Magellan Midstream Partners (MMP) 10-K 16 Feb 18 2017 FY Annual report Financial data

Document And Entity Information

Document And Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2017	Feb. 15, 2018	Jun. 30, 2017
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2017
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	FY
Entity Registrant Name	MAGELLAN MIDSTREAM PARTNERS LP
Entity Central Index Key	1,126,975
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		228,195,160
Entity Public Float			$ 16,213,584,044
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Well-known Seasoned Issuer	Yes

Consolidated Statements Of Inco

Consolidated Statements Of Income - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Statement [Abstract]
Transportation and terminals revenue	$ 1,731,775	$ 1,591,119	$ 1,544,746
Product sales revenue	758,206	599,602	629,836
Affiliate management fee revenue	17,680	14,689	13,871
Total revenue	2,507,661	2,205,410	2,188,453
Costs and expenses:
Operating	577,978	528,672	523,650
Cost of product sales	635,617	493,338	447,273
Depreciation and amortization	196,630	178,142	166,812
General and administrative	165,717	147,165	149,948
Total costs and expenses	1,575,942	1,347,317	1,287,683
Earnings of non-controlled entities	120,994	78,696	66,483
Operating profit	1,052,713	936,789	967,253
Interest expense	210,698	194,187	158,895
Interest capitalized	(15,565)	(27,375)	(14,442)
Interest income	(1,415)	(1,402)	(1,276)
Gain on sale of asset	(18,505)	0	0
Gain on exchange of interest in non-controlled entity	0	(28,144)	0
Other (income) expense	4,139	(6,466)	2,618
Income before provision for income taxes	873,361	805,989	821,458
Provision for income taxes	3,830	3,218	2,336
Net income	$ 869,531	$ 802,771	$ 819,122
Basic net income per limited partner unit (in dollars per unit)	$ 3.81	$ 3.52	$ 3.60
Diluted net income per limited partner unit (in dollars per unit)	$ 3.81	$ 3.52	$ 3.59
Weighted average number of limited partner units outstanding used for basic net income per unit calculation (in units)	228,176	227,926	227,550
Weighted average number of limited partner units outstanding used for diluted net income per unit calculation (in units)	228,338	228,057	227,888

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017		Dec. 31, 2016	Dec. 31, 2015
Statement of Comprehensive Income [Abstract]
Net income	$ 869,531		$ 802,771	$ 819,122
Other comprehensive income:
Net loss on cash flow hedges(1)	(1,937)	[1]	(6,699)	(14,904)
Reclassification of net loss (gain) on cash flow hedges to income(1)	2,958	[1]	2,049	1,365
Net actuarial loss(2)	(46,008)	[2]	(2,452)	(8,359)
Plan amendment(2)	0	[2]	0	3,610
Amortization of prior service credit(2)	(181)	[2]	(3,516)	(3,713)
Amortization of actuarial loss(2)	6,371	[2]	5,525	7,191
Settlement cost(2)	2,460	[2]	202	0
Total other comprehensive loss	(36,337)		(4,891)	(14,810)
Comprehensive income	$ 833,194		$ 797,880	$ 804,312
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[2]	{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmI4ZWY2YmRkMDE5ZjRhMTFiODJmNTYxMDNiZTMwMmU3fFRleHRTZWxlY3Rpb246QUZBQjQxRkI1MzUxRjY2NDY5QkU1MjlEODQ3Qjk0MjUM}

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 176,068	$ 14,701
Trade accounts receivable	138,779	105,689
Other accounts receivable	14,561	25,761
Inventory	182,345	134,378
Energy commodity derivatives deposits	36,690	49,899
Other current assets	63,396	39,966
Total current assets	611,839	370,394
Property, plant and equipment	7,235,468	6,783,737
Less: accumulated depreciation	1,682,633	1,507,996
Net property, plant and equipment	5,552,835	5,275,741
Investments in non-controlled entities	1,082,511	931,255
Long-term receivables	27,676	23,870
Goodwill	53,260	53,260
Other intangibles (less accumulated amortization of $2,136 and $1,389 at December 31, 2016 and 2017, respectively)	52,764	51,976
Other noncurrent assets	13,490	65,577
Total assets	7,394,375	6,772,073
Current liabilities:
Accounts payable	104,852	77,248
Accrued payroll and benefits	56,261	45,690
Accrued interest payable	70,657	65,643
Accrued taxes other than income	51,343	50,166
Environmental liabilities	6,235	10,249
Deferred revenue	117,795	101,891
Accrued product purchases	96,159	51,600
Energy commodity derivatives contracts, net	25,694	30,738
Current portion of long-term debt, net	250,974	0
Other current liabilities	56,540	48,431
Total current liabilities	836,510	481,656
Long-term debt	4,273,518	4,087,192
Long-term pension and benefits	111,305	71,461
Other noncurrent liabilities	30,350	25,868
Environmental liabilities	13,039	13,791
Commitments and contingencies
Partners' capital:
Limited partner unitholders (227,784 units and 228,025 units outstanding at December 31, 2016 and 2017, respectively)	2,267,231	2,193,346
Accumulated other comprehensive loss	(137,578)	(101,241)
Total partners’ capital	2,129,653	2,092,105
Total liabilities and partners' capital	$ 7,394,375	$ 6,772,073

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Statement of Financial Position [Abstract]
Other intangibles, accumulated amortization	$ 1,389	$ 2,136
Limited partner unitholders, units outstanding	228,024,556	227,783,916

Consolidated Statments of Cash

Consolidated Statments of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017		Dec. 31, 2016	Dec. 31, 2015
Operating Activities:
Net income	$ 869,531		$ 802,771	$ 819,122
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	196,630		178,142	166,812
Loss (gain) on sale and retirement of assets	(5,135)		11,190	7,871
Earnings of non-controlled entities	(120,994)		(78,696)	(66,483)
Distributions from investments in non-controlled entities	123,660		78,723	66,285
Equity-based incentive compensation expense	20,641		19,358	24,245
Settlement cost, amortization of prior service credit and actuarial loss	8,650		2,211	3,478
Gain on exchange of interest in non-controlled entity	0		(28,144)	0
Changes in components of operating assets and liabilities (Note 3)	15,695		(21,515)	48,362
Net cash provided by operating activities	1,108,678		964,040	1,069,692
Investing Activities:
Additions to property, plant and equipment	(558,669)		(674,159)	(621,151)
Proceeds from sale and disposition of assets	44,392		7,552	3,371
Acquisition of business	0		0	(54,678)
Investments in non-controlled entities	(134,828)		(200,023)	(152,466)
Distributions in excess of earnings of non-controlled entities	78,482	[1]	9,264	14,155
Net cash used by investing activities	(570,623)		(857,366)	(810,769)
Financing Activities:
Distributions paid	(803,216)		(739,157)	(662,948)
Net commercial paper repayments	(49,986)		(229,975)	(16,981)
Borrowings under long-term notes	496,705		1,142,997	499,589
Payments on notes	0		(250,000)	0
Debt placement costs	(6,316)		(10,906)	(6,223)
Net payment on financial derivatives	0		(19,287)	(42,908)
Payments associated with settlement of equity-based incentive compensation	(13,875)		(14,376)	(17,784)
Net cash used by financing activities	(376,688)		(120,704)	(247,255)
Change in cash and cash equivalents	161,367		(14,030)	11,668
Cash and cash equivalents at beginning of period	14,701		28,731	17,063
Cash and cash equivalents at end of period	176,068		14,701	28,731
Noncash Investing and Financing Items [Abstract]
Contribution of property, plant and equipment to a non-controlled entity	97,638		0	13,252
Issuance of limited partner units in settlement of equity-based incentive plan awards	1,669		7,289	8,045
Additions to property, plant and equipment	(572,744)		(653,528)	(623,289)
Changes in accounts payable and other current liabilities related to capital expenditures	14,075		(20,631)	2,138
Additions to property, plant and equipment, net	$ (558,669)		$ (674,159)	$ (621,151)
[1]	Includes the $48.8 million distribution to us from MVP as reimbursement for the PP&E we contributed, as well as an additional distribution of $6.2 million from BridgeTex that is not related to the ongoing operations of non-controlled entities.

Consolidated Statement Of Partn

Consolidated Statement Of Partners' Capital - USD ($) $ in Thousands	Total	Limited Partner [Member]	Accumulated Other Comprehensive Loss [Member]
Net income	$ 819,122	$ 819,122
Balance at Dec. 31, 2014	1,868,233	1,949,773	$ (81,540)
Comprehensive income:
Total other comprehensive income	(14,810)		(14,810)
Total comprehensive income (loss)	804,312	819,122	(14,810)
Distributions	(662,948)	(662,948)
Equity-based incentive compensation expense	22,248	22,248
Issuance of limited partner units in settlement of equity-based incentive plan awards	8,045	8,045
Adjustments to Additional Paid in Capital, Share-based Compensation, Other Long-term Incentive Plans, Requisite Service Period Recognition	(17,784)	(17,784)
Other	(370)	(370)
Balance at Dec. 31, 2015	2,021,736	2,118,086	(96,350)
Net income	802,771	802,771
Comprehensive income:
Total other comprehensive income	(4,891)		(4,891)
Total comprehensive income (loss)	797,880	802,771	(4,891)
Distributions	(739,157)	(739,157)
Equity-based incentive compensation expense	19,358	19,358
Issuance of limited partner units in settlement of equity-based incentive plan awards	7,289	7,289
Adjustments to Additional Paid in Capital, Share-based Compensation, Other Long-term Incentive Plans, Requisite Service Period Recognition	(14,376)	(14,376)
Other	(625)	(625)
Balance at Dec. 31, 2016	2,092,105	2,193,346	(101,241)
Net income	869,531	869,531
Comprehensive income:
Total other comprehensive income	(36,337)		(36,337)
Total comprehensive income (loss)	833,194	869,531	(36,337)
Distributions	(803,216)	(803,216)
Equity-based incentive compensation expense	20,641	20,641
Issuance of limited partner units in settlement of equity-based incentive plan awards	1,669	1,669
Adjustments to Additional Paid in Capital, Share-based Compensation, Other Long-term Incentive Plans, Requisite Service Period Recognition	(13,875)	(13,875)
Other	(865)	(865)
Balance at Dec. 31, 2017	$ 2,129,653	$ 2,267,231	$ (137,578)

Organization And Description Of

Organization And Description Of Business	12 Months Ended
	Dec. 31, 2017
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. Magellan Midstream Partners, L.P. is a Delaware limited partnership and its 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 its general partner. Description of Business We are principally engaged in the transportation, storage and distribution of refined petroleum products and crude oil. As of December 31, 2017, our asset portfolio, including the assets of our joint ventures, consisted of: • our refined products segment, comprised of our 9,700 -mile refined products pipeline system with 53 terminals as well as 26 independent terminals not connected to our pipeline system and our 1,100 -mile ammonia pipeline system; • our crude oil segment, comprised of approximately 2,200 miles of crude oil pipelines, our condensate splitter and storage facilities with an aggregate capacity of approximately 28 million barrels, of which approximately 17 million are used for contract storage; and • our marine storage segment, consisting of five marine terminals located along coastal waterways with an aggregate storage capacity of approximately 26 million barrels. Description of Products Terminology common in our industry includes the following terms, which describe products that we transport, store and distribute through our pipelines and terminals: • refined products are the output from refineries and are primarily used as fuels by consumers. Refined products include gasoline, diesel fuel, aviation fuel, kerosene and heating oil. Collectively, diesel fuel and heating oil are referred to as distillates; • liquefied petroleum gases, or LPGs, are produced as by-products of the crude oil refining process and in connection with natural gas production. LPGs include butane and propane; • blendstocks are blended with refined products to change or enhance their characteristics such as increasing a gasoline’s octane or oxygen content. Blendstocks include alkylates, oxygenates and natural gasoline; • heavy oils and feedstocks are used as burner fuels or feedstocks for further processing by refineries and petrochemical facilities. Heavy oils and feedstocks include No. 6 fuel oil and vacuum gas oil; • crude oil and condensate are used as feedstocks by refineries and petrochemical facilities; • biofuels , such as ethanol and biodiesel, are typically blended with other refined products as required by government mandates; and • ammonia is primarily used as a nitrogen fertilizer. Except for ammonia, we use the term petroleum products to describe any, or a combination, of the above-noted products.

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Summary Of Significant Accounting Policies	Summary of Significant Accounting Policies Significant Accounting Policies Basis of Presentation. Our consolidated financial statements include our refined products, crude oil and marine storage operating segments. We consolidate all entities in which we have a controlling ownership interest. We apply the equity method of accounting to investments in entities over which we exercise significant influence but do not control. We eliminate all intercompany transactions. Use of Estimates. The preparation of our consolidated financial statements in conformity with U.S. generally accepted accounting principles (“GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities that exist at the date of our consolidated financial statements, as well as their impact on the reported amounts of revenue and expense during the reporting periods. Actual results could differ from those estimates. Cash Equivalents. Cash and cash equivalents include demand and time deposits and funds that own highly marketable securities with original maturities of three months or less when acquired. We periodically assess the financial condition of the institutions where we hold these funds, and, at December 31, 2016 and 2017 , we believed our credit risk relative to these funds was minimal. Accounts Receivable and Allowance for Doubtful Accounts. Accounts receivable represent valid claims against customers. We recognize accounts receivable when we sell products or render services and collection of the receivable is probable. We extend credit terms to certain customers based on historical dealings and to other customers after a review of various credit indicators. We establish an allowance for doubtful accounts for all or any portion of an account where we consider collections to be at risk and evaluate reserves no less than quarterly to determine their adequacy. Judgments relative to at-risk accounts include the customers’ current financial condition, the customers’ historical relationship with us and current and projected economic conditions. We write off accounts receivable when we deem an account uncollectible. Revenue Recognition. Revenue is recognized based on contracts or other persuasive evidence of an arrangement with the customer that includes fixed or determinable prices in which collectability is reasonably assured. We recognize revenue net of all amounts charged to our customers for excise taxes. We recognize pipeline transportation revenue for crude oil shipments when our customers’ product arrives at the customer-designated destination. For shipments of refined products and ammonia under published tariffs that combine transportation and terminalling services, we recognize revenue when our customers take delivery of their product from our system. For shipments where terminalling services are not included in the tariff, we recognize revenue when our customers’ product arrives at the customer-designated destination. We have certain agreements that require counterparties to ship a minimum volume over an agreed-upon period. Revenue pursuant to such agreements is recognized at the earlier of when the volume is shipped or when the counterparty’s ability to meet the minimum volume commitment has expired. 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. Generally, our tariffs include provisions that 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. We receive tender deductions from our customers as consideration for product shortages during the transportation of their refined products or crude oil within our pipeline systems. Our customers are guaranteed delivery of the amount of their injected volumes, net of tender deductions, irrespective of what our actual product shortages may be during the delivery process. Tender deduction revenue is recognized as transportation and terminals revenue when the transportation barrels are received and is recorded at the fair value of the product received. We recognize 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 the rendered services. Product sales revenue is recognized when the customer assumes the risks and rewards of ownership. We recognize injection service fees associated with additives upon injection to the customer’s product, which occurs at the time we deliver the product to our customers. Deferred Transportation Revenue and Costs. Generally, we invoice customers on our refined products pipeline for transportation services when their product enters our system. At each period end, we record all invoiced amounts associated with products that have not yet been delivered (in-transit products) as a deferred liability. The value of this liability is calculated as the total of the volume of each product type, for each pipeline region, multiplied by the average tariff rate for that product type for the most recent month invoiced to our customers. We use the most recent month’s average tariff rate because the product in our pipeline system generally turns over every month. Additionally, at each period end, we defer the direct costs we have incurred associated with these in-transit products, until delivery occurs, as a deferred asset. These direct costs are estimated based on our average per-barrel direct delivery cost for the current year multiplied by the total in-transit barrels in our system at the end of the period multiplied by 50% to reflect the average transportation costs incurred for all products across all our pipeline systems. We use 50% of the in-transit barrels because that best represents the average delivery point of all barrels in our pipeline system. These deferred revenues and costs are determined using judgments and assumptions that management considers reasonable. Product Overages and Shortages. Each period end we measure the volume of each type of product in our pipeline systems and terminals, which is compared to the volumes of our customers’ inventories (as adjusted for tender deductions). To the extent the product volumes in our pipeline systems and terminals exceed the volumes of our customers’ book inventories, we recognize a gain from the product overage and increase our product inventories. To the extent the product in our pipeline systems and terminals is less than our customers’ book inventories, we recognize a loss from the product shortage and we record a liability for product owed to our customers. The product overages we recognize are recorded based on market prices, and the resulting inventory is carried at weighted average cost. The product shortages we recognize are recorded based on our weighted average cost. Additionally, when product shortages result in a net short inventory position, the related liability is recorded based on period-end market prices. Product overages and shortages as well as adjustments to the value of net short inventory positions are recorded in operating expenses on our consolidated statements of income. Income Taxes. We are a partnership for income tax purposes and, therefore, are not subject to federal or state income taxes for most of the states in which we operate. The tax on our net income is borne by our limited partners through allocation to them of their share 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 consolidated statements of income are primarily comprised of partnership-level taxes levied by the state of Texas. This tax is based on revenues less direct costs of sale for our assets apportioned to the state of Texas. Net Income Per Unit. We calculate basic net income per limited partner unit for each period by dividing net income by the weighted-average number of limited partner units outstanding. The difference between our actual limited partner units outstanding and our weighted-average number of limited partner units outstanding used to calculate net income per limited partner unit is due to the impact of: (i) the phantom units issued to independent directors, which are included in the calculation of basic and diluted weighted average units outstanding and (ii) the weighted-average effect of units actually issued during a period. The difference between the weighted-average number of limited partner units outstanding used for basic and diluted net income per unit calculations on our consolidated statements of income is primarily the dilutive effect of phantom unit grants associated with our long-term incentive plan, which have not yet vested in periods where contingent performance metrics have been met. Index of Additional Significant Accounting Policies Investments in Non-Controlled Entities Note 4 – Investments in Non-Controlled Entities Inventory Note 6 – Inventory Property, Plant and Equipment Note 8 – Property, Plant and Equipment Goodwill and Other Intangible Assets Note 8 – Property, Plant and Equipment Impairment of Long-Lived Assets Note 8 – Property, Plant and Equipment Pension and Postretirement Medical and Life Benefit Obligations Note 10 – Employee Benefit Plans Derivative Financial Instruments Note 13 – Derivative Financial Instruments Equity-Based Incentive Compensation Note 15 – Long-Term Incentive Plan Contingencies and Environmental Note 17 – Commitments and Contingencies New Accounting Pronouncements In August 2017, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2017-12, Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities . This update changes GAAP’s hedge accounting requirements to simplify some of the specialized treatment’s most complex areas. These simplifications are intended to expand opportunities to use hedge accounting and better align the accounting treatment with existing risk management activities. The ASU is effective for public companies starting after December 15, 2018, and we plan to early adopt the new standard on January 1, 2018. We do not expect the adoption of this ASU to have a material impact on our consolidated financial statements. In March 2017, the FASB issued ASU 2017-07, Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost . This ASU requires companies that offer postretirement benefits to present the service cost in the same line item with other employee compensation costs. Other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations. Additionally, only the service cost component will be eligible for capitalization when applicable. Public companies must comply with the new requirements under ASU 2017-07 for fiscal years that start after December 15, 2017, and the amendments must be applied retrospectively except for the capitalization change, which should be applied prospectively. Early adoption is allowed, and we elected to adopt ASU 2017-07 as of January 1, 2017. Prior to adoption, we expensed all components of pension expense through salaries and wages, which impacted operating income. We are now recording only the service component of pension expense to salaries and wages, with the remainder of the expense being recorded to other income and expense below operating profit. Comparative prior periods have been restated for this change. The changes were not material to our financial statements. In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments: A Consensus of the FASB Emerging Issues Task Force . This ASU makes eight targeted changes to how cash receipts and cash payments are presented and classified in the statement of cash flows. Current GAAP is either unclear or does not include specific guidance on these eight issues. This ASU is effective for fiscal years beginning after December 15, 2017. We do not expect the adoption of this ASU to have a material impact on our consolidated financial statements. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842). This ASU requires lessees to recognize a right of use asset and lease liability on the balance sheets for all leases, with the exception of short-term leases. The new accounting model for lessors remains largely the same, although some changes have been made to align it with the new lessee model and the new revenue recognition guidance. This update also requires companies to include additional disclosures regarding their lessee and lessor agreements. For public companies, this ASU is effective for fiscal years that start after December 15, 2018, and early adoption is permitted. We are currently in the process of evaluating the impact this new standard will have on our financial statements. In July 2015, the FASB issued ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory . Prior to this update, reporting entities were required to measure inventory at the lower of cost or market. Market could be replacement cost, net realizable value or net realizable value less an approximately normal profit margin. Under this update, inventory is to be measured at the lower of cost or net realizable value, which is defined as the estimated selling price in the ordinary course of business, less reasonable predictable costs of completion, disposal and transportation. This ASU became effective for fiscal years beginning after December 15, 2016 and interim periods within those fiscal years. We adopted this standard on January 1, 2017, and it did not have a material impact on our results of operations, financial position or cash flows as we have historically measured our inventory at the lower of cost or net realizable value. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers. This ASU amends the existing accounting standards for revenue recognition and is based on the principle that revenue should be recognized to depict the transfer of goods or services to a customer at an amount that reflects the consideration a company expects to receive in exchange for those goods or services. We will adopt this ASU as required on January 1, 2018, using the modified retrospective method of adoption. The primary impact to the financial statements will be the addition of the new disclosure requirements, as we do not expect material changes to individual line items in the consolidated financial statements.

