4

Derivative Financial Instruments (Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013
	Interest Expense [Member]	Fair Value Hedging [Member]	Fair Value Hedging [Member]	Fair Value Hedging [Member]	Economic Hedges [Member]	Economic Hedges Futures [Member]
		bbl	Commodity Contract [Member]	Commodity Contract [Member]	bbl	bbl
			bbl	bbl
Derivative [Line Items]	'	'	'	'	'	'
Derivative, Nonmonetary Notional Amount	'	700,000	700,000	700,000	2,200,000	100,000
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$0.10	'	'	'	'	'

Derivative_Financial_Instrumen5

Derivative Financial Instruments Derivative Financial Instruments (Schedule of Derivative Offset Amounts) (Details) (Exchange Traded [Member], USD $)	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Derivative [Line Items]	'		'
Derivative Liability, Fair Value, Gross Liability	($7,167)		($9,388)
Derivative Asset, Fair Value, Gross Asset	2,665		2,050
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	4,502	[1]	7,338
Derivative Liability, Fair Value of Collateral	14,782		18,304
Margin Deposit Net of Commodity Contract	10,280		10,966
Other Current Liabilities [Member]	'		'
Derivative [Line Items]	'		'
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	6,737		'
Other Noncurrent Assets [Member]	'		'
Derivative [Line Items]	'		'
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	($2,235)		'
[1]	Net amount includes energy commodity derivative contracts classified as current liabilities, net, of $6,737 and noncurrent assets of $2,235.

Derivative_Financial_Instrumen6

Derivative Financial Instruments (Derivatives And Hedging-Cash Flow Hedges) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	($4,744)	[1],[2]	$13,889	[1],[2]	$7,739	[1],[2]
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	-4,245	[1],[2]	2,924	[1],[2]	7,903	[1],[2]
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	-184		10,977		'
Interest Rate Contract [Member] | Interest Expense [Member]	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	163		164		'
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		'
Commodity Contract [Member] | Sales [Member]	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	($4,408)		$2,760		'
[1]	Includes amounts allocated to the non-controlling owners' interest.
[2]	(1) See Note 13–Derivative Financial Instruments for details of the amount of gain/loss recognized in 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) (Not Designated as Hedging Instrument [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Gain (Loss) on Derivative, Net	($7,277)	($37,811)
Sales [Member] | Commodity Contract [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Gain (Loss) on Derivative, Net	-6,189	-36,959
Operating Expenses [Member] | Commodity Contract [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Gain (Loss) on Derivative, Net	-3,770	-2,055
Cost of Sales [Member] | Butane Futures Agreements [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative, Gain (Loss) on Derivative, Net	$2,682	$1,203

Derivative_Financial_Instrumen8

Derivative Financial Instruments (Derivatives And Hedging-Designated) (Details) (Designated As Hedging Instrument [Member], USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$2,235	'
Derivative Liability, Fair Value, Gross Liability	146	'
Commodity Contract [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	0	473
Commodity Contract [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	146	207
Commodity Contract [Member] | Other Noncurrent Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	2,235	'
Commodity Contract [Member] | Other Noncurrent Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	$0	'

Derivative_Financial_Instrumen9

Derivative Financial Instruments (Derivatives And Hedging-Nondesignated) (Details) (Not Designated as Hedging Instrument [Member], USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$430	$1,577
Derivative Liability, Fair Value, Gross Liability	7,021	9,181
Commodity Contract [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	48	227
Commodity Contract [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	7,021	8,954
Butane Futures Agreements [Member] | Other Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	382	1,350
Butane Futures Agreements [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	$0	$227

Leases_Narrative_Details

Leases (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Leases [Abstract]	'	'	'
Total rent expense	$12	$4.80	$4.60

Leases_Lessee_future_minimum_r

Leases (Lessee, future minimum rental payments) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Leases [Abstract]	'
2014	$16.20
2015	16.5
2016	16.1
2017	16.6
2018	13.1
Thereafter	51.5
Total	$130

Leases_Lessor_future_minimum_p

Leases (Lessor, future minimum payments receivable) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Leases [Abstract]	'
2013	$240.80
2014	229.7
2015	174.6
2016	111.7
2017	71.3
Thereafter	170.5
Total	$998.60

LongTerm_Incentive_Plan_Narrat

Long-Term Incentive Plan (Narrative) (Details)	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Limited partners' capital account, units issued	9,400,000
Limited partner unitholders, units remaining available	1,800,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, 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%
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.