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - Supplemental Disclosures	12 Months Ended
	Dec. 31, 2017
Supplemental Cash Flow Information [Abstract]
Consolidated Statements of Cash Flows - Supplemental Disclosures	Consolidated Statements of Cash Flows Changes in the components of operating assets and liabilities are as follows (in thousands): Year Ended December 31, 2015 2016 2017 Trade accounts receivable and other accounts receivable $ 3,664 $ (31,107 ) $ (25,639 ) Inventory 26,894 (3,510 ) (47,967 ) Energy commodity derivatives contracts, net of derivatives deposits (606 ) (692 ) 8,556 Accounts payable 4,107 (4,423 ) 8,954 Accrued payroll and benefits 3,466 (6,074 ) 10,596 Accrued interest payable 5,323 14,347 5,014 Accrued taxes other than income 3,699 (1,421 ) 1,177 Deferred revenue 10,485 20,264 15,904 Accrued product liabilities (13,016 ) 20,261 44,559 Current and noncurrent environmental liabilities (4,904 ) (7,398 ) (4,766 ) Other current and noncurrent assets and liabilities 9,250 (21,762 ) (693 ) Total $ 48,362 $ (21,515 ) $ 15,695 Other current and noncurrent assets and liabilities above exclude certain non-cash items that were reflected in the consolidated balance sheets but were not reflected in the statements of cash flows. At December 31, 2015 , 2016 and 2017 , the long-term pension and benefits liability was increased by $4.7 million , $2.5 million and $46.0 million , respectively, resulting in a corresponding increase in accumulated other comprehensive loss (“AOCL”).

Investments in Non-Controlled E

Investments in Non-Controlled Entities	12 Months Ended
	Dec. 31, 2017
Equity Method Investments and Joint Ventures [Abstract]
Investments in Non-Controlled Entities	Investments in Non-Controlled Entities We account for interests in affiliates that we do not control using the equity method of accounting. Under this method, an investment is recorded at our acquisition cost or capital contributions, as adjusted by contractual terms, plus equity in earnings or losses since acquisition or formation, plus interest capitalized, less distributions received and amortization of interest capitalized and excess net investment. Excess net investment is the amount by which our investment in a non-controlled entity exceeded our proportionate share of the book value of the net assets of that investment. We amortize excess net investment over the weighted-average depreciable asset lives of the equity investee. Our unamortized excess net investment was $61.3 million and $59.7 million at December 31, 2016 and 2017 , respectively. The amount of unamortized excess investment is primarily related to our investment in BridgeTex Pipeline Company, LLC. We evaluate equity method investments for impairment whenever events or circumstances indicate that there is an other-than-temporary loss in value of the investment. In the event that we determine that the loss in value of an investment is other-than-temporary, we would record a charge to earnings to adjust the carrying value to fair value. We recognized no equity investment impairments during 2015 , 2016 and 2017 . Our investments in non-controlled entities at December 31, 2017 were comprised of: Entity Ownership Interest BridgeTex Pipeline Company, LLC (“BridgeTex”) 50% Double Eagle Pipeline LLC (“Double Eagle”) 50% HoustonLink Pipeline Company, LLC (“HoustonLink”) 50% MVP Terminalling, LLC (“MVP”) 50% Powder Springs Logistics, LLC (“Powder Springs”) 50% Saddlehorn Pipeline Company, LLC (“Saddlehorn”) 40% Seabrook Logistics, LLC (“Seabrook”) 50% Texas Frontera, LLC (“Texas Frontera”) 50% MVP was formed in September 2017 to construct and develop a refined products marine storage facility along the Houston Ship Channel in Pasadena, Texas. We own a 50% equity interest in MVP, with an affiliate of Valero Energy Corporation (“Valero”) owning the other 50% interest. We serve as construction manager and will serve as operator of the MVP facility. The initial phase of this facility is expected to be operational in early 2019, with the next phase of the project being completed in 2020. Upon formation of MVP, we contributed $97.6 million of property, plant and equipment (“PP&E”) to this entity. Concurrently, Valero contributed cash of $48.8 million , which was distributed to us as reimbursement for Valero’s portion of the PP&E we contributed. The $48.8 million is reflected as distributions in excess of earnings of non-controlled entities on our consolidated statements of cash flows. We receive fees for management services from BridgeTex, HoustonLink, MVP, Powder Springs, Saddlehorn, Texas Frontera and the pipeline activities of Seabrook, as well as reimbursement or payment to us for certain direct operational payroll and other overhead costs. The management fees we have received are reported as affiliate management fee revenue on our consolidated statements of income. Cost reimbursements we receive from these entities in connection with our operating services are included as reductions to costs and expenses on our consolidated statements of income and totaled $1.3 million , $4.2 million and $3.6 million , respectively, for the years ended December 31, 2015 , 2016 and 2017 . We recorded the following revenue from certain of these non-controlled entities in our consolidated statements of income (in millions): Year Ended December 31, 2015 2016 2017 Transportation and terminals revenue: BridgeTex, capacity lease $ 34.6 $ 35.5 $ 36.1 Double Eagle, throughput revenue $ 3.4 $ 3.3 $ 4.7 Saddlehorn, storage revenue $ — $ 0.7 $ 2.1 Our consolidated balance sheets reflected the following balances related to our investments in non-controlled entities (in millions): December 31, 2016 December 31, 2017 Trade Accounts Receivable Other Accounts Receivable Other Accounts Payable Trade Accounts Receivable Other Accounts Receivable Other Accounts Payable Double Eagle $ 0.3 $ — $ — $ 0.5 $ — $ — HoustonLink $ — $ — $ — $ — $ — $ 0.1 MVP $ — $ — $ — $ — $ 0.4 $ — Powder Springs $ — $ — $ — $ — $ 0.9 $ — Saddlehorn $ — $ 0.1 $ — $ — $ 0.1 $ — Seabrook $ — $ — $ — $ — $ 0.2 $ — In addition to the transactions noted above, we incurred charges of $14.5 million for transportation of crude oil at published spot tariff rates on the BridgeTex pipeline for the year ended December 31, 2017 . We recorded these charges as cost of product sales in our consolidated statements of income. We also purchased inventory from BridgeTex valued at $6.7 million during 2017. In January 2017, we entered into an agreement to guarantee our 50% pro rata share, up to $50.0 million , of obligations under Powder Springs’ credit facility. As of December 31, 2017 , we had recognized a $0.8 million other current liability and a corresponding increase in our investment in non-controlled entities on our consolidated balance sheets to reflect the fair value of this guarantee. In February 2016, we transferred a 50% membership interest in Osage Pipe Line Company, LLC (“Osage”) to an affiliate of HollyFrontier Corporation. In conjunction with this transaction, we entered into several commercial agreements with affiliates of HollyFrontier Corporation, which we recorded at that time as a $43.7 million intangible asset and an $8.3 million other receivable on our consolidated balance sheets. The intangible asset will be amortized over the 20 -year life of the contracts received. We recognized a $28.1 million non-cash gain in 2016 in relation to this transaction. The financial results from MVP and Texas Frontera are included in our marine storage segment, the financial results from BridgeTex, Double Eagle, HoustonLink, Osage, Saddlehorn and Seabrook are included in our crude oil segment and the financial results from Powder Springs are included in our refined products segment, each as earnings of non-controlled entities. A summary of our investments in non-controlled entities (representing only our proportionate interests) follows (in thousands): Investments at December 31, 2016 $ 931,255 Additional investment (1) 232,404 Earnings of non-controlled entities: Proportionate share of earnings 123,373 Amortization of excess investment and capitalized interest (2,379 ) Earnings of non-controlled entities 120,994 Less: Distributions of earnings from investments in non-controlled entities 123,660 Distributions in excess of earnings of non-controlled entities (2) 78,482 Investments at December 31, 2017 $ 1,082,511 (1) Includes our $97.6 million contribution of PP&E to MVP. (2) Includes the $48.8 million distribution to us from MVP as reimbursement for the PP&E we contributed, as well as an additional distribution of $6.2 million from BridgeTex that is not related to the ongoing operations of non-controlled entities. Summarized financial information of our non-controlled entities (representing 100% of the interests in these entities) follows (in thousands): December 31, 2016 2017 Current assets $ 208,901 $ 229,342 Noncurrent assets 1,714,920 2,057,892 Total assets $ 1,923,821 $ 2,287,234 Current liabilities $ 111,164 $ 122,198 Noncurrent liabilities 27,022 74,533 Total liabilities $ 138,186 $ 196,731 Equity $ 1,785,635 $ 2,090,503 Year Ended December 31, 2015 2016 2017 Revenue $ 246,841 $ 279,180 $ 419,214 Net income $ 138,457 $ 164,684 $ 256,423

Business Combinations

Business Combinations	12 Months Ended
	Dec. 31, 2017
Business Combinations [Abstract]
Business Combinations	Business Combinations 2015 Business Combination. On May 1, 2015, we acquired a refined products terminal in Atlanta, Georgia for net cash consideration of $54.7 million . As this acquired business is not significant to our consolidated operating results and financial position, pro forma financial information and the purchase price allocation of acquired assets and liabilities have not been presented. The results of the acquired operations subsequent to the acquisition date have been included in the accompanying consolidated financial statements and in the tables below in our refined products operating segment.

Inventory

Inventory	12 Months Ended
	Dec. 31, 2017
Inventory Disclosure [Abstract]
Inventory	Inventory 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 net realizable value. Inventory at December 31, 2016 and 2017 was as follows (in thousands): December 31, 2016 2017 Refined products $ 54,285 $ 73,845 Liquefied petroleum gases 24,868 45,553 Transmix 28,319 33,319 Crude oil 20,839 23,763 Additives 6,067 5,865 Total inventory $ 134,378 $ 182,345

Product Sales Revenue

Product Sales Revenue	12 Months Ended
	Dec. 31, 2017
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 mark-to-market adjustments from exchange-based futures contracts. See Note 13 – Derivative Financial Instruments for a discussion of our commodity hedging strategies and how our futures contracts impact product sales revenue. For the years ended December 31, 2015 , 2016 and 2017 , product sales revenue included the following (in thousands): Year Ended December 31, 2015 2016 2017 Physical sale of petroleum products $ 561,410 $ 638,186 $ 814,544 Change in value of futures contracts 68,426 (38,584 ) (56,338 ) Total product sales revenue $ 629,836 $ 599,602 $ 758,206

Property, Plant and Equipment a

Property, Plant and Equipment and Other Intangibles	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment and Other Intangibles	Property, Plant and Equipment, Goodwill and Other Intangibles Property, Plant and Equipment Property, plant and equipment consist primarily of pipeline, pipeline-related equipment, storage tanks and processing equipment. We state property, plant and equipment at cost except for certain acquired assets recorded at fair value on their respective acquisition dates and impaired assets. We record impaired assets at fair value on the last impairment evaluation date for which an adjustment was required. We assign asset lives based on reasonable estimates when we place an asset into service. Subsequent events could cause us to change our estimates, which would affect the future calculation of depreciation expense. 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 consolidated statements of income in the period of sale or disposition. We capitalize expenditures to replace existing assets and retire the replaced assets. We capitalize expenditures when they extend the useful life, increase the productivity or capacity or improve the safety or efficiency of the asset. We capitalize direct project costs such as labor and materials as incurred. Indirect project costs, such as overhead, are capitalized based on a percentage of direct labor charged to the respective capital project. We charge expenditures for maintenance, repairs and minor replacements to operating expense in the period incurred. During construction, we capitalize interest on all construction projects requiring a completion period of three months or longer and total project costs exceeding $0.5 million . The interest we capitalize is based on the weighted-average interest rate of our debt. The weighted average rates used to capitalize interest on borrowed funds was 4.7% , 4.9% and 4.8% for the years ended December 31, 2015 , 2016 and 2017 , respectively. Property, plant and equipment consisted of the following (in thousands): Estimated Depreciable Lives December 31, 2016 2017 Construction work-in-progress $ 500,208 $ 389,414 Land and rights-of-way 339,561 303,797 Buildings 101,065 114,899 10 to 56 years Storage tanks 1,829,223 1,897,046 10 to 40 years Pipeline and station equipment 2,457,429 2,581,950 10 to 69 years Processing equipment 1,350,032 1,703,478 3 to 56 years Other 206,219 244,884 3 to 53 years Property, Plant and Equipment, Gross $ 6,783,737 $ 7,235,468 Other includes total interest capitalized on construction in progress as of December 31, 2016 and 2017 of $43.1 million and $57.3 million , respectively. Depreciation expense for the years ended December 31, 2015 , 2016 and 2017 was $164.1 million , $176.7 million and $196.3 million , respectively. Goodwill and Other Intangibles We record the excess of purchase price over the fair value of the tangible and identifiable intangible assets acquired and liabilities assumed as goodwill. The goodwill relating to each of our reporting units is tested for impairment annually as well as when an event, or change in circumstances, indicates an impairment may have occurred. We amortize other intangible assets with finite lives over their estimated useful lives of six years up to 30 years. The weighted-average asset life of our other intangible assets at December 31, 2017 was approximately 21 years. We adjust the useful lives of our other intangible assets if events or circumstances indicate there has been a change in the remaining useful lives. We eliminate from our balance sheets the gross carrying amount and the related accumulated amortization for any fully amortized intangibles in the year they are fully amortized. During the years ended December 31, 2015 , 2016 and 2017 , amortization of other intangible assets was $2.7 million , $1.4 million and $0.4 million , respectively. Impairment of Long-Lived Assets Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying value may not be recoverable. In reviewing for impairment, the carrying value of such assets is compared to the estimated undiscounted future cash flows expected from the use of the assets and their eventual disposition. If such cash flows are not sufficient to support the asset’s recorded value, an impairment charge is recognized to reduce the carrying value of the long-lived asset to its estimated fair value. The determination of future cash flows as well as the estimated fair value of long-lived assets involves significant estimates on the part of management. For purposes of performing the impairment test for goodwill, our reporting units are refined products, crude oil and marine storage. In 2015 and 2016, we elected to perform the qualitative assessment for purposes of our annual goodwill impairment test. Based on this assessment, we concluded that it was more likely than not that the fair value of each of our reporting units was greater than its carrying amount. In 2017, we elected to complete the quantitative goodwill impairment test and began with step one of the test as required by ASC 350-20-35-4. Based on this assessment, we concluded that our goodwill was not impaired. During the years ended December 31, 2015 , 2016 and 2017 , no material impairments of long-lived assets were recorded.

Major Customers and Concentrati

Major Customers and Concentration Of Risks	12 Months Ended
	Dec. 31, 2017
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 more than 10% of our consolidated revenues during 2015 , 2016 or 2017 . Concentration of Risks. We transport, store and distribute refined products for refiners, marketers, traders and end users of those products. Our revenue producing activities are concentrated in the central U.S. Concentrations of customers may affect our overall credit risk as our customers may be similarly affected by changes in economic, regulatory or other factors. 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, 2017 , we had 1,802 employees, 940 of which were assigned to our refined products segment and concentrated in the central U.S. Approximately 24% of the 940 employees are represented by the United Steel Workers (“USW”) and covered by a collective bargaining agreement that expires in January 2019. At December 31, 2017 , 151 of our employees were assigned to our crude oil segment and were concentrated in the central U.S., and none of these employees were covered by a collective bargaining agreement. 177 employees were assigned to our marine storage segment at December 31, 2017 , primarily in the Gulf and East Coast regions of the U.S. Approximately 16% of these employees are represented by the International Union of Operating Engineers (“IUOE”) and covered by a collective bargaining agreement that expires in October 2020.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2017
Retirement Benefits [Abstract]
Employee Benefit Plans	Employee Benefit Plans Our pension and postretirement benefit liabilities represent the funded status of the present value of benefit obligations of our employee benefit plans. We develop pension, postretirement medical and life benefit 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 expected investment return on plan assets, discount rates, health care costs trend rates, turnover rates and rates of future compensation increases, among others. In addition, we use subjective factors such as withdrawal and mortality rates to develop actuarial valuations. Management reviews and updates these assumptions on an annual basis. The actuarial assumptions that we use may differ from actual results due to changing market rates or other factors. These differences could affect the amount of pension and postretirement medical and life benefit expense we will recognize in future periods. Defined Contribution Plan. We sponsor a defined contribution plan in which we match our employees’ qualifying contributions, resulting in additional expense to us. Expenses related to the defined contribution plan were $8.9 million , $9.6 million and $9.9 million in 2015 , 2016 and 2017 , respectively. Defined Benefit Plans. We sponsor two union pension plans that cover certain union employees (“USW plan” and “IUOE plan,” collectively, the “Union plans”), a pension plan for all non-union employees (“Salaried plan”) and a postretirement benefit plan for certain employees. 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, as well as the end-of-period accumulated benefit obligation for the years ended December 31, 2016 and 2017 (in thousands): Pension Benefits Other Postretirement Benefits 2016 2017 2016 2017 Change in benefit obligations: Benefit obligations at beginning of year $ 209,591 $ 225,970 $ 11,314 $ 13,011 Service cost 18,179 20,497 235 243 Interest cost 7,950 9,865 489 475 Plan participants’ contributions — — 217 280 Actuarial loss (gain) 1,050 59,686 1,481 (535 ) Benefits paid (10,053 ) (11,484 ) (725 ) (714 ) Settlement payments (747 ) (6,678 ) — — Benefit obligations at end of year 225,970 297,856 13,011 12,760 Change in plan assets: Fair value of plan assets at beginning of year 142,742 166,906 — — Employer contributions 25,972 26,533 508 434 Plan participants’ contributions — — 217 280 Actual return on plan assets 8,992 23,409 — — Benefits paid (10,053 ) (11,484 ) (725 ) (714 ) Settlement payments (747 ) (6,678 ) — — Fair value of plan assets at end of year 166,906 198,686 — — Funded status at end of year $ (59,064 ) $ (99,170 ) $ (13,011 ) $ (12,760 ) Accumulated benefit obligations $ 160,642 $ 206,480 The pension benefits in the previous table combine the Union plans with the Salaried plan. At December 31, 2016, the fair value of each of our plans’ assets exceeded the accumulated benefit obligations of the related benefit plans. At December 31, 2017, the Salaried and IUOE plans had combined accumulated benefit obligations of $154.4 million , which exceeded the combined fair value of plan assets of $145.9 million . The pension benefit obligations experienced an actuarial loss of $59.7 million in 2017 primarily due to the impact of decreases in the discount rates used to calculate the benefit obligations and changes to mortality assumptions, as well as losses due to annual remeasurement of the plans. Amounts recognized in the consolidated balance sheets included in these financial statements were as follows (in thousands): Pension Benefits Other Postretirement Benefits 2016 2017 2016 2017 Amounts recognized in consolidated balance sheets: Current accrued benefit cost $ — $ — $ 614 $ 625 Long-term pension and benefits 59,064 99,170 12,397 12,135 59,064 99,170 13,011 12,760 Accumulated other comprehensive loss: Net actuarial loss (62,013 ) (100,474 ) (7,881 ) (6,597 ) Prior service credit 3,429 3,248 — — (58,584 ) (97,226 ) (7,881 ) (6,597 ) Net amount of liabilities and accumulated other comprehensive loss recognized in consolidated balance sheets $ 480 $ 1,944 $ 5,130 $ 6,163 Net periodic benefit expense for the years ended December 31, 2015 , 2016 and 2017 was as follows (in thousands): Pension Benefits Other Postretirement Benefits 2015 2016 2017 2015 2016 2017 Components of net periodic pension and postretirement benefit expense: Service cost $ 18,890 $ 18,179 $ 20,497 $ 243 $ 235 $ 243 Interest cost (1) 7,754 7,950 9,865 438 489 475 Expected return on plan assets (1) (8,037 ) (8,913 ) (10,266 ) — — — Amortization of prior service credit (1) — (181 ) (181 ) (3,713 ) (3,335 ) — Amortization of actuarial loss (1) 6,306 4,645 5,622 885 880 749 Settlement cost (1) — 202 2,460 — — — Net periodic expense (credit) $ 24,913 $ 21,882 $ 27,997 $ (2,147 ) $ (1,731 ) $ 1,467 (1) Upon adoption of ASU 2017-07 Compensation-Retirement Benefits (Topic 715) : Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost on January 1, 2017, these components of net periodic benefit expense (credit) are reported on the consolidated statements of income as other (income) expense. See Note 2 – Summary of Significant Accounting Policies - New Accounting Pronouncements for further details about this accounting change. Changes in plan assets and benefit obligations recognized in other comprehensive loss during 2015 , 2016 and 2017 were as follows (in thousands): Pension Benefits Other Postretirement Benefits 2015 2016 2017 2015 2016 2017 Beginning balance $ (63,257 ) $ (62,279 ) $ (58,584 ) $ (1,696 ) $ (3,945 ) $ (7,881 ) Net actuarial gain (loss) (8,938 ) (971 ) (46,543 ) 579 (1,481 ) 535 Plan amendment 3,610 — — — — — Amortization of prior service credit — (181 ) (181 ) (3,713 ) (3,335 ) — Amortization of actuarial loss 6,306 4,645 5,622 885 880 749 Settlement cost — 202 2,460 — — — Amount recognized in other comprehensive loss 978 3,695 (38,642 ) (2,249 ) (3,936 ) 1,284 Ending balance $ (62,279 ) $ (58,584 ) $ (97,226 ) $ (3,945 ) $ (7,881 ) $ (6,597 ) Actuarial gains and losses are amortized over the average future service period of current active plan participants expected to receive benefits. The corridor approach is used to determine when actuarial gains and losses are to be amortized and is equal to 10% of the greater of the projected benefit obligation or the market related value of plan assets. The amount of gain or loss in excess of the calculated corridor is subject to amortization. The estimated net actuarial loss and prior service credit for the defined benefit pension plans that will be amortized from AOCL into net periodic benefit cost in 2018 are $7.0 million and $(0.2) million , respectively. The estimated net actuarial loss for the other defined benefit postretirement plan that will be amortized from AOCL into net periodic benefit cost in 2018 is $0.6 million . The weighted-average rate assumptions used to determine benefit obligations were as follows: December 31, 2016 2017 Discount rate—Salaried plan 4.21% 3.70% Discount rate—USW plan 4.08% 3.54% Discount rate—IUOE plan 4.41% 3.79% Discount rate—Other Postretirement Benefits 3.85% 3.43% Rate of compensation increase—Salaried plan (1) 4% - 11% 4% - 11% Rate of compensation increase—USW plan 3.50% 3.50% Rate of compensation increase—IUOE plan 5.00% 5.00% (1) The rate of compensation increase assumption for the Salaried plan in 2016 and 2017 is calculated by 10-year age groupings beginning with ages 20-29 at 11% dropping to 4% by ages 70 and above. The weighted-average rate assumptions used to determine net pension and other postretirement benefit expense were as follows: For the Year Ended December 31, 2015 2016 2017 Discount rate—Salaried plan 3.91% 3.95% 4.21% Discount rate—USW plan 3.56% 3.82% 4.04% Discount rate—IUOE plan 3.93% 3.78% 4.41% Discount rate—Other Postretirement Benefits 3.66% 4.00% 3.85% Rate of compensation increase—Salaried plan (1) 5.50% 4% - 11% 4% - 11% Rate of compensation increase—USW plan 3.50% 3.50% 3.50% Rate of compensation increase—IUOE plan 5.00% 5.00% 5.00% Expected rate of return on plan assets—Salaried plan 6.00% 6.00% 6.00% Expected rate of return on plan assets—USW plan 6.00% 6.00% 6.00% Expected rate of return on plan assets—IUOE plan 6.00% 6.00% 6.00% (1) The rate of compensation increase assumption for the Salaried plan is calculated by 10-year age groupings beginning with ages 20-29 at 11% dropping to 4% by ages 70 and above. 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 2018 is 5.4% decreasing systematically to 4.5% by 2083 for pre-65 year-old participants. As of December 31, 2017 , a 1.0% change in assumed health care cost trend rates would have been immaterial to us. The fair values of the pension plan assets at December 31, 2016 were as follows (in thousands): Asset Category Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Domestic Equity Securities (a) : Small-cap fund $ 3,465 $ 3,465 $ — $ — Mid-cap fund 3,472 3,472 — — Large-cap fund 26,323 26,323 — — International equity fund 16,797 16,797 — — Fixed Income Securities (a) : Short-term bond funds 4,414 4,414 — — Intermediate-term bond funds 23,629 23,629 — — Long-term investment grade bond funds 83,240 83,240 — — Other: Short-term investment funds 5,346 5,346 — — Group annuity contract 220 — — 220 Fair value of plan assets $ 166,906 $ 166,686 $ — $ 220 (a) We hold equity and fixed income securities through investments in mutual funds, which are dedicated to each category as indicated. The fair values of the pension plan assets at December 31, 2017 were as follows (in thousands): Asset Category Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Domestic Equity Securities (a) : Small-cap fund $ 5,122 $ 5,122 $ — $ — Mid-cap fund 5,132 5,132 — — Large-cap funds 38,678 38,678 — — International equity fund 24,284 24,284 — — Fixed Income Securities (a) : Short-term bond funds 5,110 5,110 — — Intermediate-term bond funds 25,875 25,875 — — Long-term investment grade bond funds 88,563 88,563 — — Other: Short-term investment fund 5,722 5,722 — — Group annuity contract 200 — — 200 Fair value of plan assets $ 198,686 $ 198,486 $ — $ 200 (a) We hold equity and fixed income securities through investments in mutual funds, which are dedicated to each category as indicated. As reflected in the tables above, Level 3 activity was not material. 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 funds Seek 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 fund Invests in high quality short-term money market instruments issued by the U.S. Treasury Group annuity contract Earns interest quarterly equal to the effective yield of the 91-day U.S. Treasury bill 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 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 to 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 liabilities are calculated using rates defined by the Pension Protection Act of 2006. Investments are made to match the durations of the short-term and intermediate-term pension liabilities. Additional investments are made to bring the overall investment allocation to 70% fixed income securities and 30% equity securities. The target allocation and actual weighted-average asset allocation percentages at December 31, 2016 and 2017 were as follows: 2016 2017 Actual Target Actual Target Equity securities 30% 30% 37% 30% Fixed income securities 67% 67% 60% 67% Other 3% 3% 3% 3% As of December 31, 2017 , the benefit amounts expected to be paid from plan assets through December 31, 2027 were as follows (in thousands): Pension Benefits Other Postretirement Benefits 2018 $ 14,200 $ 625 2019 $ 13,854 $ 678 2020 $ 16,206 $ 715 2021 $ 16,556 $ 785 2022 $ 18,518 $ 844 2023 through 2027 $ 95,544 $ 4,021 Contributions estimated to be paid by us into the plans in 2018 are $28.1 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, 2017
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 was also a director of Targa Resources Partners, L.P. (“Targa”) through February 29, 2016. In the normal course of business, we purchase butane from subsidiaries of Targa. During Mr. Pearl’s tenure as a director of the general partner of Targa, we made purchases of butane from subsidiaries of Targa of $25.5 million and $4.7 million for the years ended December 31, 2015 and 2016, respectively. Stacy P. Methvin was elected as an independent member of our general partner’s board of directors on April 23, 2015 and is also a director of one of our customers. Since April 23, 2015, we received tariff revenue of $9.3 million , $16.2 million and $16.6 million for the periods ending December 31, 2015, 2016 and 2017 , respectively, from this customer. We recorded a receivable of $1.4 million and $1.6 million from this customer at December 31, 2016 and 2017 , respectively. The tariff revenue we recognized from this customer was in the normal course of business, with rates determined in accordance with published tariffs. See Note 4 – Investments in Non-Controlled Entities for a discussion of transactions with our joint venture affiliates.

Debt

Debt	12 Months Ended
	Dec. 31, 2017
Debt Disclosure [Abstract]
Debt	Debt Long-term debt at December 31, 2016 and 2017 was as follows (in thousands): December 31, 2016 2017 Commercial paper $ 50,000 $ — 6.40% Notes due 2018 250,000 250,000 6.55% Notes due 2019 550,000 550,000 4.25% Notes due 2021 550,000 550,000 3.20% Notes due 2025 250,000 250,000 5.00% Notes due 2026 650,000 650,000 6.40% Notes due 2037 250,000 250,000 4.20% Notes due 2042 250,000 250,000 5.15% Notes due 2043 550,000 550,000 4.20% Notes due 2045 250,000 250,000 4.25% Notes due 2046 500,000 500,000 4.20% Notes due 2047 — 500,000 Face value of long-term debt 4,100,000 4,550,000 Unamortized debt issuance costs (1) (26,948 ) (29,472 ) Net unamortized debt premium (1) 6,530 215 Net unamortized amount of gains from historical fair value hedges (1) 7,610 3,749 Long-term debt, net, including current portion 4,087,192 4,524,492 Less: current portion of long-term debt, net — 250,974 Long-term debt, net $ 4,087,192 $ 4,273,518 (1) Debt issuance costs, note discounts and premiums, and realized gains and losses of historical fair value hedges are being amortized or accreted to the applicable notes over the respective lives of those notes. All of the instruments detailed in the table above are senior indebtedness. At December 31, 2017 , maturities of our debt were as follows: $250.0 million in July 2018; $550.0 million in 2019; $0 in 2020; $550.0 million in 2021; $0 in 2022; and approximately $3.2 billion thereafter. 2017 Debt Offering On October 3, 2017, we issued $500.0 million of our 4.20% notes due 2047 in an underwritten public offering. The notes were issued at 99.341% of par. Net proceeds from this offering were approximately $491.6 million , after underwriting discounts and offering expenses of $5.1 million . The net proceeds from this offering were used to repay borrowings outstanding under our commercial paper program. The remaining proceeds were used for general partnership purposes, including capital expenditures. Other Debt Revolving Credit Facility. At December 31, 2017 , the total borrowing capacity under our revolving credit facility maturing October 26, 2022 was $1.0 billion . Any borrowings outstanding under this facility are classified as long-term debt on our consolidated balance sheets. Borrowings under the facility are unsecured and bear interest at LIBOR plus a spread ranging from 1.000% to 1.625% based on our credit ratings. Additionally, an unused commitment fee is assessed at a rate from 0.100% to 0.275% depending on our credit ratings. The unused commitment fee was 0.125% at December 31, 2017 . Borrowings under this facility may be used for general purposes, including capital expenditures. As of December 31, 2016 and 2017 , respectively, there were no borrowings outstanding under this facility, with $6.3 million obligated for letters of credit. Amounts obligated for letters of credit are not reflected as debt on our consolidated balance sheets, but decrease our borrowing capacity under the facility. Our revolving credit facility requires us to maintain a specified ratio of consolidated debt to EBITDA (as defined in the credit agreement) of no greater than 5.0 to 1.0. In addition, the revolving credit facility and the indentures under which our senior notes were issued contain covenants that limit our ability to, among other things, incur indebtedness secured by certain liens or encumber our assets, engage in certain sale-leaseback transactions and consolidate, merge or dispose of all or substantially all of our assets. We were in compliance with these covenants as of and during the year ended December 31, 2017 . Commercial Paper Program. We have a commercial paper program under which we may issue commercial paper notes in an amount up to the available capacity under our $1.0 billion revolving credit facility. The maturities of the commercial paper notes vary, but may not exceed 397 days from the date of issuance. Because the commercial paper we can issue is limited to amounts available under our revolving credit facility, amounts outstanding under the program are classified as long-term debt. The commercial paper notes are sold under customary terms in the commercial paper market and are issued at a discount from par, or alternatively, are sold at par and bear varying interest rates on a fixed or floating basis. The weighted-average interest rate for commercial paper borrowings based on the number of days outstanding was 0.8% and 1.3% , respectively, for the year ended December 31, 2016 and 2017 . During the years ending December 31, 2015 , 2016 and 2017 , total cash payments for interest on all indebtedness, excluding the impact of related interest rate swap agreements, were $156.6 million , $181.7 million and $206.2 million , respectively.

Derivative Financial Instrument

Derivative Financial Instruments	12 Months Ended
	Dec. 31, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	Derivative Financial Instruments We use derivative instruments to manage market price risks associated with inventories, interest rates, tank bottoms and certain forecasted transactions. For those instruments that qualify for hedge accounting, the accounting treatment depends on their intended use and their designation. We divide derivative financial instruments qualifying for hedge accounting treatment into two categories: (1) cash flow hedges and (2) fair value hedges. We execute cash flow hedges to hedge against the variability in cash flows related to a forecasted transaction and execute fair value hedges to hedge against the changes in the value of a recognized asset or liability. At the inception of a hedged transaction, we document the relationship between the hedging instrument and the hedged item, the risk management objectives and the methods used for assessing and testing 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 changes in fair value of derivative financial instruments that are not designated as hedges for accounting purposes, which we refer to as economic hedges, are 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. Our policies prohibit us from engaging in speculative trading activities. Interest Rate Derivatives We periodically enter into interest rate derivatives to hedge the fair value of debt or hedge against variability in interest rates. We record any ineffectiveness on interest rate derivatives designated as hedging instruments to interest expense and the change in fair value of interest rate derivatives that we do not designate as hedging instruments to other income or expense in our results of operations. For the effective portion of interest rate cash flow hedges, we record the noncurrent portion of unrealized gains or losses as an adjustment to other comprehensive income with the current portion recorded as an adjustment to interest expense. For the effective portion of fair value hedges on long-term debt, we record the noncurrent portion of gains or losses as an adjustment to long-term debt with the current portion recorded as an adjustment to interest expense. Adjustments resulting from discontinued hedges continue to be recognized in accordance with their historic hedging relationships. During 2016, we entered into $100.0 million of forward-starting interest rate swap agreements to hedge against the risk of variability of future interest payments on a portion of debt we anticipate issuing in 2018. The fair values of these contracts at December 31, 2017 were recorded on our balance sheets as other current assets of $12.2 million , with the net offset recorded to other comprehensive income. We account for these agreements as cash flow hedges. During 2015 and 2016, we entered into $250.0 million of forward-starting interest rate swap agreements to hedge against the risk of variability of future interest payments on a portion of debt we anticipated issuing in 2016. We accounted for these agreements as cash flow hedges. When we issued $500.0 million of 4.25% notes due 2046 in third quarter 2016, we settled the associated interest rate swap agreements for a loss of $19.3 million . The loss was recorded to other comprehensive income and will be recognized into earnings as an adjustment to our periodic interest expense accruals over the first ten years of the associated notes. This loss was also reported as a net payment on financial derivatives in the financing activities of our consolidated statements of cash flows in 2016. Commodity Derivatives Our butane blending activities produce gasoline, and we can reasonably estimate the timing and quantities of sales of these products. We use a combination of exchange-based commodities futures contracts and forward purchase and sale contracts to help manage commodity price changes and mitigate the risk of decline in the product margin realized from our butane blending activities. Further, certain of our other commercial operations generate petroleum products, and we also use futures contracts to hedge against price changes for some of these commodities. Forward physical purchase and sale contracts that qualify for and are elected as normal purchases and sales are accounted for using traditional accrual accounting, whereby changes in the mark-to-market values of such contracts are not recognized in income, rather the revenues and expenses associated with such transactions are recognized during the period when commodities are physically delivered or received. Physical forward commodity contracts subject to this exception are evaluated for the probability of future delivery and are periodically back-tested once the forecasted period has passed to determine whether similar forward contracts are probable of physical delivery in the future. We record the effective portion of the gains or losses for commodity-based contracts designated as fair value hedges as adjustments to the assets being hedged and the ineffective portions as well as amounts excluded from the assessment of hedge effectiveness as adjustments to other income or expense. We recognize the change in fair value of economic hedges that hedge against changes in the price of petroleum products that we expect to sell or purchase in the future currently in earnings as adjustments to product sales revenue, cost of product sales, or operating expenses, as applicable. Our open futures contracts at December 31, 2017 were as follows: Type of Contract/Accounting Methodology Product Represented by the Contract and Associated Barrels Maturity Dates Futures - Economic Hedges 4.4 million barrels of refined products and crude oil Between January 2018 and April 2019 Futures - Economic Hedges 1.5 million barrels of butane and natural gasoline Between January 2018 and April 2019 Energy Commodity Derivatives Contracts and Deposits Offsets At December 31, 2016 and 2017 , we had made margin deposits of $49.9 million and $36.7 million , respectively, for our futures contracts with our counterparties, which were recorded as a current asset under energy commodity derivatives deposits on our consolidated balance sheets. We have the right to offset the combined fair values of our open futures contracts against our margin deposits under a master netting arrangement for each counterparty; however, we have elected to present the combined fair values of our open futures contracts separately from the related margin deposits on our consolidated balance sheets. Additionally, we have the right to offset the fair values of our futures contracts 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, 2016 and 2017 (in thousands): Gross Amounts of Recognized Liabilities Gross Amounts of Assets Offset in the Consolidated Balance Sheets Net Amounts of Liabilities Presented in the Consolidated Balance Sheets Margin Deposit Amounts Not Offset in the Consolidated Balance Sheets Net Asset Amount (1) Year Ended December 31, 2016 $ (36,798 ) $ 6,060 $ (30,738 ) $ 49,899 $ 19,161 Year Ended December 31, 2017 $ (38,936 ) $ 12,851 $ (26,085 ) $ 36,690 $ 10,605 (1) This represents the maximum amount of loss we would incur if our counterparties failed to perform on their derivative contracts. (2) Net amount includes energy commodity derivative contracts classified as current liabilities of $25,694 and noncurrent liabilities of $391 . Impact of Derivatives on Our Financial Statements Comprehensive Income The changes in derivative activity included in AOCL for the years ended December 31, 2015 , 2016 and 2017 were as follows (in thousands): Year Ended December 31, Derivative Gains (Losses) Included in AOCL 2015 2016 2017 Beginning balance $ (16,587 ) $ (30,126 ) $ (34,776 ) Net loss on interest rate contract cash flow hedges (14,904 ) (6,699 ) (1,937 ) Reclassification of net loss (gain) on cash flow hedges to income 1,365 2,049 2,958 Ending balance $ (30,126 ) $ (34,776 ) $ (33,755 ) The following is a summary of the effect on our consolidated statements of income for the years ended December 31, 2015 , 2016 and 2017 of derivatives that were designated as cash flow hedges (in thousands): Interest Rate Contracts Amount of Loss Recognized in AOCL on Derivative Location of Loss Reclassified from AOCL into Income Amount of Loss Reclassified from AOCL into Income Effective Portion Ineffective Portion Year Ended December 31, 2015 $ (14,904 ) Interest expense $ (1,365 ) $ — Year Ended December 31, 2016 $ (6,699 ) Interest expense $ (2,049 ) $ — Year Ended December 31, 2017 $ (1,937 ) Interest expense $ (2,958 ) $ — As of December 31, 2017 , the net loss estimated to be classified to interest expense over the next twelve months from AOCL is approximately $3.0 million . This amount relates to the amortization of losses on interest rate swap contracts over the life of the related debt instruments. Until the third quarter of 2017, we had used futures contracts designated as fair value hedges to hedge against changes in the fair value of crude oil that was contractually reserved as tank bottoms and included with other noncurrent assets on our consolidated balance sheets. During September 2017, as a result of contract renegotiations, we sold a portion of the tank bottoms, settled the related hedges and transferred the remaining tank bottoms from noncurrent assets to PP&E. The effective portions of the fair value gains or losses on these futures contracts were offset by fair value gains or losses on the tank bottoms. There was no ineffectiveness recognized on these hedges. The cash flows from settled contracts were recorded in operating activities in our consolidated statements of cash flows. The gains (losses) on these futures contracts and the underlying tank bottoms were as follows (in millions): Year Ended December 31, 2015 2016 2017 Gain (loss) recognized in other income/expense on derivative (futures contracts) $ 15.6 $ (9.0 ) $ 4.8 Gain (loss) recognized in other income/expense on hedged item (tank bottoms) $ (15.6 ) $ 9.0 $ (4.8 ) The differential between the current spot price and forward price was excluded from the assessment of hedge effectiveness for these fair value hedges. During 2015 , 2016 and 2017 , we recognized a gain of $1.0 million , $5.2 million and $2.4 million , respectively, for the amounts we excluded from the assessment of effectiveness of these fair value hedges, which we reported as other (income) expense on our consolidated statements of income. The following table provides a summary of the effect on our consolidated statements of income for the years ended December 31, 2015 , 2016 and 2017 of derivatives accounted for as economic hedges (in thousands): Amount of Gain (Loss) Year Ended December 31, Derivative Instrument Location of Gain (Loss) Recognized on Derivative 2015 2016 2017 Futures contracts Product sales revenue $ 68,426 $ (38,584 ) $ (56,338 ) Futures contracts Cost of product sales (8,997 ) 10,998 25,566 Futures contracts Operating expenses 11,819 (5,000 ) 3,002 Total $ 71,248 $ (32,586 ) $ (27,770 ) The impact of the derivatives in the above table was reflected as cash from operations on our consolidated statements of cash flows. Balance Sheets The following tables provide a summary of the fair value of derivatives, which are presented on a net basis in our consolidated balance sheets, that were designated as hedging instruments as of December 31, 2016 and 2017 (in thousands): December 31, 2016 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value Futures contracts Energy commodity derivatives contracts, net $ — Energy commodity derivatives contracts, net $ 3,079 Interest rate contracts Other noncurrent assets 14,114 Other noncurrent liabilities — Total $ 14,114 Total $ 3,079 December 31, 2017 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value Futures contracts Energy commodity derivatives contracts, net $ — Energy commodity derivatives contracts, net $ 173 Interest rate contracts Other current assets 12,177 Other current liabilities — Total $ 12,177 Total $ 173 The following tables provide a summary of the fair value of derivatives, which are presented on a net basis in our consolidated balance sheets, that were not designated as hedging instruments as of December 31, 2016 and 2017 (in thousands): December 31, 2016 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value Futures contracts Energy commodity derivatives contracts, net $ 6,060 Energy commodity derivatives contracts, net $ 33,719 December 31, 2017 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value Futures contracts Energy commodity derivatives contracts, net $ 12,605 Energy commodity derivatives contracts, net $ 38,126 Futures contracts Other noncurrent assets 246 Other noncurrent liabilities 637 Total $ 12,851 Total $ 38,763 See Note 18 – Fair Value Disclosure s for additional details regarding our derivative contracts.