LongTerm_Incentive_Plan_Change

Long-Term Incentive Plan (Changes In Non-Vested Unit Awards) (Details) (Management [Member], USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]	'	'	'
Non-vested units - 1/1/2013	613,917	'	'
Units granted	251,166	'	'
Units vested during 2013	-287,280	'	'
Units forfeited during 2013	-15,827	'	'
Non-vested units - 12/31/13	561,976	'	'
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 - 1/1/2013	$32.77	'	'
Units granted during 2013	$51.63	'	'
Units vested during 2013	$35.90	'	'
Units forfeited during 2013	$37.23	'	'
Non-vested units - 12/31/13	$44.40	'	'
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 - 1/1/2013	111,025	'	'
Units granted	45,700	53,558	70,296
Units vested during 2013	-57,015	'	'
Units forfeited during 2013	-2,355	'	'
Non-vested units - 12/31/13	97,355	111,025	'
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 - 1/1/2013	$43.19	'	'
Units granted during 2013	$51.49	$33.57	$34.32
Units vested during 2013	$63.27	'	'
Units forfeited during 2013	$63.27	'	'
Non-vested units - 12/31/13	$63.27	$43.19	'
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 - 1/1/2013	444,090	'	'
Units granted	182,798	214,232	281,180
Units vested during 2013	-228,058	'	'
Units forfeited during 2013	-9,420	'	'
Non-vested units - 12/31/13	389,410	444,090	'
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 - 1/1/2013	$31.24	'	'
Units granted during 2013	$51.49	$33.57	$28.52
Units vested during 2013	$29.07	'	'
Units forfeited during 2013	$35.98	'	'
Non-vested units - 12/31/13	$41.90	$31.24	'
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 - 1/1/2013	58,802	'	'
Units granted	22,668	7,016	59,880
Units vested during 2013	-2,207	'	'
Units forfeited during 2013	-4,052	'	'
Non-vested units - 12/31/13	75,211	58,802	'
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 - 1/1/2013	$24.60	'	'
Units granted during 2013	$53.02	$30.54	$23.96
Units vested during 2013	$34.02	'	'
Units forfeited during 2013	$25	'	'
Non-vested units - 12/31/13	$32.87	$24.60	'

LongTerm_Incentive_Plan_Total_

Long-Term Incentive Plan (Total Non-Vested Unit Awards) (Details) (Management [Member], USD $)	Dec. 31, 2013
In Millions, except Share data, unless otherwise specified
Long Term Incentive Plan [Line Items]	'
Unit Awards Granted	581,413
Estimated Forfeitures	82,559
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results	375,569
Total Unit Award Accrual	874,423
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$19.80	[1]
2012 Awards [Member] | Performance Shares [Member]	'
Long Term Incentive Plan [Line Items]	'
Unit Awards Granted	267,322
Estimated Forfeitures	39,225
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results	228,097
Total Unit Award Accrual	456,194
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	6	[1]
2013 Awards [Member] | Performance Shares [Member]	'
Long Term Incentive Plan [Line Items]	'
Unit Awards Granted	228,498
Estimated Forfeitures	31,869
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results	147,472
Total Unit Award Accrual	344,101
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	12.4	[1]
Retention Awards Vesting 2014 [Member] | Retention Awards [Member]	'
Long Term Incentive Plan [Line Items]	'
Unit Awards Granted	71,849
Estimated Forfeitures	10,778
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results	0
Total Unit Award Accrual	61,071
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	0.7	[1]
Retention Awards Vesting 2015 [Member] | Retention Awards [Member]	'
Long Term Incentive Plan [Line Items]	'
Unit Awards Granted	444
Estimated Forfeitures	22
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results	0
Total Unit Award Accrual	422
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	0	[1]
Retention Awards Vesting 2016 [Member] | Retention Awards [Member]	'
Long Term Incentive Plan [Line Items]	'
Unit Awards Granted	13,300
Estimated Forfeitures	665
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results	0
Total Unit Award Accrual	12,635
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$0.70	[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, 2013	Dec. 31, 2012	Dec. 31, 2011
Long Term Incentive Plan [Line Items]	'	'	'
Units granted	251,166	'	'
Weighted-Average Grant Date Fair Value	$51.63	'	'
Equity Method [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Units granted	182,798	214,232	281,180
Weighted-Average Grant Date Fair Value	$51.49	$33.57	$28.52
Equity Method [Member] | Retention Awards [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Units granted	22,668	7,016	59,880
Weighted-Average Grant Date Fair Value	$53.02	$30.54	$23.96
Liability Method [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Units granted	45,700	53,558	70,296
Weighted-Average Grant Date Fair Value	$51.49	$33.57	$34.32