Leases

Leases	12 Months Ended
	Dec. 31, 2017
Leases [Abstract]
Leases	Leases Lessee We lease office buildings, equipment and pipeline capacity (primarily to facilitate movements on our Longhorn pipeline and Little Rock pipeline extension) and have entered into storage contracts to conduct our business operations. We have also entered into land leases and right-of-way contracts, several of which have cancellation penalties that include the requirement to remove our pipeline from the property for non-performance. Several of our agreements provide for negotiated renewal options, and 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 $25.7 million , $30.2 million and $34.8 million for the years ended December 31, 2015 , 2016 and 2017 , respectively. Future minimum annual rentals under non-cancellable operating leases and storage contracts with initial or remaining terms greater than one year as of December 31, 2017 , were as follows (in millions): 2018 $ 34.5 2019 30.9 2020 27.5 2021 27.1 2022 26.5 Thereafter 116.0 Total $ 262.5 Lessor We have entered into capacity leases and storage contracts with our customers with remaining terms from one to approximately 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, 2017 , were as follows (in millions): 2018 $ 262.9 2019 246.6 2020 178.5 2021 119.6 2022 82.9 Thereafter 168.4 Total $ 1,058.9 During 2017, we recognized contingent rental income from our condensate splitter in Corpus Christi, Texas in the amount of $24.9 million . Direct Financing Lease We entered into a long-term throughput and deficiency agreement with a customer on a 40 -mile pipeline we constructed in Texas and New Mexico, which contains minimum volume/payment commitments. This agreement is being accounted for as a direct financing lease. The net investment under direct financing leasing arrangements as of December 31, 2016 and 2017 was as follows (in millions): December 31, 2016 December 31, 2017 Total minimum lease payments receivable $ 23.3 $ 19.2 Less: Unearned income 4.8 4.1 Recorded net investment in direct financing lease $ 18.5 $ 15.1 The net investment in direct financing leases was classified in the consolidated balance sheets as follows (in millions): December 31, 2016 December 31, 2017 Other accounts receivable $ 3.4 $ 1.1 Long-term receivables 15.1 14.0 Total $ 18.5 $ 15.1 Future minimum payments receivable under this direct financing lease for the next five years are $1.7 million each year.

Long-Term Incentive Plan

Long-Term Incentive Plan	12 Months Ended
	Dec. 31, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Long-Term Incentive Plan	Long-Term Incentive Plan The compensation committee of our general partner’s board of directors administers our long-term incentive plan (“LTIP”) covering certain of our employees and the independent directors of our general partner. The LTIP primarily consists of phantom units and permits the grant of awards covering an aggregate of 11.9 million of our limited partner units. The estimated units remaining available under the LTIP at December 31, 2017 totaled approximately 2.7 million . The awards include: (i) performance-based awards issued to certain officers and other key employees (“performance-based awards”), (ii) time-based awards issued to certain officers and other key employees (“time-based awards”, and together with performance-based awards, “employee awards”), and (iii) awards issued to independent members of our general partner’s board of directors (“director awards”), which may be deferred and if deferred may be paid in cash. All of the awards include distribution equivalent rights, except non-deferred director awards. The LTIP requires employee awards to be settled in our limited partner units, except the settlement of distribution equivalents, which we pay in cash. As a result, we classify employee awards as equity. Fair value for these awards is determined on the grant date, and we recognize this value as compensation expense ratably over the requisite service period, which is the vesting period of each award. The vesting period for employee awards is generally three years; however, certain awards have been issued with shorter vesting periods while others have vesting periods of up to four years. Because employee awards contain distribution equivalent rights, the fair value of our employee awards is based on the closing price of our units on the grant date. Payouts for performance-based awards are subject to the attainment of a financial metric and to an adjustment for our total unitholder return (the “TUR adjustment”), and the fair value of these awards is adjusted for the fair value of the TUR adjustment. The financial metric for the performance-based awards is our distributable cash flow per unit excluding commodity-related activities for the last year of the three-year vesting period as compared to established threshold, target and stretch levels. The payouts for the performance-related component of the awards can range from 0% for results below threshold, up to 200% for actual results at stretch or above. The TUR adjustment is based on our total unitholder return at the end of the three-year vesting period of the awards in relation to the total unitholder returns of certain peer entities and can increase or decrease the payout of the award by as much as 50% . Payouts related to time-based awards are based solely on the completion of the requisite service period by the employee and contain no provisions that provide for a payout other than the original number of units awarded and the associated distribution equivalents. Performance-based awards are subject to forfeiture if a participant’s employment is terminated for any reason other than for termination within two years of a change-in-control that occurs on an involuntary basis without cause or on a voluntary basis for good cause, or due to retirement, disability or death prior to the vesting date. These awards can vest early under certain circumstances following a change in control. Time-based awards are subject to forfeiture if a participant’s employment is terminated for any reason other than retirement, death or disability prior to the vesting date, or as the result of certain other employment restrictions. If an employee award recipient retires, dies or becomes disabled prior to the end of the vesting period, the award is prorated based upon months of employment completed during the vesting period, and the award is settled shortly after the end of the vesting period. Compensation expense for our equity awards is calculated as the number of unit awards less forfeitures, multiplied by the 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. Non-deferred director awards are paid in units on the grant date, with compensation expense calculated as the number of units awarded multiplied by the fair value of those units at that date. We classify deferred director awards as liability awards because they may be settled in cash. Because deferred director awards have distribution equivalent rights, the fair value of these awards equals the closing price of our units at the measurement date. Compensation expense for deferred director awards is calculated as the number of units awarded, multiplied by the fair value of those awards on the measurement date, less previously-recognized compensation expense. Director awards deferred prior to 2015 are paid in January of the year following the director’s resignation from the board of directors of our general partner or death. Director awards deferred after January 1, 2015 are paid 60 days following the director’s death or resignation from the board of directors of our general partner. 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 do not include adjustments for above-target or below-target performance. Performance-Based Awards Time-Based Awards Total Awards Number of Unit Awards Weighted-Average Fair Value Number of Unit Awards Weighted-Average Fair Value Number of Unit Awards Weighted-Average Fair Value Non-vested units - 1/1/2017 313,696 $ 78.03 82,418 $ 75.36 396,114 $ 77.47 Units granted during 2017 189,544 $ 82.34 30,604 $ 79.10 220,148 $ 81.89 Units vested during 2017 (128,333 ) $ 88.75 (50,099 ) $ 82.46 (178,432 ) $ 86.99 Units forfeited during 2017 (18,839 ) $ 79.11 (1,819 ) $ 77.05 (20,658 ) $ 78.93 Non-vested units - 12/31/17 356,068 $ 76.40 61,104 $ 71.36 417,172 $ 75.66 The table below summarizes the total non-vested unit awards outstanding adjusted 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 Non-Vested Unit Awards 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: 2016 Awards 175,445 43,861 219,306 12/31/2018 $ 5.0 2017 Awards 180,623 — 180,623 12/31/2019 9.8 Time-Based Awards: 2018 Vesting Date 31,174 — 31,174 12/31/2018 0.7 2019 Vesting Date 28,214 — 28,214 12/31/2019 1.6 2020 Vesting Date 1,716 — 1,716 12/31/2020 0.1 Total 417,172 43,861 461,033 $ 17.2 (a) Unrecognized compensation expense will be recognized over the remaining vesting period of the awards. Weighted-Average Fair Value The weighted-average fair value of awards granted during 2015 , 2016 and 2017 was as follows: Performance-Based Awards Time-Based Awards Number of Unit Awards Weighted-Average Fair Value Number of Unit Awards Weighted-Average Fair Value Units granted during 2015 148,028 $ 88.78 26,421 $ 81.51 Units granted during 2016 193,344 $ 70.29 39,301 $ 64.76 Units granted during 2017 189,544 $ 82.34 30,604 $ 79.10 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, 2017 . The vested limited partner units include adjustments for above-target financial and market performance. Vesting Date Vested Limited Partner Units Fair Value of Unit Awards on Vesting Date (in millions) Intrinsic Value of Unit Awards on Vesting Date (in millions) 12/31/2015 506,393 $27.7 $34.4 12/31/2016 361,711 $22.6 $27.4 12/31/2017 266,028 $19.9 $18.9 Cash Flow Effects of LTIP Settlements The difference between the limited partner units issued to the participants and the total number of unit awards vested primarily represents the tax withholdings associated with the award settlement, which we pay in cash. Settlement Date Number of Limited Partner Units Issued, Net of Tax Withholdings Tax Withholdings and Other Cash Payments (in millions) Employer Taxes (in millions) Total Cash Taxes Paid (in millions) January 2015 354,529 $17.8 $1.7 $19.5 February 2016 350,552 $14.4 $1.4 $15.8 January 2017 216,679 $13.9 $1.2 $15.1 Compensation Expense Summary Equity-based incentive compensation expense for 2015 , 2016 and 2017 was as follows (in thousands): Year Ended December 31, 2015 2016 2017 2013 awards $ 10,658 $ — $ — 2014 awards 7,471 7,928 28 2015 awards 4,917 4,874 6,645 2016 awards — 4,304 6,125 2017 awards — — 5,025 Time-based awards 1,199 2,252 2,818 Total $ 24,245 $ 19,358 $ 20,641 Allocation of LTIP expense on our consolidated statements of income: G&A expense $ 23,937 $ 19,204 $ 20,463 Operating expense 308 154 178 Total $ 24,245 $ 19,358 $ 20,641

Segment Disclosures

Segment Disclosures	12 Months Ended
	Dec. 31, 2017
Segment Reporting [Abstract]
Segment Disclosures	Segment Disclosures Our reportable segments are strategic business units that offer different products and services. Our segments are managed separately because each segment requires different marketing strategies and business knowledge. Management evaluates performance based on segment operating margin, which includes revenue from affiliates and external customers, operating expenses, cost of product sales and earnings of non-controlled entities. We believe that investors benefit from having access to the same financial measures used by management. Operating margin, which is presented in the following tables, is an important measure used by management to evaluate the economic performance of our core operations. Operating margin is not a 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 expense that management does not consider when evaluating the core profitability of our separate operating segments. Year Ended December 31, 2015 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 974,505 $ 394,098 $ 176,143 $ — $ 1,544,746 Product sales revenue 623,102 3,587 3,147 — 629,836 Affiliate management fee revenue — 12,495 1,376 — 13,871 Total revenue 1,597,607 410,180 180,666 — 2,188,453 Operating expenses 376,279 89,001 62,221 (3,851 ) 523,650 Cost of product sales 442,621 3,278 1,374 — 447,273 (Earnings) losses of non-controlled entities 193 (63,918 ) (2,758 ) — (66,483 ) Operating margin 778,514 381,819 119,829 3,851 1,284,013 Depreciation and amortization expense 96,244 35,681 31,036 3,851 166,812 G&A expenses 93,567 35,721 20,660 — 149,948 Operating profit $ 588,703 $ 310,417 $ 68,133 $ — $ 967,253 Additions to long-lived assets $ 310,907 $ 289,851 $ 70,290 $ 671,048 As of December 31, 2015 Segment assets $ 2,991,322 $ 2,313,110 $ 677,914 $ 5,982,346 Corporate assets 59,221 Total assets $ 6,041,567 Goodwill $ 38,369 $ 12,082 $ 2,809 $ 53,260 Investments in non-controlled entities $ 12,381 $ 739,470 $ 13,777 $ 765,628 Year Ended December 31, 2016 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 1,002,368 $ 407,837 $ 181,721 $ (807 ) $ 1,591,119 Product sales revenue 561,759 31,170 6,673 — 599,602 Affiliate management fee revenue 765 12,533 1,391 — 14,689 Total revenue 1,564,892 451,540 189,785 (807 ) 2,205,410 Operating expenses 380,347 88,528 65,559 (5,762 ) 528,672 Cost of product sales 459,989 31,657 1,692 — 493,338 (Earnings) losses of non-controlled entities 968 (76,972 ) (2,692 ) — (78,696 ) Operating margin 723,588 408,327 125,226 4,955 1,262,096 Depreciation and amortization expense 103,388 38,081 31,718 4,955 178,142 G&A expenses 91,372 36,165 19,628 — 147,165 Operating profit $ 528,828 $ 334,081 $ 73,880 $ — $ 936,789 Additions to long-lived assets $ 291,202 $ 250,433 $ 104,728 $ 646,363 As of December 31, 2016 Segment assets $ 3,289,600 $ 2,631,407 $ 791,132 $ 6,712,139 Corporate assets 59,934 Total assets $ 6,772,073 Goodwill $ 38,369 $ 12,082 $ 2,809 $ 53,260 Investments in non-controlled entities $ 31,029 $ 886,920 $ 13,306 $ 931,255 Year Ended December 31, 2017 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 1,096,040 $ 458,455 $ 180,683 $ (3,403 ) $ 1,731,775 Product sales revenue 717,140 35,053 6,013 — 758,206 Affiliate management fee revenue 1,388 13,950 2,342 — 17,680 Total revenue 1,814,568 507,458 189,038 (3,403 ) 2,507,661 Operating expenses 400,439 120,920 65,296 (8,677 ) 577,978 Cost of product sales 586,751 41,325 7,541 — 635,617 (Earnings) losses of non-controlled entities 1,632 (120,173 ) (2,453 ) — (120,994 ) Operating margin 825,746 465,386 118,654 5,274 1,415,060 Depreciation and amortization expense 109,434 48,796 33,126 5,274 196,630 G&A expenses 103,225 41,490 21,002 — 165,717 Operating profit $ 613,087 $ 375,100 $ 64,526 $ — $ 1,052,713 Additions to long-lived assets $ 269,369 $ 168,306 $ 127,012 $ 564,687 As of December 31, 2017 Segment assets $ 3,499,492 $ 2,817,186 $ 871,557 $ 7,188,235 Corporate assets 206,140 Total assets $ 7,394,375 Goodwill $ 38,369 $ 12,082 $ 2,809 $ 53,260 Investments in non-controlled entities $ 29,578 $ 961,032 $ 91,901 $ 1,082,511

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Certain conditions may exist as of the date our consolidated financial statements are issued that could result in a loss to us, but which will only be resolved when one or more future events occur or fail to occur. Our management assesses such contingent liabilities, which inherently involves significant judgment. In assessing loss contingencies related to legal proceedings that are pending against us or for unasserted claims that may result in proceedings, our management, with input from legal counsel, evaluates the perceived merits of any legal proceedings or unasserted claims as well as the perceived merits of the amount of relief sought or expected to be sought therein. Environmental expenditures are charged to operating expense or capitalized based on the nature of the expenditures. Environmental expenditures that meet the capitalization criteria for property, plant and equipment, as well as costs that mitigate or prevent environmental contamination that has yet to occur, are capitalized. We expense expenditures that relate to an existing condition caused by past operations. We initially 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 specific 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. Environmental Liabilities Liabilities recognized for estimated environmental costs were $24.0 million and $19.3 million at December 31, 2016 and December 31, 2017 , respectively. We have classified environmental liabilities as current or noncurrent based on management’s estimates regarding the timing of actual payments. 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 $8.4 million , $5.9 million and $9.0 million for the years ended December 31, 2015 , 2016 and 2017 , respectively. Environmental Receivables Receivables from insurance carriers and other third parties related to environmental matters at December 31, 2016 were $4.1 million , of which $0.6 million and $3.5 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheets. Receivables from insurance carriers related to environmental matters at December 31, 2017 were $7.2 million , of which $0.5 million and $6.7 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheets. Amounts received from insurance carriers and other third parties related to environmental matters during 2015 , 2016 and 2017 were $0.5 million , $0.9 million and $0.7 million , respectively. Other See Note 4 – Investments in Non-Controlled Entities for detail of our guarantee on behalf of Powder Springs. 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 annual 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.

Fair Value Disclosures

Fair Value Disclosures	12 Months Ended
	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Fair Value Disclosures	Fair Value Disclosures Fair Value Methods and Assumptions - Financial Assets and Liabilities The following methods and assumptions were used in estimating fair value for our financial assets and liabilities: • Energy commodity derivatives contracts . These include exchange-traded futures contracts related to petroleum products. These contracts are carried at fair value on our consolidated balance sheets and are valued based on quoted prices in active markets. See Note 13 – Derivative Financial Instruments for further disclosures regarding these contracts. • Interest rate contracts. These include forward-starting interest rate swap agreements to hedge against the risk of variability of interest payments on future debt. These contracts are carried at fair value on our consolidated balance sheets and are valued based on an assumed exchange, at the end of each period, in an orderly transaction with a market participant in the market in which the financial instrument is traded. The exchange value was calculated using present value techniques on estimated future cash flows based on forward interest rate curves. See Note 13 – Derivative Financial Instruments for further disclosures regarding these contracts. • Long-term receivables. These primarily include payments receivable under a direct-financing leasing arrangement and cost reimbursement payments receivable. These receivables were recorded at fair value on our consolidated balance sheets, using then-current market rates to estimate the present value of future cash flows. • Debt. The fair value of our publicly traded notes was based on the prices of those notes at December 31, 2016 and 2017 ; however, where recent observable market trades were not available, prices were determined using adjustments to the last traded value for that debt issuance or by adjustments to the prices of similar debt instruments of peer entities that are actively traded. The carrying amount of borrowings, if any, under our revolving credit facility and our commercial paper program approximates fair value due to the frequent repricing of these obligations. Fair Value Measurements - Financial Assets and Liabilities The following tables summarize the carrying amounts, fair values and fair value measurements recorded or disclosed as of December 31, 2016 and 2017 , based on the three levels established by ASC 820; Fair Value Measurements and Disclosures (in thousands): Fair Value Measurements as of December 31, 2016 using: Assets (Liabilities) Carrying Amount Fair Value Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Energy commodity derivatives contracts $ (30,738 ) $ (30,738 ) $ (30,738 ) $ — $ — Interest rate contracts $ 14,114 $ 14,114 $ — $ 14,114 $ — Long-term receivables $ 23,870 $ 23,870 $ — $ — $ 23,870 Debt $ (4,087,192 ) $ (4,262,321 ) $ — $ (4,262,321 ) $ — Fair Value Measurements as of December 31, 2017 using: Assets (Liabilities) Carrying Amount Fair Value Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Energy commodity derivatives contracts $ (26,085 ) $ (26,085 ) $ (26,085 ) $ — $ — Interest rate contracts $ 12,177 $ 12,177 $ — $ 12,177 $ — Long-term receivables $ 27,676 $ 27,676 $ — $ — $ 27,676 Debt $ (4,524,492 ) $ (4,826,480 ) $ — $ (4,826,480 ) $ —

Partners' Capital and Distribut

Partners' Capital and Distributions	12 Months Ended
	Dec. 31, 2017
Partners' Capital Notes [Abstract]
Partners' Capital and Distributions	Partners’ Capital and Distributions Partners’ Capital In May 2017, we filed a prospectus supplement to the shelf registration statement for our continuous equity offering program (which we refer to as an at-the-market program, or “ATM”) pursuant to which we may issue up to $750.0 million of common units in amounts, at prices and on terms to be determined by market conditions at the time. The net proceeds from any sales under the ATM, after deducting the sales agents’ commissions and our offering expenses, will be used for general partnership purposes, including repayment of indebtedness or capital expenditures. No units were issued pursuant to this program during 2017. The following table details the changes in the number of our limited partner units outstanding from January 1, 2015 through December 31, 2017 : Limited partner units outstanding on January 1, 2015 227,068,257 January 2015—Settlement of employee LTIP awards 354,529 During 2015—Other (a) 4,461 Limited partner units outstanding on December 31, 2015 227,427,247 February 2016—Settlement of employee LTIP awards 350,552 During 2016—Other (a) 6,117 Limited partner units outstanding on December 31, 2016 227,783,916 January 2017—Settlement of employee LTIP awards 216,679 During 2017—Other (a) 23,961 Limited partner units outstanding on December 31, 2017 228,024,556 (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. Distributions Distributions we paid during 2015 , 2016 and 2017 were as follows (in thousands, except per unit amount): Payment Date Per Unit Cash Distribution Amount Total Cash Distribution 2/13/2015 $ 0.6950 $ 158,061 5/15/2015 0.7175 163,178 8/14/2015 0.7400 168,296 11/13/2015 0.7625 173,413 Total $ 2.9150 $ 662,948 2/12/2016 $ 0.7850 $ 178,808 5/13/2016 0.8025 182,797 8/12/2016 0.8200 186,783 11/14/2016 0.8375 190,769 Total $ 3.2450 $ 739,157 2/14/2017 $ 0.8550 $ 194,961 5/15/2017 0.8725 198,951 8/14/2017 0.8900 202,942 11/14/2017 0.9050 206,362 Total $ 3.5225 $ 803,216

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2017
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Recognizable events No recognizable events have occurred subsequent to December 31, 2017 . Non-recognizable events On January 31, 2018, we issued 170,604 limited partner units, of which 168,913 were issued to settle unit awards to certain employees that vested on December 31, 2017 and 1,691 were issued to settle the equity-based retainer paid to one independent director of our general partner. On February 1, 2018, 294,054 unit awards were granted pursuant to our LTIP. These awards included both performance-based and time-based awards and have a 3 -year vesting period that will end on December 31, 2020. On February 14, 2018, we paid cash distributions of $0.92 per unit on our outstanding limited partner units to unitholders of record at the close of business on February 6, 2018. The total distributions paid were $209.9 million .