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, 2013		Dec. 31, 2012		Dec. 31, 2011
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	572,353		751,237		1,100,276
Fair Value of Unit Awards on Vesting Date (in millions)	$20.50	[1]	$17.10	[1]	$16.50	[1]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Vested	$36.20		$32.50		$37.90
[1]	Represents the amount of the equity-based liabilities settled in January of the year following the vesting date.

LongTerm_Incentive_Plan_Cash_F

Long-Term Incentive Plan (Cash Flow Effects Of LTIP Settlements) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Long Term Incentive Plan [Line Items]	'	'	'
Settlement of tax withholdings on long-term incentive compensation	$12,259,000	$13,001,000	$7,410,000
Management [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Partners' Capital Account, Units, Unit-based Compensation	476,682	722,766	505,492
Settlement of tax withholdings on long-term incentive compensation	12,300,000	13,000,000	7,400,000
Payments for Other Taxes	1,100,000	1,300,000	900,000
Total Cash Taxes Paid (in millions)	$13,400,000	$14,300,000	$8,300,000

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, 2013	Dec. 31, 2012	Dec. 31, 2011
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	$24,083	$21,036	$17,710
G&A Expense [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	23,264	18,587	16,024
Operating Expenses [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	819	2,449	1,686
Retention Awards [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	575	693	686
2009 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	0	0	8,682
2010 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	194	8,660	4,662
2011 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	9,639	7,156	3,680
2012 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	7,498	4,527	0
2013 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	6,177	0	0
Liability Method [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	8,551	6,918	6,667
Liability Method [Member] | 2009 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	0	0	4,264
Liability Method [Member] | 2010 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	73	3,723	1,562
Liability Method [Member] | 2011 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	4,280	2,094	841
Liability Method [Member] | 2012 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	2,747	1,101	0
Liability Method [Member] | 2013 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	1,451	0	0
Equity Method [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	15,532	14,118	11,043
Equity Method [Member] | Retention Awards [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	575	693	686
Equity Method [Member] | 2009 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	0	0	4,418
Equity Method [Member] | 2010 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	121	4,937	3,100
Equity Method [Member] | 2011 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	5,359	5,062	2,839
Equity Method [Member] | 2012 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	4,751	3,426	0
Equity Method [Member] | 2013 Awards [Member] | Performance Shares [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Allocation of LTIP expense on Consolidated Statements of Income	$4,726	$0	$0

LongTerm_Incentive_Plan_Direct

Long-Term Incentive Plan (Director Equity-Based Compensation Expense) (Details) (Director [Member], USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Director [Member]	'	'	'
Long Term Incentive Plan [Line Items]	'	'	'
Units granted	16,424	20,054	20,284
Deferred Compensation Arrangement, Compensation	$533	$523	$446
Distribution equivalents	267	195	139
Changes in market value of phantom units	2,535	973	568
Deferred Compensation Arrangement with Individual, Fair Value of Shares Issued	3,335	1,691	1,153
Compensation paid in cash	422	345	292
Director Compensation Paid in Limited Partner Units	85	170	140
Total director compensation	3,842	2,206	1,585
Deferred Compensation Arrangement with Individual, Equivalents Charged to Partners Capital	-267	-195	-139
Deferred Compensation Arrangement with Individual, Compensation Expense	$3,575	$2,011	$1,446

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, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Transportation and terminals revenue	'	'	'	'	'	'	'	'	$1,138,328	$970,744	$893,369
Product sales revenue	'	'	'	'	'	'	'	'	744,669	799,382	854,528
Affiliate management fee revenue	'	'	'	'	'	'	'	'	14,609	1,948	770
Total revenues	577,438	443,835	443,912	432,421	503,195	325,869	449,527	493,483	1,897,606	1,772,074	1,748,667
Operating expenses	'	'	'	'	'	'	'	'	346,070	328,454	306,415
Cost of product sales	'	'	'	'	'	'	'	'	578,029	657,108	706,270
Earnings of non-controlled entities	'	'	'	'	'	'	'	'	-6,275	-2,961	-6,763
Operating margin	296,335	222,649	251,905	208,893	248,698	138,527	224,181	178,067	979,782	789,473	742,745
Depreciation and amortization expense	'	'	'	'	'	'	'	'	142,230	128,012	121,179
G&A expenses	'	'	'	'	'	'	'	'	132,496	109,403	98,669
Operating profit	'	'	'	'	'	'	'	'	705,056	552,058	522,897
Payments to Acquire Property, Plant, and Equipment	'	'	'	'	'	'	'	'	383,757	354,168	199,665
Total assets	4,820,812	'	'	'	4,420,067	'	'	'	4,820,812	4,420,067	4,045,001
Goodwill	53,260	'	'	'	53,260	'	'	'	53,260	53,260	53,260
Investment in non-controlled entities	360,852	'	'	'	107,356	'	'	'	360,852	107,356	35,594
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]	'	'	'	'	'	'	'	'	'	'	'
Payments to Acquire Property, Plant, and Equipment	'	'	'	'	'	'	'	'	593,059	351,189	213,894
Total assets	4,711,495	'	'	'	4,062,630	'	'	'	4,711,495	4,062,630	3,807,046
Operating Segments [Member] | Refined Products Segment [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Transportation and terminals revenue	'	'	'	'	'	'	'	'	801,128	723,835	680,235
Product sales revenue	'	'	'	'	'	'	'	'	738,271	790,116	848,902
Affiliate management fee revenue	'	'	'	'	'	'	'	'	0	0	0
Total revenues	'	'	'	'	'	'	'	'	1,539,399	1,513,951	1,529,137
Operating expenses	'	'	'	'	'	'	'	'	270,711	267,694	250,794
Cost of product sales	'	'	'	'	'	'	'	'	574,703	653,429	704,313
Earnings of non-controlled entities	'	'	'	'	'	'	'	'	0	0	0
Operating margin	'	'	'	'	'	'	'	'	693,985	592,828	574,030
Depreciation and amortization expense	'	'	'	'	'	'	'	'	86,926	86,218	81,876
G&A expenses	'	'	'	'	'	'	'	'	91,658	87,309	80,746
Operating profit	'	'	'	'	'	'	'	'	515,401	419,301	411,408
Payments to Acquire Property, Plant, and Equipment	'	'	'	'	'	'	'	'	361,134	127,744	130,645
Total assets	2,811,398	'	'	'	2,530,770	'	'	'	2,811,398	2,530,770	2,736,522
Goodwill	38,369	'	'	'	38,369	'	'	'	38,369	38,369	38,369
Investment 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	'	'	'	'	'	'	'	'	178,409	92,288	61,205
Product sales revenue	'	'	'	'	'	'	'	'	0	0	591
Affiliate management fee revenue	'	'	'	'	'	'	'	'	13,361	1,734	770
Total revenues	'	'	'	'	'	'	'	'	191,770	94,022	62,566
Operating expenses	'	'	'	'	'	'	'	'	19,131	5,229	-4,898
Cost of product sales	'	'	'	'	'	'	'	'	0	0	0
Earnings of non-controlled entities	'	'	'	'	'	'	'	'	-3,781	-2,574	-6,761
Operating margin	'	'	'	'	'	'	'	'	176,420	91,367	74,225
Depreciation and amortization expense	'	'	'	'	'	'	'	'	24,119	12,228	10,303
G&A expenses	'	'	'	'	'	'	'	'	19,896	5,420	1,773
Operating profit	'	'	'	'	'	'	'	'	132,405	73,719	62,149
Payments to Acquire Property, Plant, and Equipment	'	'	'	'	'	'	'	'	199,362	166,960	45,124
Total assets	1,252,036	'	'	'	875,005	'	'	'	1,252,036	875,005	432,073
Goodwill	12,082	'	'	'	12,082	'	'	'	12,082	12,082	12,082
Investment in non-controlled entities	345,904	'	'	'	91,629	'	'	'	345,904	91,629	24,936
Operating Segments [Member] | Marine Storage Segment [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Transportation and terminals revenue	'	'	'	'	'	'	'	'	158,791	154,621	151,929
Product sales revenue	'	'	'	'	'	'	'	'	6,398	9,266	5,035
Affiliate management fee revenue	'	'	'	'	'	'	'	'	1,248	214	0
Total revenues	'	'	'	'	'	'	'	'	166,437	164,101	156,964
Operating expenses	'	'	'	'	'	'	'	'	59,407	58,486	63,438
Cost of product sales	'	'	'	'	'	'	'	'	3,326	3,679	1,957
Earnings of non-controlled entities	'	'	'	'	'	'	'	'	-2,494	-387	-2
Operating margin	'	'	'	'	'	'	'	'	106,198	102,323	91,571
Depreciation and amortization expense	'	'	'	'	'	'	'	'	28,006	26,611	26,081
G&A expenses	'	'	'	'	'	'	'	'	20,942	16,674	16,150
Operating profit	'	'	'	'	'	'	'	'	57,250	59,038	49,340
Payments to Acquire Property, Plant, and Equipment	'	'	'	'	'	'	'	'	32,563	56,485	38,125
Total assets	648,061	'	'	'	656,855	'	'	'	648,061	656,855	638,451
Goodwill	2,809	'	'	'	2,809	'	'	'	2,809	2,809	2,809
Investment in non-controlled entities	14,948	'	'	'	15,727	'	'	'	14,948	15,727	10,658
Corporate, Non-Segment [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Total assets	109,317	'	'	'	357,437	'	'	'	109,317	357,437	237,955
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 revenues	'	'	'	'	'	'	'	'	0	0	0
Operating expenses	'	'	'	'	'	'	'	'	-3,179	-2,955	-2,919
Cost of product sales	'	'	'	'	'	'	'	'	0	0	0
Earnings of non-controlled entities	'	'	'	'	'	'	'	'	0	0	0
Operating margin	'	'	'	'	'	'	'	'	3,179	2,955	2,919
Depreciation and amortization expense	'	'	'	'	'	'	'	'	3,179	2,955	2,919
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
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Loss Contingencies [Line Items]	'	'	'
Accrual for Environmental Loss Contingencies	$38.50	$48.30	'
Estimated Environmental Liabilities Over A Period	'10 years	'	'
Environmental Remediation Expense	-5.2	12	23.1
Recorded Third-Party Environmental Recoveries Receivable	4.8	7.9	'
Recorded Third-Party Environmental Recoveries, Amount	4.2	1.2	0.5
Texas Commission On Environmental Quality Fees [Member]	'	'	'
Loss Contingencies [Line Items]	'	'	'
Loss Contingency, Estimate of Possible Loss	'	10.9	'
Loss Contingency, Loss in Period	-10.6	'	'
Accounts Receivable [Member]	'	'	'
Loss Contingencies [Line Items]	'	'	'
Recorded Third-Party Environmental Recoveries Receivable	2.1	2.8	'
Other Noncurrent Assets [Member]	'	'	'
Loss Contingencies [Line Items]	'	'	'
Recorded Third-Party Environmental Recoveries Receivable	$2.70	$5.10	'