Summary Of Significant Accoun28

Summary Of Significant Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation. Our consolidated financial statements include our refined products, crude oil and marine storage operating segments. We consolidate all entities in which we have a controlling ownership interest. We apply the equity method of accounting to investments in entities over which we exercise significant influence but do not control. We eliminate all intercompany transactions.
Use Of Estimates	Use of Estimates. The preparation of our consolidated financial statements in conformity with U.S. generally accepted accounting principles (“GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities that exist at the date of our consolidated financial statements, as well as their impact on the reported amounts of revenue and expense during the reporting periods. Actual results could differ from those estimates.
Cash Equivalents	Cash Equivalents. Cash and cash equivalents include demand and time deposits and funds that own highly marketable securities with original maturities of three months or less when acquired. We periodically assess the financial condition of the institutions where we hold these funds, and, at December 31, 2016 and 2017 , we believed our credit risk relative to these funds was minimal.
Accounts Receivable And Allowance For Doubtful Accounts	Accounts Receivable and Allowance for Doubtful Accounts. Accounts receivable represent valid claims against customers. We recognize accounts receivable when we sell products or render services and collection of the receivable is probable. We extend credit terms to certain customers based on historical dealings and to other customers after a review of various credit indicators. We establish an allowance for doubtful accounts for all or any portion of an account where we consider collections to be at risk and evaluate reserves no less than quarterly to determine their adequacy. Judgments relative to at-risk accounts include the customers’ current financial condition, the customers’ historical relationship with us and current and projected economic conditions. We write off accounts receivable when we deem an account uncollectible.
Revenue Recognition	Revenue Recognition. Revenue is recognized based on contracts or other persuasive evidence of an arrangement with the customer that includes fixed or determinable prices in which collectability is reasonably assured. We recognize revenue net of all amounts charged to our customers for excise taxes. We recognize pipeline transportation revenue for crude oil shipments when our customers’ product arrives at the customer-designated destination. For shipments of refined products and ammonia under published tariffs that combine transportation and terminalling services, we recognize revenue when our customers take delivery of their product from our system. For shipments where terminalling services are not included in the tariff, we recognize revenue when our customers’ product arrives at the customer-designated destination. We have certain agreements that require counterparties to ship a minimum volume over an agreed-upon period. Revenue pursuant to such agreements is recognized at the earlier of when the volume is shipped or when the counterparty’s ability to meet the minimum volume commitment has expired. 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. Generally, our tariffs include provisions that 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. We receive tender deductions from our customers as consideration for product shortages during the transportation of their refined products or crude oil within our pipeline systems. Our customers are guaranteed delivery of the amount of their injected volumes, net of tender deductions, irrespective of what our actual product shortages may be during the delivery process. Tender deduction revenue is recognized as transportation and terminals revenue when the transportation barrels are received and is recorded at the fair value of the product received. We recognize 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 the rendered services. Product sales revenue is recognized when the customer assumes the risks and rewards of ownership. We recognize injection service fees associated with additives upon injection to the customer’s product, which occurs at the time we deliver the product to our customers.
Deferred Transportation Revenues And Costs	Deferred Transportation Revenue and Costs. Generally, we invoice customers on our refined products pipeline for transportation services when their product enters our system. At each period end, we record all invoiced amounts associated with products that have not yet been delivered (in-transit products) as a deferred liability. The value of this liability is calculated as the total of the volume of each product type, for each pipeline region, multiplied by the average tariff rate for that product type for the most recent month invoiced to our customers. We use the most recent month’s average tariff rate because the product in our pipeline system generally turns over every month. Additionally, at each period end, we defer the direct costs we have incurred associated with these in-transit products, until delivery occurs, as a deferred asset. These direct costs are estimated based on our average per-barrel direct delivery cost for the current year multiplied by the total in-transit barrels in our system at the end of the period multiplied by 50% to reflect the average transportation costs incurred for all products across all our pipeline systems. We use 50% of the in-transit barrels because that best represents the average delivery point of all barrels in our pipeline system. These deferred revenues and costs are determined using judgments and assumptions that management considers reasonable.
Pipeline Over/Short Product	Product Overages and Shortages. Each period end we measure the volume of each type of product in our pipeline systems and terminals, which is compared to the volumes of our customers’ inventories (as adjusted for tender deductions). To the extent the product volumes in our pipeline systems and terminals exceed the volumes of our customers’ book inventories, we recognize a gain from the product overage and increase our product inventories. To the extent the product in our pipeline systems and terminals is less than our customers’ book inventories, we recognize a loss from the product shortage and we record a liability for product owed to our customers. The product overages we recognize are recorded based on market prices, and the resulting inventory is carried at weighted average cost. The product shortages we recognize are recorded based on our weighted average cost. Additionally, when product shortages result in a net short inventory position, the related liability is recorded based on period-end market prices. Product overages and shortages as well as adjustments to the value of net short inventory positions are recorded in operating expenses on our consolidated statements of income.
Income Taxes	Income Taxes. We are a partnership for income tax purposes and, therefore, are not subject to federal or state income taxes for most of the states in which we operate. The tax on our net income is borne by our limited partners through allocation to them of their share 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 consolidated statements of income are primarily comprised of partnership-level taxes levied by the state of Texas. This tax is based on revenues less direct costs of sale for our assets apportioned to the state of Texas.
Net Income Per Unit	Net Income Per Unit. We calculate basic net income per limited partner unit for each period by dividing net income by the weighted-average number of limited partner units outstanding. The difference between our actual limited partner units outstanding and our weighted-average number of limited partner units outstanding used to calculate net income per limited partner unit is due to the impact of: (i) the phantom units issued to independent directors, which are included in the calculation of basic and diluted weighted average units outstanding and (ii) the weighted-average effect of units actually issued during a period. The difference between the weighted-average number of limited partner units outstanding used for basic and diluted net income per unit calculations on our consolidated statements of income is primarily the dilutive effect of phantom unit grants associated with our long-term incentive plan, which have not yet vested in periods where contingent performance metrics have been met.
New Accounting Pronouncements	New Accounting Pronouncements In August 2017, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2017-12, Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities . This update changes GAAP’s hedge accounting requirements to simplify some of the specialized treatment’s most complex areas. These simplifications are intended to expand opportunities to use hedge accounting and better align the accounting treatment with existing risk management activities. The ASU is effective for public companies starting after December 15, 2018, and we plan to early adopt the new standard on January 1, 2018. We do not expect the adoption of this ASU to have a material impact on our consolidated financial statements. In March 2017, the FASB issued ASU 2017-07, Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost . This ASU requires companies that offer postretirement benefits to present the service cost in the same line item with other employee compensation costs. Other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations. Additionally, only the service cost component will be eligible for capitalization when applicable. Public companies must comply with the new requirements under ASU 2017-07 for fiscal years that start after December 15, 2017, and the amendments must be applied retrospectively except for the capitalization change, which should be applied prospectively. Early adoption is allowed, and we elected to adopt ASU 2017-07 as of January 1, 2017. Prior to adoption, we expensed all components of pension expense through salaries and wages, which impacted operating income. We are now recording only the service component of pension expense to salaries and wages, with the remainder of the expense being recorded to other income and expense below operating profit. Comparative prior periods have been restated for this change. The changes were not material to our financial statements. In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments: A Consensus of the FASB Emerging Issues Task Force . This ASU makes eight targeted changes to how cash receipts and cash payments are presented and classified in the statement of cash flows. Current GAAP is either unclear or does not include specific guidance on these eight issues. This ASU is effective for fiscal years beginning after December 15, 2017. We do not expect the adoption of this ASU to have a material impact on our consolidated financial statements. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842). This ASU requires lessees to recognize a right of use asset and lease liability on the balance sheets for all leases, with the exception of short-term leases. The new accounting model for lessors remains largely the same, although some changes have been made to align it with the new lessee model and the new revenue recognition guidance. This update also requires companies to include additional disclosures regarding their lessee and lessor agreements. For public companies, this ASU is effective for fiscal years that start after December 15, 2018, and early adoption is permitted. We are currently in the process of evaluating the impact this new standard will have on our financial statements. In July 2015, the FASB issued ASU 2015-11, Inventory (Topic 330): Simplifying the Measurement of Inventory . Prior to this update, reporting entities were required to measure inventory at the lower of cost or market. Market could be replacement cost, net realizable value or net realizable value less an approximately normal profit margin. Under this update, inventory is to be measured at the lower of cost or net realizable value, which is defined as the estimated selling price in the ordinary course of business, less reasonable predictable costs of completion, disposal and transportation. This ASU became effective for fiscal years beginning after December 15, 2016 and interim periods within those fiscal years. We adopted this standard on January 1, 2017, and it did not have a material impact on our results of operations, financial position or cash flows as we have historically measured our inventory at the lower of cost or net realizable value. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers. This ASU amends the existing accounting standards for revenue recognition and is based on the principle that revenue should be recognized to depict the transfer of goods or services to a customer at an amount that reflects the consideration a company expects to receive in exchange for those goods or services. We will adopt this ASU as required on January 1, 2018, using the modified retrospective method of adoption. The primary impact to the financial statements will be the addition of the new disclosure requirements, as we do not expect material changes to individual line items in the consolidated financial statements.

Investments in Non-Controlled29

Investments in Non-Controlled Entities (Policies)	12 Months Ended
	Dec. 31, 2017
Equity Method Investments and Joint Ventures [Abstract]
Investments in Non-Controlled Entities	We account for interests in affiliates that we do not control using the equity method of accounting. Under this method, an investment is recorded at our acquisition cost or capital contributions, as adjusted by contractual terms, plus equity in earnings or losses since acquisition or formation, plus interest capitalized, less distributions received and amortization of interest capitalized and excess net investment. Excess net investment is the amount by which our investment in a non-controlled entity exceeded our proportionate share of the book value of the net assets of that investment. We amortize excess net investment over the weighted-average depreciable asset lives of the equity investee. Our unamortized excess net investment was $61.3 million and $59.7 million at December 31, 2016 and 2017 , respectively. The amount of unamortized excess investment is primarily related to our investment in BridgeTex Pipeline Company, LLC. We evaluate equity method investments for impairment whenever events or circumstances indicate that there is an other-than-temporary loss in value of the investment. In the event that we determine that the loss in value of an investment is other-than-temporary, we would record a charge to earnings to adjust the carrying value to fair value. We recognized no equity investment impairments during 2015 , 2016 and 2017 .

Inventory (Policies)

Inventory (Policies)	12 Months Ended
	Dec. 31, 2017
Inventory Disclosure [Abstract]
Inventory	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 net realizable value.

Property, Plant and Equipment31

Property, Plant and Equipment and Other Intangibles (Policies)	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment consist primarily of pipeline, pipeline-related equipment, storage tanks and processing equipment. We state property, plant and equipment at cost except for certain acquired assets recorded at fair value on their respective acquisition dates and impaired assets. We record impaired assets at fair value on the last impairment evaluation date for which an adjustment was required. We assign asset lives based on reasonable estimates when we place an asset into service. Subsequent events could cause us to change our estimates, which would affect the future calculation of depreciation expense. 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 consolidated statements of income in the period of sale or disposition. We capitalize expenditures to replace existing assets and retire the replaced assets. We capitalize expenditures when they extend the useful life, increase the productivity or capacity or improve the safety or efficiency of the asset. We capitalize direct project costs such as labor and materials as incurred. Indirect project costs, such as overhead, are capitalized based on a percentage of direct labor charged to the respective capital project. We charge expenditures for maintenance, repairs and minor replacements to operating expense in the period incurred.
Goodwill and Other Intangible Assets	We record the excess of purchase price over the fair value of the tangible and identifiable intangible assets acquired and liabilities assumed as goodwill. The goodwill relating to each of our reporting units is tested for impairment annually as well as when an event, or change in circumstances, indicates an impairment may have occurred. We amortize other intangible assets with finite lives over their estimated useful lives of six years up to 30 years. The weighted-average asset life of our other intangible assets at December 31, 2017 was approximately 21 years. We adjust the useful lives of our other intangible assets if events or circumstances indicate there has been a change in the remaining useful lives. We eliminate from our balance sheets the gross carrying amount and the related accumulated amortization for any fully amortized intangibles in the year they are fully amortized.
Impairment of Long-Lived Assets	Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying value may not be recoverable. In reviewing for impairment, the carrying value of such assets is compared to the estimated undiscounted future cash flows expected from the use of the assets and their eventual disposition. If such cash flows are not sufficient to support the asset’s recorded value, an impairment charge is recognized to reduce the carrying value of the long-lived asset to its estimated fair value. The determination of future cash flows as well as the estimated fair value of long-lived assets involves significant estimates on the part of management. For purposes of performing the impairment test for goodwill, our reporting units are refined products, crude oil and marine storage. In 2015 and 2016, we elected to perform the qualitative assessment for purposes of our annual goodwill impairment test. Based on this assessment, we concluded that it was more likely than not that the fair value of each of our reporting units was greater than its carrying amount. In 2017, we elected to complete the quantitative goodwill impairment test and began with step one of the test as required by ASC 350-20-35-4. Based on this assessment, we concluded that our goodwill was not impaired. During the years ended December 31, 2015 , 2016 and 2017 , no material impairments of long-lived assets were recorded.

Employee Benefit Plans (Policie

Employee Benefit Plans (Policies)	12 Months Ended
	Dec. 31, 2017
Retirement Benefits [Abstract]
Pension And Postretirement Medical And Life Benefit Obligations	Our pension and postretirement benefit liabilities represent the funded status of the present value of benefit obligations of our employee benefit plans. We develop pension, postretirement medical and life benefit 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 expected investment return on plan assets, discount rates, health care costs trend rates, turnover rates and rates of future compensation increases, among others. In addition, we use subjective factors such as withdrawal and mortality rates to develop actuarial valuations. Management reviews and updates these assumptions on an annual basis. The actuarial assumptions that we use may differ from actual results due to changing market rates or other factors. These differences could affect the amount of pension and postretirement medical and life benefit expense we will recognize in future periods.

Derivative Financial Instrume33

Derivative Financial Instruments (Policies)	12 Months Ended
	Dec. 31, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	We use derivative instruments to manage market price risks associated with inventories, interest rates, tank bottoms and certain forecasted transactions. For those instruments that qualify for hedge accounting, the accounting treatment depends on their intended use and their designation. We divide derivative financial instruments qualifying for hedge accounting treatment into two categories: (1) cash flow hedges and (2) fair value hedges. We execute cash flow hedges to hedge against the variability in cash flows related to a forecasted transaction and execute fair value hedges to hedge against the changes in the value of a recognized asset or liability. At the inception of a hedged transaction, we document the relationship between the hedging instrument and the hedged item, the risk management objectives and the methods used for assessing and testing 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 changes in fair value of derivative financial instruments that are not designated as hedges for accounting purposes, which we refer to as economic hedges, are 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. Our policies prohibit us from engaging in speculative trading activities.

Long-Term Incentive Plan (Polic

Long-Term Incentive Plan (Policies)	12 Months Ended
	Dec. 31, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Equity-Based Incentive Compensation Awards	The compensation committee of our general partner’s board of directors administers our long-term incentive plan (“LTIP”) covering certain of our employees and the independent directors of our general partner. The LTIP primarily consists of phantom units and permits the grant of awards covering an aggregate of 11.9 million of our limited partner units. The estimated units remaining available under the LTIP at December 31, 2017 totaled approximately 2.7 million . The awards include: (i) performance-based awards issued to certain officers and other key employees (“performance-based awards”), (ii) time-based awards issued to certain officers and other key employees (“time-based awards”, and together with performance-based awards, “employee awards”), and (iii) awards issued to independent members of our general partner’s board of directors (“director awards”), which may be deferred and if deferred may be paid in cash. All of the awards include distribution equivalent rights, except non-deferred director awards. The LTIP requires employee awards to be settled in our limited partner units, except the settlement of distribution equivalents, which we pay in cash. As a result, we classify employee awards as equity. Fair value for these awards is determined on the grant date, and we recognize this value as compensation expense ratably over the requisite service period, which is the vesting period of each award. The vesting period for employee awards is generally three years; however, certain awards have been issued with shorter vesting periods while others have vesting periods of up to four years. Because employee awards contain distribution equivalent rights, the fair value of our employee awards is based on the closing price of our units on the grant date. Payouts for performance-based awards are subject to the attainment of a financial metric and to an adjustment for our total unitholder return (the “TUR adjustment”), and the fair value of these awards is adjusted for the fair value of the TUR adjustment. The financial metric for the performance-based awards is our distributable cash flow per unit excluding commodity-related activities for the last year of the three-year vesting period as compared to established threshold, target and stretch levels. The payouts for the performance-related component of the awards can range from 0% for results below threshold, up to 200% for actual results at stretch or above. The TUR adjustment is based on our total unitholder return at the end of the three-year vesting period of the awards in relation to the total unitholder returns of certain peer entities and can increase or decrease the payout of the award by as much as 50% . Payouts related to time-based awards are based solely on the completion of the requisite service period by the employee and contain no provisions that provide for a payout other than the original number of units awarded and the associated distribution equivalents. Performance-based awards are subject to forfeiture if a participant’s employment is terminated for any reason other than for termination within two years of a change-in-control that occurs on an involuntary basis without cause or on a voluntary basis for good cause, or due to retirement, disability or death prior to the vesting date. These awards can vest early under certain circumstances following a change in control. Time-based awards are subject to forfeiture if a participant’s employment is terminated for any reason other than retirement, death or disability prior to the vesting date, or as the result of certain other employment restrictions. If an employee award recipient retires, dies or becomes disabled prior to the end of the vesting period, the award is prorated based upon months of employment completed during the vesting period, and the award is settled shortly after the end of the vesting period. Compensation expense for our equity awards is calculated as the number of unit awards less forfeitures, multiplied by the 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. Non-deferred director awards are paid in units on the grant date, with compensation expense calculated as the number of units awarded multiplied by the fair value of those units at that date. We classify deferred director awards as liability awards because they may be settled in cash. Because deferred director awards have distribution equivalent rights, the fair value of these awards equals the closing price of our units at the measurement date. Compensation expense for deferred director awards is calculated as the number of units awarded, multiplied by the fair value of those awards on the measurement date, less previously-recognized compensation expense. Director awards deferred prior to 2015 are paid in January of the year following the director’s resignation from the board of directors of our general partner or death. Director awards deferred after January 1, 2015 are paid 60 days following the director’s death or resignation from the board of directors of our general partner.

Commitments and Contingencies (

Commitments and Contingencies (Policies)	12 Months Ended
	Dec. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Contingencies And Environmental	Certain conditions may exist as of the date our consolidated financial statements are issued that could result in a loss to us, but which will only be resolved when one or more future events occur or fail to occur. Our management assesses such contingent liabilities, which inherently involves significant judgment. In assessing loss contingencies related to legal proceedings that are pending against us or for unasserted claims that may result in proceedings, our management, with input from legal counsel, evaluates the perceived merits of any legal proceedings or unasserted claims as well as the perceived merits of the amount of relief sought or expected to be sought therein. Environmental expenditures are charged to operating expense or capitalized based on the nature of the expenditures. Environmental expenditures that meet the capitalization criteria for property, plant and equipment, as well as costs that mitigate or prevent environmental contamination that has yet to occur, are capitalized. We expense expenditures that relate to an existing condition caused by past operations. We initially 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 specific 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.