Quarterly_Financial_Data_Detai

Quarterly Financial Data (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Quarterly Financial Data [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Total revenues	$577,438,000	$443,835,000	$443,912,000	$432,421,000	$503,195,000	$325,869,000	$449,527,000	$493,483,000	$1,897,606,000	$1,772,074,000	$1,748,667,000
Total costs and expenses	355,081,000	291,586,000	260,191,000	291,967,000	318,601,000	248,334,000	283,724,000	372,318,000	1,198,825,000	1,222,977,000	1,232,533,000
Operating margin (loss)	296,335,000	222,649,000	251,905,000	208,893,000	248,698,000	138,527,000	224,181,000	178,067,000	979,782,000	789,473,000	742,745,000
Net income	190,007,000	125,623,000	153,640,000	112,967,000	153,803,000	50,522,000	137,821,000	93,524,000	582,237,000	435,670,000	413,566,000
Basic and diluted net income per limited partner unit	'	'	'	'	$0.68	$0.22	$0.61	$0.41	'	'	'
Basic net income per limited partner unit (in dollars per unit)	$0.84	$0.55	$0.68	$0.50	'	'	'	'	$2.57	$1.92	$1.83
Diluted net income per limited partner unit (in dollars per unit)	$0.83	$0.55	$0.68	$0.50	'	'	'	'	$2.56	$1.92	$1.83
Texas Commission On Environmental Quality Fees [Member]	'	'	'	'	'	'	'	'	'	'	'
Quarterly Financial Data [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Loss Contingency, Loss in Period	'	'	'	'	'	'	'	'	($10,600,000)	'	'