Consolidated Statements Of Ca36

Consolidated Statements Of Cash Flows - Supplemental Disclosures (Tables)	12 Months Ended
	Dec. 31, 2017
Supplemental Cash Flow Information [Abstract]
Consolidated Statement Of Cash Flows	Changes in the components of operating assets and liabilities are as follows (in thousands): Year Ended December 31, 2015 2016 2017 Trade accounts receivable and other accounts receivable $ 3,664 $ (31,107 ) $ (25,639 ) Inventory 26,894 (3,510 ) (47,967 ) Energy commodity derivatives contracts, net of derivatives deposits (606 ) (692 ) 8,556 Accounts payable 4,107 (4,423 ) 8,954 Accrued payroll and benefits 3,466 (6,074 ) 10,596 Accrued interest payable 5,323 14,347 5,014 Accrued taxes other than income 3,699 (1,421 ) 1,177 Deferred revenue 10,485 20,264 15,904 Accrued product liabilities (13,016 ) 20,261 44,559 Current and noncurrent environmental liabilities (4,904 ) (7,398 ) (4,766 ) Other current and noncurrent assets and liabilities 9,250 (21,762 ) (693 ) Total $ 48,362 $ (21,515 ) $ 15,695

Investments in Non-Controlled37

Investments in Non-Controlled Entities (Tables)	12 Months Ended
	Dec. 31, 2017
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Our investments in non-controlled entities at December 31, 2017 were comprised of: Entity Ownership Interest BridgeTex Pipeline Company, LLC (“BridgeTex”) 50% Double Eagle Pipeline LLC (“Double Eagle”) 50% HoustonLink Pipeline Company, LLC (“HoustonLink”) 50% MVP Terminalling, LLC (“MVP”) 50% Powder Springs Logistics, LLC (“Powder Springs”) 50% Saddlehorn Pipeline Company, LLC (“Saddlehorn”) 40% Seabrook Logistics, LLC (“Seabrook”) 50% Texas Frontera, LLC (“Texas Frontera”) 50% MVP was formed in September 2017 to construct and develop a refined products marine storage facility along the Houston Ship Channel in Pasadena, Texas. We own a 50% equity interest in MVP, with an affiliate of Valero Energy Corporation (“Valero”) owning the other 50% interest. We serve as construction manager and will serve as operator of the MVP facility. The initial phase of this facility is expected to be operational in early 2019, with the next phase of the project being completed in 2020. Upon formation of MVP, we contributed $97.6 million of property, plant and equipment (“PP&E”) to this entity. Concurrently, Valero contributed cash of $48.8 million , which was distributed to us as reimbursement for Valero’s portion of the PP&E we contributed. The $48.8 million is reflected as distributions in excess of earnings of non-controlled entities on our consolidated statements of cash flows. We receive fees for management services from BridgeTex, HoustonLink, MVP, Powder Springs, Saddlehorn, Texas Frontera and the pipeline activities of Seabrook, as well as reimbursement or payment to us for certain direct operational payroll and other overhead costs. The management fees we have received are reported as affiliate management fee revenue on our consolidated statements of income. Cost reimbursements we receive from these entities in connection with our operating services are included as reductions to costs and expenses on our consolidated statements of income and totaled $1.3 million , $4.2 million and $3.6 million , respectively, for the years ended December 31, 2015 , 2016 and 2017 . We recorded the following revenue from certain of these non-controlled entities in our consolidated statements of income (in millions): Year Ended December 31, 2015 2016 2017 Transportation and terminals revenue: BridgeTex, capacity lease $ 34.6 $ 35.5 $ 36.1 Double Eagle, throughput revenue $ 3.4 $ 3.3 $ 4.7 Saddlehorn, storage revenue $ — $ 0.7 $ 2.1 Our consolidated balance sheets reflected the following balances related to our investments in non-controlled entities (in millions): December 31, 2016 December 31, 2017 Trade Accounts Receivable Other Accounts Receivable Other Accounts Payable Trade Accounts Receivable Other Accounts Receivable Other Accounts Payable Double Eagle $ 0.3 $ — $ — $ 0.5 $ — $ — HoustonLink $ — $ — $ — $ — $ — $ 0.1 MVP $ — $ — $ — $ — $ 0.4 $ — Powder Springs $ — $ — $ — $ — $ 0.9 $ — Saddlehorn $ — $ 0.1 $ — $ — $ 0.1 $ — Seabrook $ — $ — $ — $ — $ 0.2 $ — In addition to the transactions noted above, we incurred charges of $14.5 million for transportation of crude oil at published spot tariff rates on the BridgeTex pipeline for the year ended December 31, 2017 . We recorded these charges as cost of product sales in our consolidated statements of income. We also purchased inventory from BridgeTex valued at $6.7 million during 2017. In January 2017, we entered into an agreement to guarantee our 50% pro rata share, up to $50.0 million , of obligations under Powder Springs’ credit facility. As of December 31, 2017 , we had recognized a $0.8 million other current liability and a corresponding increase in our investment in non-controlled entities on our consolidated balance sheets to reflect the fair value of this guarantee. In February 2016, we transferred a 50% membership interest in Osage Pipe Line Company, LLC (“Osage”) to an affiliate of HollyFrontier Corporation. In conjunction with this transaction, we entered into several commercial agreements with affiliates of HollyFrontier Corporation, which we recorded at that time as a $43.7 million intangible asset and an $8.3 million other receivable on our consolidated balance sheets. The intangible asset will be amortized over the 20 -year life of the contracts received. We recognized a $28.1 million non-cash gain in 2016 in relation to this transaction. The financial results from MVP and Texas Frontera are included in our marine storage segment, the financial results from BridgeTex, Double Eagle, HoustonLink, Osage, Saddlehorn and Seabrook are included in our crude oil segment and the financial results from Powder Springs are included in our refined products segment, each as earnings of non-controlled entities. A summary of our investments in non-controlled entities (representing only our proportionate interests) follows (in thousands): Investments at December 31, 2016 $ 931,255 Additional investment (1) 232,404 Earnings of non-controlled entities: Proportionate share of earnings 123,373 Amortization of excess investment and capitalized interest (2,379 ) Earnings of non-controlled entities 120,994 Less: Distributions of earnings from investments in non-controlled entities 123,660 Distributions in excess of earnings of non-controlled entities (2) 78,482 Investments at December 31, 2017 $ 1,082,511 (1) Includes our $97.6 million contribution of PP&E to MVP. (2) Includes the $48.8 million distribution to us from MVP as reimbursement for the PP&E we contributed, as well as an additional distribution of $6.2 million from BridgeTex that is not related to the ongoing operations of non-controlled entities. Summarized financial information of our non-controlled entities (representing 100% of the interests in these entities) follows (in thousands): December 31, 2016 2017 Current assets $ 208,901 $ 229,342 Noncurrent assets 1,714,920 2,057,892 Total assets $ 1,923,821 $ 2,287,234 Current liabilities $ 111,164 $ 122,198 Noncurrent liabilities 27,022 74,533 Total liabilities $ 138,186 $ 196,731 Equity $ 1,785,635 $ 2,090,503 Year Ended December 31, 2015 2016 2017 Revenue $ 246,841 $ 279,180 $ 419,214 Net income $ 138,457 $ 164,684 $ 256,423

Inventory (Tables)

Inventory (Tables)	12 Months Ended
	Dec. 31, 2017
Inventory Disclosure [Abstract]
Inventory	Inventory at December 31, 2016 and 2017 was as follows (in thousands): December 31, 2016 2017 Refined products $ 54,285 $ 73,845 Liquefied petroleum gases 24,868 45,553 Transmix 28,319 33,319 Crude oil 20,839 23,763 Additives 6,067 5,865 Total inventory $ 134,378 $ 182,345

Product Sales Revenue (Tables)

Product Sales Revenue (Tables)	12 Months Ended
	Dec. 31, 2017
Product Sales Revenue [Abstract]
Disclosure Of Product Sales Revenue	For the years ended December 31, 2015 , 2016 and 2017 , product sales revenue included the following (in thousands): Year Ended December 31, 2015 2016 2017 Physical sale of petroleum products $ 561,410 $ 638,186 $ 814,544 Change in value of futures contracts 68,426 (38,584 ) (56,338 ) Total product sales revenue $ 629,836 $ 599,602 $ 758,206

Property, Plant and Equipment40

Property, Plant and Equipment and Other Intangibles (Tables)	12 Months Ended
	Dec. 31, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, plant and equipment consisted of the following (in thousands): Estimated Depreciable Lives December 31, 2016 2017 Construction work-in-progress $ 500,208 $ 389,414 Land and rights-of-way 339,561 303,797 Buildings 101,065 114,899 10 to 56 years Storage tanks 1,829,223 1,897,046 10 to 40 years Pipeline and station equipment 2,457,429 2,581,950 10 to 69 years Processing equipment 1,350,032 1,703,478 3 to 56 years Other 206,219 244,884 3 to 53 years Property, Plant and Equipment, Gross $ 6,783,737 $ 7,235,468

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2017
Retirement Benefits [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, as well as the end-of-period accumulated benefit obligation for the years ended December 31, 2016 and 2017 (in thousands): Pension Benefits Other Postretirement Benefits 2016 2017 2016 2017 Change in benefit obligations: Benefit obligations at beginning of year $ 209,591 $ 225,970 $ 11,314 $ 13,011 Service cost 18,179 20,497 235 243 Interest cost 7,950 9,865 489 475 Plan participants’ contributions — — 217 280 Actuarial loss (gain) 1,050 59,686 1,481 (535 ) Benefits paid (10,053 ) (11,484 ) (725 ) (714 ) Settlement payments (747 ) (6,678 ) — — Benefit obligations at end of year 225,970 297,856 13,011 12,760 Change in plan assets: Fair value of plan assets at beginning of year 142,742 166,906 — — Employer contributions 25,972 26,533 508 434 Plan participants’ contributions — — 217 280 Actual return on plan assets 8,992 23,409 — — Benefits paid (10,053 ) (11,484 ) (725 ) (714 ) Settlement payments (747 ) (6,678 ) — — Fair value of plan assets at end of year 166,906 198,686 — — Funded status at end of year $ (59,064 ) $ (99,170 ) $ (13,011 ) $ (12,760 ) Accumulated benefit obligations $ 160,642 $ 206,480
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 2016 2017 2016 2017 Amounts recognized in consolidated balance sheets: Current accrued benefit cost $ — $ — $ 614 $ 625 Long-term pension and benefits 59,064 99,170 12,397 12,135 59,064 99,170 13,011 12,760 Accumulated other comprehensive loss: Net actuarial loss (62,013 ) (100,474 ) (7,881 ) (6,597 ) Prior service credit 3,429 3,248 — — (58,584 ) (97,226 ) (7,881 ) (6,597 ) Net amount of liabilities and accumulated other comprehensive loss recognized in consolidated balance sheets $ 480 $ 1,944 $ 5,130 $ 6,163
Consolidated Net Periodic Benefit Costs	Net periodic benefit expense for the years ended December 31, 2015 , 2016 and 2017 was as follows (in thousands): Pension Benefits Other Postretirement Benefits 2015 2016 2017 2015 2016 2017 Components of net periodic pension and postretirement benefit expense: Service cost $ 18,890 $ 18,179 $ 20,497 $ 243 $ 235 $ 243 Interest cost (1) 7,754 7,950 9,865 438 489 475 Expected return on plan assets (1) (8,037 ) (8,913 ) (10,266 ) — — — Amortization of prior service credit (1) — (181 ) (181 ) (3,713 ) (3,335 ) — Amortization of actuarial loss (1) 6,306 4,645 5,622 885 880 749 Settlement cost (1) — 202 2,460 — — — Net periodic expense (credit) $ 24,913 $ 21,882 $ 27,997 $ (2,147 ) $ (1,731 ) $ 1,467 (1) Upon adoption of ASU 2017-07 Compensation-Retirement Benefits (Topic 715) : Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost on January 1, 2017, these components of net periodic benefit expense (credit) are reported on the consolidated statements of income as other (income) expense. See Note 2 – Summary of Significant Accounting Policies - New Accounting Pronouncements for further details about this accounting change.
Other Changes In Plan Assets And Benefit Obligations Recognized In Other Comprehensive Loss	Changes in plan assets and benefit obligations recognized in other comprehensive loss during 2015 , 2016 and 2017 were as follows (in thousands): Pension Benefits Other Postretirement Benefits 2015 2016 2017 2015 2016 2017 Beginning balance $ (63,257 ) $ (62,279 ) $ (58,584 ) $ (1,696 ) $ (3,945 ) $ (7,881 ) Net actuarial gain (loss) (8,938 ) (971 ) (46,543 ) 579 (1,481 ) 535 Plan amendment 3,610 — — — — — Amortization of prior service credit — (181 ) (181 ) (3,713 ) (3,335 ) — Amortization of actuarial loss 6,306 4,645 5,622 885 880 749 Settlement cost — 202 2,460 — — — Amount recognized in other comprehensive loss 978 3,695 (38,642 ) (2,249 ) (3,936 ) 1,284 Ending balance $ (62,279 ) $ (58,584 ) $ (97,226 ) $ (3,945 ) $ (7,881 ) $ (6,597 )
Weighted-Average Rate Assumptions Used	The weighted-average rate assumptions used to determine benefit obligations were as follows: December 31, 2016 2017 Discount rate—Salaried plan 4.21% 3.70% Discount rate—USW plan 4.08% 3.54% Discount rate—IUOE plan 4.41% 3.79% Discount rate—Other Postretirement Benefits 3.85% 3.43% Rate of compensation increase—Salaried plan (1) 4% - 11% 4% - 11% Rate of compensation increase—USW plan 3.50% 3.50% Rate of compensation increase—IUOE plan 5.00% 5.00% (1) The rate of compensation increase assumption for the Salaried plan in 2016 and 2017 is calculated by 10-year age groupings beginning with ages 20-29 at 11% dropping to 4% by ages 70 and above. The weighted-average rate assumptions used to determine net pension and other postretirement benefit expense were as follows: For the Year Ended December 31, 2015 2016 2017 Discount rate—Salaried plan 3.91% 3.95% 4.21% Discount rate—USW plan 3.56% 3.82% 4.04% Discount rate—IUOE plan 3.93% 3.78% 4.41% Discount rate—Other Postretirement Benefits 3.66% 4.00% 3.85% Rate of compensation increase—Salaried plan (1) 5.50% 4% - 11% 4% - 11% Rate of compensation increase—USW plan 3.50% 3.50% 3.50% Rate of compensation increase—IUOE plan 5.00% 5.00% 5.00% Expected rate of return on plan assets—Salaried plan 6.00% 6.00% 6.00% Expected rate of return on plan assets—USW plan 6.00% 6.00% 6.00% Expected rate of return on plan assets—IUOE plan 6.00% 6.00% 6.00% (1) The rate of compensation increase assumption for the Salaried plan is calculated by 10-year age groupings beginning with ages 20-29 at 11% dropping to 4% by ages 70 and above.
Schedule of Allocation of Plan Assets	The target allocation and actual weighted-average asset allocation percentages at December 31, 2016 and 2017 were as follows: 2016 2017 Actual Target Actual Target Equity securities 30% 30% 37% 30% Fixed income securities 67% 67% 60% 67% Other 3% 3% 3% 3%
Fair Value, Assets Measured on Recurring Basis	The fair values of the pension plan assets at December 31, 2016 were as follows (in thousands): Asset Category Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Domestic Equity Securities (a) : Small-cap fund $ 3,465 $ 3,465 $ — $ — Mid-cap fund 3,472 3,472 — — Large-cap fund 26,323 26,323 — — International equity fund 16,797 16,797 — — Fixed Income Securities (a) : Short-term bond funds 4,414 4,414 — — Intermediate-term bond funds 23,629 23,629 — — Long-term investment grade bond funds 83,240 83,240 — — Other: Short-term investment funds 5,346 5,346 — — Group annuity contract 220 — — 220 Fair value of plan assets $ 166,906 $ 166,686 $ — $ 220 (a) We hold equity and fixed income securities through investments in mutual funds, which are dedicated to each category as indicated. The fair values of the pension plan assets at December 31, 2017 were as follows (in thousands): Asset Category Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Domestic Equity Securities (a) : Small-cap fund $ 5,122 $ 5,122 $ — $ — Mid-cap fund 5,132 5,132 — — Large-cap funds 38,678 38,678 — — International equity fund 24,284 24,284 — — Fixed Income Securities (a) : Short-term bond funds 5,110 5,110 — — Intermediate-term bond funds 25,875 25,875 — — Long-term investment grade bond funds 88,563 88,563 — — Other: Short-term investment fund 5,722 5,722 — — Group annuity contract 200 — — 200 Fair value of plan assets $ 198,686 $ 198,486 $ — $ 200 (a) We hold equity and fixed income securities through investments in mutual funds, which are dedicated to each category as indicated.
Expected Benefit Payments	As of December 31, 2017 , the benefit amounts expected to be paid from plan assets through December 31, 2027 were as follows (in thousands): Pension Benefits Other Postretirement Benefits 2018 $ 14,200 $ 625 2019 $ 13,854 $ 678 2020 $ 16,206 $ 715 2021 $ 16,556 $ 785 2022 $ 18,518 $ 844 2023 through 2027 $ 95,544 $ 4,021

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2017
Debt Disclosure [Abstract]
Consolidated Debt	Debt Long-term debt at December 31, 2016 and 2017 was as follows (in thousands): December 31, 2016 2017 Commercial paper $ 50,000 $ — 6.40% Notes due 2018 250,000 250,000 6.55% Notes due 2019 550,000 550,000 4.25% Notes due 2021 550,000 550,000 3.20% Notes due 2025 250,000 250,000 5.00% Notes due 2026 650,000 650,000 6.40% Notes due 2037 250,000 250,000 4.20% Notes due 2042 250,000 250,000 5.15% Notes due 2043 550,000 550,000 4.20% Notes due 2045 250,000 250,000 4.25% Notes due 2046 500,000 500,000 4.20% Notes due 2047 — 500,000 Face value of long-term debt 4,100,000 4,550,000 Unamortized debt issuance costs (1) (26,948 ) (29,472 ) Net unamortized debt premium (1) 6,530 215 Net unamortized amount of gains from historical fair value hedges (1) 7,610 3,749 Long-term debt, net, including current portion 4,087,192 4,524,492 Less: current portion of long-term debt, net — 250,974 Long-term debt, net $ 4,087,192 $ 4,273,518 (1) Debt issuance costs, note discounts and premiums, and realized gains and losses of historical fair value hedges are being amortized or accreted to the applicable notes over the respective lives of those notes.

Derivative Financial Instrume43

Derivative Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements	ur open futures contracts at December 31, 2017 were as follows: Type of Contract/Accounting Methodology Product Represented by the Contract and Associated Barrels Maturity Dates Futures - Economic Hedges 4.4 million barrels of refined products and crude oil Between January 2018 and April 2019 Futures - Economic Hedges 1.5 million barrels of butane and natural gasoline Between January 2018 and April 2019
Derivatives and Offset Amounts	December 31, 2016 and 2017 (in thousands): Gross Amounts of Recognized Liabilities Gross Amounts of Assets Offset in the Consolidated Balance Sheets Net Amounts of Liabilities Presented in the Consolidated Balance Sheets Margin Deposit Amounts Not Offset in the Consolidated Balance Sheets Net Asset Amount (1) Year Ended December 31, 2016 $ (36,798 ) $ 6,060 $ (30,738 ) $ 49,899 $ 19,161 Year Ended December 31, 2017 $ (38,936 ) $ 12,851 $ (26,085 ) $ 36,690 $ 10,605 (1) This represents the maximum amount of loss we would incur if our counterparties failed to perform on their derivative contracts. (2) Net amount includes energy commodity derivative contracts classified as current liabilities of $25,694 and noncurrent liabilities of $391 .
Schedule of Derivative Instruments, Effect on Other Comprehensive Income (Loss)	The changes in derivative activity included in AOCL for the years ended December 31, 2015 , 2016 and 2017 were as follows (in thousands): Year Ended December 31, Derivative Gains (Losses) Included in AOCL 2015 2016 2017 Beginning balance $ (16,587 ) $ (30,126 ) $ (34,776 ) Net loss on interest rate contract cash flow hedges (14,904 ) (6,699 ) (1,937 ) Reclassification of net loss (gain) on cash flow hedges to income 1,365 2,049 2,958 Ending balance $ (30,126 ) $ (34,776 ) $ (33,755 )
Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss)	The following is a summary of the effect on our consolidated statements of income for the years ended December 31, 2015 , 2016 and 2017 of derivatives that were designated as cash flow hedges (in thousands): Interest Rate Contracts Amount of Loss Recognized in AOCL on Derivative Location of Loss Reclassified from AOCL into Income Amount of Loss Reclassified from AOCL into Income Effective Portion Ineffective Portion Year Ended December 31, 2015 $ (14,904 ) Interest expense $ (1,365 ) $ — Year Ended December 31, 2016 $ (6,699 ) Interest expense $ (2,049 ) $ — Year Ended December 31, 2017 $ (1,937 ) Interest expense $ (2,958 ) $ —
Schedule of Fair Value Hedging Instruments, Statements of Financial Performance and Financial Position, Location	The gains (losses) on these futures contracts and the underlying tank bottoms were as follows (in millions): Year Ended December 31, 2015 2016 2017 Gain (loss) recognized in other income/expense on derivative (futures contracts) $ 15.6 $ (9.0 ) $ 4.8 Gain (loss) recognized in other income/expense on hedged item (tank bottoms) $ (15.6 ) $ 9.0 $ (4.8 )
Schedule of 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, 2015 , 2016 and 2017 of derivatives accounted for as economic hedges (in thousands): Amount of Gain (Loss) Year Ended December 31, Derivative Instrument Location of Gain (Loss) Recognized on Derivative 2015 2016 2017 Futures contracts Product sales revenue $ 68,426 $ (38,584 ) $ (56,338 ) Futures contracts Cost of product sales (8,997 ) 10,998 25,566 Futures contracts Operating expenses 11,819 (5,000 ) 3,002 Total $ 71,248 $ (32,586 ) $ (27,770 )
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following tables provide a summary of the fair value of derivatives, which are presented on a net basis in our consolidated balance sheets, that were designated as hedging instruments as of December 31, 2016 and 2017 (in thousands): December 31, 2016 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value Futures contracts Energy commodity derivatives contracts, net $ — Energy commodity derivatives contracts, net $ 3,079 Interest rate contracts Other noncurrent assets 14,114 Other noncurrent liabilities — Total $ 14,114 Total $ 3,079 December 31, 2017 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value Futures contracts Energy commodity derivatives contracts, net $ — Energy commodity derivatives contracts, net $ 173 Interest rate contracts Other current assets 12,177 Other current liabilities — Total $ 12,177 Total $ 173 The following tables provide a summary of the fair value of derivatives, which are presented on a net basis in our consolidated balance sheets, that were not designated as hedging instruments as of December 31, 2016 and 2017 (in thousands): December 31, 2016 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value Futures contracts Energy commodity derivatives contracts, net $ 6,060 Energy commodity derivatives contracts, net $ 33,719 December 31, 2017 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value Futures contracts Energy commodity derivatives contracts, net $ 12,605 Energy commodity derivatives contracts, net $ 38,126 Futures contracts Other noncurrent assets 246 Other noncurrent liabilities 637 Total $ 12,851 Total $ 38,763

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2017
Leases [Abstract]
Lessee, Future Minimum Rental Payments	Future minimum annual rentals under non-cancellable operating leases and storage contracts with initial or remaining terms greater than one year as of December 31, 2017 , were as follows (in millions): 2018 $ 34.5 2019 30.9 2020 27.5 2021 27.1 2022 26.5 Thereafter 116.0 Total $ 262.5
Lessor, Future Minimum Payments Receivable	Future minimum payments receivable under these arrangements as of December 31, 2017 , were as follows (in millions): 2018 $ 262.9 2019 246.6 2020 178.5 2021 119.6 2022 82.9 Thereafter 168.4 Total $ 1,058.9
Leases, Investment in Direct Financing Lease	The net investment under direct financing leasing arrangements as of December 31, 2016 and 2017 was as follows (in millions): December 31, 2016 December 31, 2017 Total minimum lease payments receivable $ 23.3 $ 19.2 Less: Unearned income 4.8 4.1 Recorded net investment in direct financing lease $ 18.5 $ 15.1 The net investment in direct financing leases was classified in the consolidated balance sheets as follows (in millions): December 31, 2016 December 31, 2017 Other accounts receivable $ 3.4 $ 1.1 Long-term receivables 15.1 14.0 Total $ 18.5 $ 15.1 Future minimum payments receivable under this direct financing lease for the next five years are $1.7 million each year.

Long-Term Incentive Plan (Table

Long-Term Incentive Plan (Tables)	12 Months Ended
	Dec. 31, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Changes In Non-Vested Unit Awards	The amounts below do not include adjustments for above-target or below-target performance. Performance-Based Awards Time-Based Awards Total Awards Number of Unit Awards Weighted-Average Fair Value Number of Unit Awards Weighted-Average Fair Value Number of Unit Awards Weighted-Average Fair Value Non-vested units - 1/1/2017 313,696 $ 78.03 82,418 $ 75.36 396,114 $ 77.47 Units granted during 2017 189,544 $ 82.34 30,604 $ 79.10 220,148 $ 81.89 Units vested during 2017 (128,333 ) $ 88.75 (50,099 ) $ 82.46 (178,432 ) $ 86.99 Units forfeited during 2017 (18,839 ) $ 79.11 (1,819 ) $ 77.05 (20,658 ) $ 78.93 Non-vested units - 12/31/17 356,068 $ 76.40 61,104 $ 71.36 417,172 $ 75.66
Total Non-Vested Unit Awards	The table below summarizes the total non-vested unit awards outstanding adjusted 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 Non-Vested Unit Awards 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: 2016 Awards 175,445 43,861 219,306 12/31/2018 $ 5.0 2017 Awards 180,623 — 180,623 12/31/2019 9.8 Time-Based Awards: 2018 Vesting Date 31,174 — 31,174 12/31/2018 0.7 2019 Vesting Date 28,214 — 28,214 12/31/2019 1.6 2020 Vesting Date 1,716 — 1,716 12/31/2020 0.1 Total 417,172 43,861 461,033 $ 17.2 (a) Unrecognized compensation expense will be recognized over the remaining vesting period of the awards.
Weighted-Average Grant Date Fair Values	The weighted-average fair value of awards granted during 2015 , 2016 and 2017 was as follows: Performance-Based Awards Time-Based Awards Number of Unit Awards Weighted-Average Fair Value Number of Unit Awards Weighted-Average Fair Value Units granted during 2015 148,028 $ 88.78 26,421 $ 81.51 Units granted during 2016 193,344 $ 70.29 39,301 $ 64.76 Units granted during 2017 189,544 $ 82.34 30,604 $ 79.10
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, 2017 . The vested limited partner units include adjustments for above-target financial and market performance. Vesting Date Vested Limited Partner Units Fair Value of Unit Awards on Vesting Date (in millions) Intrinsic Value of Unit Awards on Vesting Date (in millions) 12/31/2015 506,393 $27.7 $34.4 12/31/2016 361,711 $22.6 $27.4 12/31/2017 266,028 $19.9 $18.9
Cash Flow Effects Of Long Term Incentive Plan Settlements [Table Text Block]	The difference between the limited partner units issued to the participants and the total number of unit awards vested primarily represents the tax withholdings associated with the award settlement, which we pay in cash. Settlement Date Number of Limited Partner Units Issued, Net of Tax Withholdings Tax Withholdings and Other Cash Payments (in millions) Employer Taxes (in millions) Total Cash Taxes Paid (in millions) January 2015 354,529 $17.8 $1.7 $19.5 February 2016 350,552 $14.4 $1.4 $15.8 January 2017 216,679 $13.9 $1.2 $15.1
Equity-Based Incentive Compensation Expense	Equity-based incentive compensation expense for 2015 , 2016 and 2017 was as follows (in thousands): Year Ended December 31, 2015 2016 2017 2013 awards $ 10,658 $ — $ — 2014 awards 7,471 7,928 28 2015 awards 4,917 4,874 6,645 2016 awards — 4,304 6,125 2017 awards — — 5,025 Time-based awards 1,199 2,252 2,818 Total $ 24,245 $ 19,358 $ 20,641 Allocation of LTIP expense on our consolidated statements of income: G&A expense $ 23,937 $ 19,204 $ 20,463 Operating expense 308 154 178 Total $ 24,245 $ 19,358 $ 20,641

Segment Disclosures (Tables)

Segment Disclosures (Tables)	12 Months Ended
	Dec. 31, 2017
Segment Reporting [Abstract]
Segment Reporting Information By Segment	Year Ended December 31, 2015 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 974,505 $ 394,098 $ 176,143 $ — $ 1,544,746 Product sales revenue 623,102 3,587 3,147 — 629,836 Affiliate management fee revenue — 12,495 1,376 — 13,871 Total revenue 1,597,607 410,180 180,666 — 2,188,453 Operating expenses 376,279 89,001 62,221 (3,851 ) 523,650 Cost of product sales 442,621 3,278 1,374 — 447,273 (Earnings) losses of non-controlled entities 193 (63,918 ) (2,758 ) — (66,483 ) Operating margin 778,514 381,819 119,829 3,851 1,284,013 Depreciation and amortization expense 96,244 35,681 31,036 3,851 166,812 G&A expenses 93,567 35,721 20,660 — 149,948 Operating profit $ 588,703 $ 310,417 $ 68,133 $ — $ 967,253 Additions to long-lived assets $ 310,907 $ 289,851 $ 70,290 $ 671,048 As of December 31, 2015 Segment assets $ 2,991,322 $ 2,313,110 $ 677,914 $ 5,982,346 Corporate assets 59,221 Total assets $ 6,041,567 Goodwill $ 38,369 $ 12,082 $ 2,809 $ 53,260 Investments in non-controlled entities $ 12,381 $ 739,470 $ 13,777 $ 765,628 Year Ended December 31, 2016 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 1,002,368 $ 407,837 $ 181,721 $ (807 ) $ 1,591,119 Product sales revenue 561,759 31,170 6,673 — 599,602 Affiliate management fee revenue 765 12,533 1,391 — 14,689 Total revenue 1,564,892 451,540 189,785 (807 ) 2,205,410 Operating expenses 380,347 88,528 65,559 (5,762 ) 528,672 Cost of product sales 459,989 31,657 1,692 — 493,338 (Earnings) losses of non-controlled entities 968 (76,972 ) (2,692 ) — (78,696 ) Operating margin 723,588 408,327 125,226 4,955 1,262,096 Depreciation and amortization expense 103,388 38,081 31,718 4,955 178,142 G&A expenses 91,372 36,165 19,628 — 147,165 Operating profit $ 528,828 $ 334,081 $ 73,880 $ — $ 936,789 Additions to long-lived assets $ 291,202 $ 250,433 $ 104,728 $ 646,363 As of December 31, 2016 Segment assets $ 3,289,600 $ 2,631,407 $ 791,132 $ 6,712,139 Corporate assets 59,934 Total assets $ 6,772,073 Goodwill $ 38,369 $ 12,082 $ 2,809 $ 53,260 Investments in non-controlled entities $ 31,029 $ 886,920 $ 13,306 $ 931,255 Year Ended December 31, 2017 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 1,096,040 $ 458,455 $ 180,683 $ (3,403 ) $ 1,731,775 Product sales revenue 717,140 35,053 6,013 — 758,206 Affiliate management fee revenue 1,388 13,950 2,342 — 17,680 Total revenue 1,814,568 507,458 189,038 (3,403 ) 2,507,661 Operating expenses 400,439 120,920 65,296 (8,677 ) 577,978 Cost of product sales 586,751 41,325 7,541 — 635,617 (Earnings) losses of non-controlled entities 1,632 (120,173 ) (2,453 ) — (120,994 ) Operating margin 825,746 465,386 118,654 5,274 1,415,060 Depreciation and amortization expense 109,434 48,796 33,126 5,274 196,630 G&A expenses 103,225 41,490 21,002 — 165,717 Operating profit $ 613,087 $ 375,100 $ 64,526 $ — $ 1,052,713 Additions to long-lived assets $ 269,369 $ 168,306 $ 127,012 $ 564,687 As of December 31, 2017 Segment assets $ 3,499,492 $ 2,817,186 $ 871,557 $ 7,188,235 Corporate assets 206,140 Total assets $ 7,394,375 Goodwill $ 38,369 $ 12,082 $ 2,809 $ 53,260 Investments in non-controlled entities $ 29,578 $ 961,032 $ 91,901 $ 1,082,511

Fair Value Disclosures (Tables)

Fair Value Disclosures (Tables)	12 Months Ended
	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Fair Value Measurements, Recurring and Nonrecurring	The following tables summarize the carrying amounts, fair values and fair value measurements recorded or disclosed as of December 31, 2016 and 2017 , based on the three levels established by ASC 820; Fair Value Measurements and Disclosures (in thousands): Fair Value Measurements as of December 31, 2016 using: Assets (Liabilities) Carrying Amount Fair Value Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Energy commodity derivatives contracts $ (30,738 ) $ (30,738 ) $ (30,738 ) $ — $ — Interest rate contracts $ 14,114 $ 14,114 $ — $ 14,114 $ — Long-term receivables $ 23,870 $ 23,870 $ — $ — $ 23,870 Debt $ (4,087,192 ) $ (4,262,321 ) $ — $ (4,262,321 ) $ — Fair Value Measurements as of December 31, 2017 using: Assets (Liabilities) Carrying Amount Fair Value Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Energy commodity derivatives contracts $ (26,085 ) $ (26,085 ) $ (26,085 ) $ — $ — Interest rate contracts $ 12,177 $ 12,177 $ — $ 12,177 $ — Long-term receivables $ 27,676 $ 27,676 $ — $ — $ 27,676 Debt $ (4,524,492 ) $ (4,826,480 ) $ — $ (4,826,480 ) $ —

Partners' Capital and Distrib48

Partners' Capital and Distributions (Tables)	12 Months Ended
	Dec. 31, 2017
Partners' Capital Notes [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, 2015 through December 31, 2017 : Limited partner units outstanding on January 1, 2015 227,068,257 January 2015—Settlement of employee LTIP awards 354,529 During 2015—Other (a) 4,461 Limited partner units outstanding on December 31, 2015 227,427,247 February 2016—Settlement of employee LTIP awards 350,552 During 2016—Other (a) 6,117 Limited partner units outstanding on December 31, 2016 227,783,916 January 2017—Settlement of employee LTIP awards 216,679 During 2017—Other (a) 23,961 Limited partner units outstanding on December 31, 2017 228,024,556 (a) Limited partner units issued to settle the equity-based retainer paid to independent directors of our general partner.
Distributions Made to Limited Partner, by Distribution	Distributions we paid during 2015 , 2016 and 2017 were as follows (in thousands, except per unit amount): Payment Date Per Unit Cash Distribution Amount Total Cash Distribution 2/13/2015 $ 0.6950 $ 158,061 5/15/2015 0.7175 163,178 8/14/2015 0.7400 168,296 11/13/2015 0.7625 173,413 Total $ 2.9150 $ 662,948 2/12/2016 $ 0.7850 $ 178,808 5/13/2016 0.8025 182,797 8/12/2016 0.8200 186,783 11/14/2016 0.8375 190,769 Total $ 3.2450 $ 739,157 2/14/2017 $ 0.8550 $ 194,961 5/15/2017 0.8725 198,951 8/14/2017 0.8900 202,942 11/14/2017 0.9050 206,362 Total $ 3.5225 $ 803,216

Organization And Description 49

Organization And Description Of Business (Narrative) (Details) bbl in Millions	Dec. 31, 2017Terminalbblmi
Refined Products Segment [Member]
Organization and Description of Business [Line Items]
Number of Pipeline Terminals | Terminal	53
Number of Independent Terminals | Terminal	26
Refined Products Segment [Member] | Refined Products Transportation Services [Member]
Organization and Description of Business [Line Items]
Pipeline, Length | mi	9,700
Refined Products Segment [Member] | Ammonia Transportation Services [Member]
Organization and Description of Business [Line Items]
Pipeline, Length | mi	1,100
Crude Oil Pipeline and Terminals Segment [Member]
Organization and Description of Business [Line Items]
Pipeline, Length | mi	2,200
Storage Capacity | bbl	28
Contracted Storage | bbl	17
Marine Storage Segment [Member]
Organization and Description of Business [Line Items]
Number of Independent Terminals | Terminal	5
Storage Capacity | bbl	26

Summary Of Significant Accoun50

Summary Of Significant Accounting Policies (Narrative) (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015
Summary of Significant Accounting Policies [Line Items]
Equity investments, unamortized excess net investment	$ 59,700	$ 61,300
Intangible asset estimated useful life	21 years
Property, Plant and Equipment, Gross	$ 7,235,468	$ 6,783,737
Interest capitalization threshold for construction in process	$ 500
Long-term Debt, Weighted Average Interest Rate, over Time	4.80%	4.90%	4.70%
Deferred Cost Multiplier	0.5
Board of Director Deferred Award Days to Payment	60 days
Minimum [Member]
Summary of Significant Accounting Policies [Line Items]
Intangible asset estimated useful life	6 years
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Maximum [Member]
Summary of Significant Accounting Policies [Line Items]
Intangible asset estimated useful life	30 years
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	4 years
Performance Shares [Member]
Summary of Significant Accounting Policies [Line Items]
Equity-based compensation, award payout percentage, minimum	0.00%
Equity-based compensation, award payout percentage, maximum	200.00%
Equity Based Compensation Award Payout Fluctuation Of Award Market	50.00%

Consolidated Statements Of Ca51

Consolidated Statements Of Cash Flows - Supplemental Disclosures (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Supplemental Cash Flow Information [Abstract]
Increase (decrease) in long-term pension and benefits liability	$ 46	$ 2.5	$ 4.7

Consolidated Statements Of Ca52

Consolidated Statements Of Cash Flows - Supplemental Disclosures (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Supplemental Cash Flow Information [Abstract]
Trade accounts receivable and other accounts receivable	$ (25,639)	$ (31,107)	$ 3,664
Inventory	(47,967)	(3,510)	26,894
Energy commodity derivatives contracts, net of derivatives deposits	8,556	(692)	(606)
Accounts payable	8,954	(4,423)	4,107
Accrued payroll and benefits	10,596	(6,074)	3,466
Accrued interest payable	5,014	14,347	5,323
Accrued taxes other than income	1,177	(1,421)	3,699
Deferred revenue	15,904	20,264	10,485
Accrued product purchases	44,559	20,261	(13,016)
Current and noncurrent environmental liabilities	(4,766)	(7,398)	(4,904)
Other current and noncurrent assets and liabilities	(693)	(21,762)	9,250
Changes in components of operating assets and liabilities	$ 15,695	$ (21,515)	$ 48,362

Investments in Non-Controlled53

Investments in Non-Controlled Entities (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments Unamortized Excess Investment Net	$ 59.7	$ 61.3

Investments in Non-Controlled54

Investments in Non-Controlled Entities (Equity Method Investments) (Details) - USD ($) $ in Thousands		Feb. 29, 2016	Dec. 31, 2017		Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Contribution of property, plant and equipment to a non-controlled entity			$ 97,638		$ 0	$ 13,252
Transportation and terminals revenue			1,731,775		1,591,119	1,544,746
Accounts Receivable, Net, Current			138,779		105,689
Other accounts receivable			14,561		25,761
Cost of product sales			635,617		493,338	447,273
Intangible Assets, Net (Excluding Goodwill)			$ 52,764		51,976
Finite-Lived Intangible Asset, Useful Life			21 years
Gain on exchange of interest in non-controlled entity			$ 0		(28,144)	0
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2016			931,255		765,628
Additional Investments	[1]		232,404
Proportionate Share of Equity Earnings			123,373
Amortization of Excess Investment and Capitalized Interest			(2,379)
Income (Loss) from Equity Method Investments			120,994		78,696	66,483
Distributions from investments in non-controlled entities			123,660		78,723	66,285
Distributions in excess of earnings of non-controlled entities			78,482	[2]	9,264	14,155
Investments at December 31, 2017			1,082,511		931,255	765,628
Equity Method Investment, Summarized Financial Information, Current Assets			229,342		208,901
Equity Method Investment, Summarized Financial Information, Noncurrent Assets			2,057,892		1,714,920
Equity Method Investment, Summarized Financial Information, Assets			2,287,234		1,923,821
Equity Method Investment, Summarized Financial Information, Current Liabilities			122,198		111,164
Equity Method Investment, Summarized Financial Information, Noncurrent Liabilities			74,533		27,022
Equity Method Investment, Summarized Financial Information, Liabilities			196,731		138,186
Equity Method Investment Summarized Financial Information, Equity			2,090,503		1,785,635
Equity Method Investment, Summarized Financial Information, Revenue			419,214		279,180	246,841
Equity Method Investment, Summarized Financial Information, Net Income (Loss)			256,423		164,684	138,457
Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party			$ 3,600		4,200	1,300
BridgeTex [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage			50.00%
Change in Equity Method Investments [Roll Forward]
Distributions in excess of earnings of non-controlled entities			$ 6,200
BridgeTex [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Transportation and terminals revenue			36,100		35,500	34,600
Cost of product sales			14,500
Related Party Transaction, Purchases from Related Party			$ 6,700
Double Eagle Pipeline Llc [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage			50.00%
Double Eagle Pipeline Llc [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Transportation and terminals revenue			$ 4,700		3,300	3,400
Accounts Receivable, Net, Current			$ 500		300
HoustonLink Pipeline Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage			50.00%
HoustonLink Pipeline Company LLC [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Accounts Payable, Other			$ 100		0
MVP Terminalling, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage			50.00%
Joint Venture, Ownership Interest			50.00%
Contribution of property, plant and equipment to a non-controlled entity			$ 97,600
Change in Equity Method Investments [Roll Forward]
Distributions in excess of earnings of non-controlled entities			48,800
MVP Terminalling, LLC [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Other accounts receivable			$ 400		0
Powder Springs Logistics, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage			50.00%
Powder Springs Logistics, LLC [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Other accounts receivable			$ 900		0
Saddlehorn Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage			40.00%
Saddlehorn Pipeline Company [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Transportation and terminals revenue			$ 2,100		700	$ 0
Other accounts receivable			$ 100		100
Seabrook Logistics, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage			50.00%
Seabrook Logistics, LLC [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Other accounts receivable			$ 200		0
Texas Frontera Llc [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage			50.00%
Osage Pipeline Co [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50.00%
Intangible Assets, Net (Excluding Goodwill)		$ 43,700
Nontrade Receivables		$ 8,300
Finite-Lived Intangible Asset, Useful Life		20 years
Gain on exchange of interest in non-controlled entity					$ (28,100)
Guarantee of Indebtedness of Others [Member] | Powder Springs Logistics, LLC [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted			$ 50,000
Guarantees, Fair Value Disclosure			$ 800
[1]	Includes our $97.6 million contribution of PP&E to MVP.
[2]	Includes the $48.8 million distribution to us from MVP as reimbursement for the PP&E we contributed, as well as an additional distribution of $6.2 million from BridgeTex that is not related to the ongoing operations of non-controlled entities.