Fair_Value_Disclosures_Details

Fair Value Disclosures (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
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	$2,730	$5,135
Debt	-2,685,287	-2,393,408
Reported Value Measurement [Member] | Commodity Contract [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Energy commodity derivatives contracts (liabilities)	-4,502	-7,338
Estimate of Fair Value Measurement [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Long-term receivables	2,658	5,108
Debt	-2,815,210	-2,721,985
Estimate of Fair Value Measurement [Member] | Commodity Contract [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Energy commodity derivatives contracts (liabilities)	-4,502	-7,338
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	-2,721,985
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	-2,815,210	0
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	2,658	5,108
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]	'	'
Energy commodity derivatives contracts (liabilities)	-4,502	-7,338
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]	'	'
Energy commodity derivatives contracts (liabilities)	0	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]	'	'
Energy commodity derivatives contracts (liabilities)	$0	$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, 2013	Aug. 14, 2013	15-May-13	Feb. 14, 2013	Nov. 14, 2012	Aug. 14, 2012	15-May-12	Feb. 14, 2012	Nov. 14, 2011	Aug. 12, 2011	13-May-11	Feb. 14, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Distributions Made to Limited Liability Company (LLC) Member [Line Items]	'	'	'	'	'	'	'	'	'	'	'	'	'	'	'
Per unit cash distribution amount (in dollars per unit)	$0.56	$0.53	$0.51	$0.50	$0.49	$0.47	$0.42	$0.41	$0.40	$0.39	$0.39	$0.38	$2.10	$1.78	$1.56
Limited partner units	$126,374	$120,707	$115,040	$113,340	$109,707	$106,597	$95,004	$92,177	$90,189	$88,498	$86,807	$85,398	$475,461	$403,485	$350,892

Owners_Equity_Changes_In_Limit

Owners' Equity (Changes In Limited Partner Units Outstanding) (Details)

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Management [Member]

Management [Member]

Management [Member]

Director [Member]

Director [Member]

Director [Member]

Limited Partners' Capital Account [Roll Forward]

'

'

'

'

'

'

'

'

'

Limited partner unitholders, units outstanding

226,200,872

225,473,142

224,962,698

'

'

'

'

'

'

Partners' Capital Account, Units, Unit-based Compensation

'

'

'

476,682

722,766

505,492

1,884

[1]

4,964

[1]

4,952

[1]

Limited partner unitholders, units outstanding

226,679,438

225,473,142

224,962,698

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

[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

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

In Thousands, except Share data, unless otherwise specified

Nov. 14, 2013

Aug. 14, 2013

15-May-13

Feb. 14, 2013

Nov. 14, 2012

Aug. 14, 2012

15-May-12

Feb. 14, 2012

Nov. 14, 2011

Aug. 12, 2011

13-May-11

Feb. 14, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 14, 2014

Feb. 03, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 03, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 03, 2014

Subsequent Event [Member]

Subsequent Event [Member]

Management [Member]

Management [Member]

Management [Member]

Management [Member]

Director [Member]

Director [Member]

Director [Member]

Director [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Units granted

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

178,184

251,166

'

'

'

16,424

20,054

20,284

'

Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years

'

'

'

'

'

'

'

'

Partners' Capital Account, Units, Unit-based Compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

388,819

476,682

722,766

505,492

387,216

1,884

[1]

4,964

[1]

4,952

[1]

1,603

Cash distribution per limited partner unit

$0.56

$0.53

$0.51

$0.50

$0.49

$0.47

$0.42

$0.41

$0.40

$0.39

$0.39

$0.38

$2.10

$1.78

$1.56

$0.59

'

'

'

'

'

'

'

'

'

Total cash distributions

$126,374

$120,707

$115,040

$113,340

$109,707

$106,597

$95,004

$92,177

$90,189

$88,498

$86,807

$85,398

$475,461

$403,485

$350,892

$132,800

'

'

'

'

'

'

'

'

'

[1]

Limited partner units issued to settle the equity-based retainer paid to independent directors of our general partner.