Business Combinations (Details)

Business Combinations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Business Combinations [Abstract]
Acquisition of business	$ 0	$ 0	$ 54,678

Inventory (Inventory) (Details)

Inventory (Inventory) (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Inventory Disclosure [Abstract]
Refined petroleum products	$ 73,845	$ 54,285
Liquefied petroleum gases	45,553	24,868
Transmix	33,319	28,319
Crude oil	23,763	20,839
Additives	5,865	6,067
Total inventory	$ 182,345	$ 134,378

Product Sales Revenue (Disclosu

Product Sales Revenue (Disclosure Of Product Sales Revenue) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Product Sales Revenue [Abstract]
Physical sale of petroleum products	$ 814,544	$ 638,186	$ 561,410
Change in value of futures contracts	(56,338)	(38,584)	68,426
Total product sales revenue	$ 758,206	$ 599,602	$ 629,836

Property, Plant and Equipment58

Property, Plant and Equipment and Other Intangibles (Narrative) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Interest Costs Threshold For Capitalization Construction In Process	$ 500
Long-term Debt, Weighted Average Interest Rate, over Time	4.80%	4.90%	4.70%
Property, Plant and Equipment, Gross	$ 7,235,468	$ 6,783,737
Depreciation expense	$ 196,300	176,700	$ 164,100
Finite-Lived Intangible Asset, Useful Life	21 years
Amortization of Intangible Assets	$ 400	1,400	$ 2,700
Property, Plant and Equipment, Other Types [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	244,884	206,219
Capitalized Interest [Member] | Property, Plant and Equipment, Other Types [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 57,300	$ 43,100
Minimum [Member]
Property, Plant and Equipment [Line Items]
Finite-Lived Intangible Asset, Useful Life	6 years
Maximum [Member]
Property, Plant and Equipment [Line Items]
Finite-Lived Intangible Asset, Useful Life	30 years

Property, Plant and Equipment59

Property, Plant and Equipment and Other Intangibles (Property, Plant And Equipment) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Long-term Debt, Weighted Average Interest Rate, over Time	4.80%	4.90%	4.70%
Property, Plant and Equipment, Gross	$ 7,235,468	$ 6,783,737
Construction in Progress [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	389,414	500,208
Land [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	303,797	339,561
Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	114,899	101,065
Storage Tanks [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	1,897,046	1,829,223
Pipelines [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	2,581,950	2,457,429
Processing Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	1,703,478	1,350,032
Property, Plant and Equipment, Other Types [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 244,884	$ 206,219
Minimum [Member] | Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	10 years
Minimum [Member] | Storage Tanks [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	10 years
Minimum [Member] | Pipelines [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	10 years
Minimum [Member] | Processing Equipment [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	3 years
Minimum [Member] | Property, Plant and Equipment, Other Types [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	3 years
Maximum [Member] | Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	56 years
Maximum [Member] | Storage Tanks [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	40 years
Maximum [Member] | Pipelines [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	69 years
Maximum [Member] | Processing Equipment [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	56 years
Maximum [Member] | Property, Plant and Equipment, Other Types [Member]
Property, Plant and Equipment [Line Items]
Estimated depreciable life, years	53 years

Major Customers and Concentra60

Major Customers and Concentration Of Risks (Details)	12 Months Ended
	Dec. 31, 2017Employee
Concentration Risk [Line Items]
Number of employees	1,802
Refined Products Segment [Member]
Concentration Risk [Line Items]
Number of employees	940
Crude Oil Pipeline and Terminals Segment [Member]
Concentration Risk [Line Items]
Number of employees	151
Marine Storage Segment [Member]
Concentration Risk [Line Items]
Number of employees	177
Customer Concentration Risk [Member]
Concentration Risk [Line Items]
Customer Concentration Risk, Benchmark Percentage	10.00%
Unionized Employees Concentration Risk [Member] | Refined Products Segment [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	24.00%
Unionized Employees Concentration Risk [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	0.00%
Unionized Employees Concentration Risk [Member] | Marine Storage Segment [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	16.00%

Employee Benefit Plans (Narrati

Employee Benefit Plans (Narrative) (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2017USD ($)pension_plan	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Defined Benefit Plan Disclosure [Line Items]
Defined contribution plan, expenses	$ 9,900	$ 9,600	$ 8,900
Number of Union Pension Plans | pension_plan	2
Defined Benefit Plan, Health Care Cost Trend Rate Assumed, Next Fiscal Year	5.40%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	4.50%
Fixed Income Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	67.00%	67.00%
Fixed Income Securities [Member] | Scenario, Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	70.00%
Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	30.00%	30.00%
Equity Securities [Member] | Scenario, Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Assets, Target Allocation, Percentage	30.00%
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Benefit Obligation	$ 297,856	$ 225,970	209,591
Defined Benefit Plan, Fair Value of Plan Assets	198,686	166,906	142,742
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	(59,686)	(1,050)
Defined Benefit Plan, Expected Amortization of Gain (Loss), Next Fiscal Year	(7,000)
Defined Benefit Plan, Expected Amortization of Prior Service Cost (Credit), Next Fiscal Year	(200)
Contributions estimated to be paid	28,100
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Benefit Obligation	12,760	13,011	11,314
Defined Benefit Plan, Fair Value of Plan Assets	0	0	$ 0
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss)	535	$ (1,481)
Defined Benefit Plan, Expected Amortization of Gain (Loss), Next Fiscal Year	(600)
Contributions estimated to be paid	500
Salaried Plan and IUOE [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Benefit Obligation	154,400
Defined Benefit Plan, Fair Value of Plan Assets	$ 145,900

Employee Benefit Plans (Changes

Employee Benefit Plans (Changes In Benefit Obligations And Plan Assets) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Pension Plan [Member]
Change in benefit obligation:
Benefit obligation at beginning of year	$ 225,970	$ 209,591
Service cost	20,497	18,179	$ 18,890
Interest cost	9,865	7,950	7,754
Defined Benefit Plan, Benefit Obligation, Contributions by Plan Participant	0	0
Actuarial loss	59,686	1,050
Benefits paid	(11,484)	(10,053)
Settlements	(6,678)	(747)
Benefit obligation at end of year	297,856	225,970	209,591
Change in plan assets:
Beginning balance	166,906	142,742
Employer contributions	26,533	25,972
Plan participants’ contributions	0	0
Actual return on plan assets	23,409	8,992
Defined Benefit Plan, Plan Assets, Benefits Paid	11,484	10,053
Defined Benefit Plan, Plan Assets, Payment for Settlement	(6,678)	(747)
Fair value of plan assets at end of year	198,686	166,906	142,742
Funded status at end of year	(99,170)	(59,064)
Accumulated benefit obligation	206,480	160,642
Other Postretirement Benefits [Member]
Change in benefit obligation:
Benefit obligation at beginning of year	13,011	11,314
Service cost	243	235	243
Interest cost	475	489	438
Defined Benefit Plan, Benefit Obligation, Contributions by Plan Participant	280	217
Actuarial loss	(535)	1,481
Benefits paid	(714)	(725)
Settlements	0	0
Benefit obligation at end of year	12,760	13,011	11,314
Change in plan assets:
Beginning balance	0	0
Employer contributions	434	508
Plan participants’ contributions	280	217
Actual return on plan assets	0	0
Defined Benefit Plan, Plan Assets, Benefits Paid	714	725
Defined Benefit Plan, Plan Assets, Payment for Settlement	0	0
Fair value of plan assets at end of year	0	0	$ 0
Funded status at end of year	$ (12,760)	$ (13,011)

Employee Benefit Plans (Amounts

Employee Benefit Plans (Amounts Recognized In Consolidated Balance Sheets) (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Amounts recognized in consolidated balance sheet:
Long-term pension and benefit cost	$ 111,305	$ 71,461
Accumulated other comprehensive loss:
Accumulated Other Comprehensive Income (Loss), Net of Tax	(137,578)	(101,241)
Pension Plan [Member]
Amounts recognized in consolidated balance sheet:
Current accrued benefit cost	0	0
Long-term pension and benefit cost	99,170	59,064
Net amount recognized in consolidated balance sheet	99,170	59,064
Accumulated other comprehensive loss:
Net actuarial loss	(100,474)	(62,013)
Prior service credit	3,248	3,429
Accumulated Other Comprehensive Income (Loss), Net of Tax	(97,226)	(58,584)	$ (62,279)	$ (63,257)
Amount of Liabilities and Accumulated Other Comprehensive Loss Recognized in Consolidated Balance Sheet	1,944	480
Other Postretirement Benefits [Member]
Amounts recognized in consolidated balance sheet:
Current accrued benefit cost	625	614
Long-term pension and benefit cost	12,135	12,397
Net amount recognized in consolidated balance sheet	12,760	13,011
Accumulated other comprehensive loss:
Net actuarial loss	(6,597)	(7,881)
Prior service credit	0	0
Accumulated Other Comprehensive Income (Loss), Net of Tax	(6,597)	(7,881)	$ (3,945)	$ (1,696)
Amount of Liabilities and Accumulated Other Comprehensive Loss Recognized in Consolidated Balance Sheet	$ 6,163	$ 5,130

Employee Benefit Plans (Consoli

Employee Benefit Plans (Consolidated Net Periodic Benefit Costs) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Pension Plan [Member]
Components of net periodic pension and postretirement benefit expense:
Service cost	$ 20,497	$ 18,179	$ 18,890
Interest cost	9,865	7,950	7,754
Expected return on plan assets	(10,266)	(8,913)	(8,037)
Amortization of prior service cost (credit)	(181)	(181)	0
Amortization of net actuarial loss	5,622	4,645	6,306
Settlement	2,460	202	0
Net periodic expense (credit)	27,997	21,882	24,913
Other Postretirement Benefits [Member]
Components of net periodic pension and postretirement benefit expense:
Service cost	243	235	243
Interest cost	475	489	438
Expected return on plan assets	0	0	0
Amortization of prior service cost (credit)	0	(3,335)	(3,713)
Amortization of net actuarial loss	749	880	885
Settlement	0	0	0
Net periodic expense (credit)	$ 1,467	$ (1,731)	$ (2,147)

Employee Benefit Plans (Other C

Employee Benefit Plans (Other Changes In Plan Assets And Benefit Obligations Recognized In Other Comprehensive Loss) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017		Dec. 31, 2016	Dec. 31, 2015
Changes in AOCL [Roll Forward]
Accumulated Other Comprehensive Income, Beginning Balance	$ (101,241)
Net actuarial loss(2)	(46,008)	[1]	$ (2,452)	$ (8,359)
Plan amendment	0	[1]	0	3,610
Amortization of prior service credit(2)	(181)	[1]	(3,516)	(3,713)
Amortization of actuarial loss(2)	6,371	[1]	5,525	7,191
Settlement cost	2,460	[1]	202	0
Total other comprehensive loss	(36,337)		(4,891)	(14,810)
Accumulated Other Comprehensive Income, Ending Balance	(137,578)		(101,241)
Pension Plan [Member]
Changes in AOCL [Roll Forward]
Accumulated Other Comprehensive Income, Beginning Balance	(58,584)		(62,279)	(63,257)
Net actuarial loss(2)	(46,543)		(971)	(8,938)
Plan amendment	0		0	3,610
Amortization of prior service credit(2)	(181)		(181)	0
Amortization of actuarial loss(2)	5,622		4,645	6,306
Settlement cost	2,460		202	0
Total other comprehensive loss	(38,642)		3,695	978
Accumulated Other Comprehensive Income, Ending Balance	(97,226)		(58,584)	(62,279)
Other Postretirement Benefits [Member]
Changes in AOCL [Roll Forward]
Accumulated Other Comprehensive Income, Beginning Balance	(7,881)		(3,945)	(1,696)
Net actuarial loss(2)	535		(1,481)	579
Plan amendment	0		0	0
Amortization of prior service credit(2)	0		(3,335)	(3,713)
Amortization of actuarial loss(2)	749		880	885
Settlement cost	0		0	0
Total other comprehensive loss	1,284		(3,936)	(2,249)
Accumulated Other Comprehensive Income, Ending Balance	$ (6,597)		$ (7,881)	$ (3,945)
[1]	{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmI4ZWY2YmRkMDE5ZjRhMTFiODJmNTYxMDNiZTMwMmU3fFRleHRTZWxlY3Rpb246QUZBQjQxRkI1MzUxRjY2NDY5QkU1MjlEODQ3Qjk0MjUM}

Employee Benefit Plans (Weighte

Employee Benefit Plans (Weighted-Average Rate Assumptions Used) (Details)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	3.43%	3.85%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	3.85%	4.00%	3.66%
Salaried Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	3.70%	4.21%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.21%	3.95%	3.91%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets	6.00%	6.00%	6.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			5.50%
U S W Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	3.54%	4.08%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	3.50%	3.50%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.04%	3.82%	3.56%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets	6.00%	6.00%	6.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	3.50%	3.50%	3.50%
I U O E Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	3.79%	4.41%
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	4.41%	3.78%	3.93%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets	6.00%	6.00%	6.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	5.00%	5.00%	5.00%
Minimum [Member] | Salaried Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	4.00%	4.00%
Minimum [Member] | U S W Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	4.00%
Minimum [Member] | Pension Plan [Member] | U S W Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase		4.00%
Maximum [Member] | Salaried Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	11.00%
Maximum [Member] | U S W Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase		11.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	11.00%	11.00%

Employee Benefit Plans (Fair Va

Employee Benefit Plans (Fair Value Of Pension Plan Assets) (Details) - Pension Plan [Member] - USD ($) $ in Thousands		Dec. 31, 2017		Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 198,686		$ 166,906	$ 142,742
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		198,486		166,686
Significant Unobservable Inputs (Level 3) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		200		220
Small-Cap Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	5,122		3,465
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	[1]	5,122		3,465
Mid-Cap Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	5,132		3,472
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	[1]	5,132		3,472
Large-Cap Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	38,678		26,323
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	[1]	38,678		26,323
International Equity Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		24,284	[1]	16,797
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		24,284	[1]	16,797
Short-Term Bond Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	5,110		4,414
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	[1]	5,110		4,414
Intermediate-Term Bond Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	25,875		23,629
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	[1]	25,875		23,629
Long-Term Investment Grade Bond Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	88,563		83,240
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	[1]	88,563		83,240
Short-Term Investment Fund [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5,722		5,346
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		5,722		5,346
Group Annuity Contract [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		200		220
Group Annuity Contract [Member] | Significant Unobservable Inputs (Level 3) [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 200		$ 220
[1]	We hold equity and fixed income securities through investments in mutual funds, which are dedicated to each category as indicated.

Employee Benefit Plans (Investm

Employee Benefit Plans (Investment Strategies) (Details)	12 Months Ended
	Dec. 31, 2017
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 funds
Fund's Investment Strategy	Seek 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 fund
Fund's Investment Strategy	Invests in high quality short-term money market instruments issued by the U.S. Treasury
Group Annuity Contract [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset Category	Group annuity contract
Fund's Investment Strategy	Earns interest quarterly equal to the effective yield of the 91-day U.S. Treasury bill

Employee Benefit Plans (Target

Employee Benefit Plans (Target Allocation And Actual Weighted-Average Asset Allocation Of Plan Assets) (Details)	Dec. 31, 2017	Dec. 31, 2016
Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Actual plan asset allocation	37.00%	30.00%
Target plan asset allocation	30.00%	30.00%
Fixed Income Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Actual plan asset allocation	60.00%	67.00%
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%	3.00%
Target plan asset allocation	3.00%	3.00%

Employee Benefit Plans (Expecte

Employee Benefit Plans (Expected Benefit Payments) (Details) $ in Thousands	Dec. 31, 2017USD ($)
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
2,018	$ 14,200
2,019	13,854
2,020	16,206
2,021	16,556
2,022	18,518
2023 through 2027	95,544
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
2,018	625
2,019	678
2,020	715
2,021	785
2,022	844
2023 through 2027	$ 4,021

Related Party Transactions (Nar

Related Party Transactions (Narrative) (Details) - Director [Member] - USD ($) $ in Millions	2 Months Ended	8 Months Ended	12 Months Ended
	Feb. 29, 2016	Dec. 31, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Targa Resource Partners L P [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$ 4.7				$ 25.5
Methvin Company [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party		$ 9.3	$ 16.6	$ 16.2
Accounts Receivable, Related Parties, Current			$ 1.6	$ 1.4

Debt (Consolidated Debt) (Detai

Debt (Consolidated Debt) (Details) - USD ($)		Dec. 31, 2017	Oct. 03, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 4,550,000,000		$ 4,100,000,000
Debt Issuance Costs, Net	[1]	(29,472,000)		(26,948,000)
Debt Instrument, Unamortized Discount (Premium), Net	[1]	215,000		6,530,000
Deferred Gain (Loss) on Discontinuation of Interest Rate Fair Value Hedge	[1]	3,749,000		7,610,000
Long-term Debt		4,524,492,000		4,087,192,000
Current portion of long-term debt, net		250,974,000		0
Long-term Debt, Excluding Current Maturities		4,273,518,000		4,087,192,000
6.40% Notes Due 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage		6.40%
6.55% Notes Due 2019 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 550,000,000		550,000,000
Debt Instrument, Interest Rate, Stated Percentage		6.55%
4.25% Notes Due 2021 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 550,000,000		550,000,000
Debt Instrument, Interest Rate, Stated Percentage		4.25%
3.20% Notes Due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage		3.20%
5.00% Notes Due 2046 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 650,000,000		650,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.00%
6.40% Notes Due 2037 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage		6.40%
4.20% Notes Due 2042 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage		4.20%
5.15% Notes Due 2043 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 550,000,000		550,000,000
Debt Instrument, Interest Rate, Stated Percentage		5.15%
4.20% Notes Due 2045 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage		4.20%
4.25% Notes Due 2046 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 500,000,000		500,000,000
Debt Instrument, Interest Rate, Stated Percentage		4.25%
4.20% Notes Due 2047 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 500,000,000	$ 500,000,000	0
Debt Instrument, Interest Rate, Stated Percentage		4.20%	4.20%
Commercial Paper [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 0		50,000,000
Line of Credit [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Long-term Debt		$ 0		$ 0
[1]	Debt issuance costs, note discounts and premiums, and realized gains and losses of historical fair value hedges are being amortized or accreted to the applicable notes over the respective lives of those notes.

Debt (Narrative) (Details)

Debt (Narrative) (Details)	Oct. 03, 2017USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months		$ 250,000,000
Long-term Debt, Maturities, Repayments of Principal in Year Two		550,000,000
Long-term Debt, Maturities, Repayments of Principal in Year Three		0
Long-term Debt, Maturities, Repayments of Principal in Year Four		550,000,000
Long-term Debt, Maturities, Repayments of Principal in Year Five		0
Long-term Debt, Maturities, Repayments of Principal after Year Five		3,200,000,000
Debt Instrument, Face Amount		4,550,000,000	$ 4,100,000,000
Proceeds from Issuance of Senior Long-term Debt		496,705,000	1,142,997,000	$ 499,589,000
Payments of Debt Issuance Costs		6,316,000	10,906,000	$ 6,223,000
Long-term Debt		$ 4,524,492,000	$ 4,087,192,000
Long-term Debt, Weighted Average Interest Rate, over Time		4.80%	4.90%	4.70%
Cash Payments for Interest		$ 206,200,000	$ 181,700,000	$ 156,600,000
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$ 1,000,000,000
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage		0.125%
Letters of Credit Outstanding, Amount		$ 6,300,000	6,300,000
Debt Instrument, Covenant Description		The revolving credit facility described above requires us to maintain a specified ratio of consolidated debt to EBITDA (as defined in the agreement) of no greater than 5.0 to 1.0
Debt Instrument, Consolidated Debt to EBITDA Ratio		5
Revolving Credit Facility [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.00%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage		0.10%
Revolving Credit Facility [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.625%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage		0.275%
Commercial Paper [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount		$ 0	$ 50,000,000
Line of Credit Facility, Maximum Borrowing Capacity		$ 1,000,000,000
Long-term Debt, Weighted Average Interest Rate, over Time		1.30%	0.80%
Commercial Paper [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Term		397 days
4.20% Notes Due 2047 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 500,000,000	$ 500,000,000	$ 0
Debt Instrument, Interest Rate, Stated Percentage	4.20%	4.20%
Debt Instrument, Notes At Price	99.341%
Proceeds from Issuance of Senior Long-term Debt	$ 491,600,000
Payments of Debt Issuance Costs	$ 5,100,000

Derivative Financial Instrume74

Derivative Financial Instruments (Narrative) (Details) - USD ($)	3 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Derivative [Line Items]
Debt Instrument, Face Amount		$ 4,550,000,000	$ 4,100,000,000
Net payment on financial derivatives		0	19,287,000	$ 42,908,000
Energy commodity derivatives deposits		36,690,000	49,899,000
Interest Expense [Member]
Derivative [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months		(3,000,000)
4.25% Notes Due 2046 [Member]
Derivative [Line Items]
Debt Instrument, Face Amount		$ 500,000,000	500,000,000
Debt Instrument, Interest Rate, Stated Percentage		4.25%
Interest Rate Contract [Member] | Future Debt Issuance 2018 [Member] | Cash Flow Hedging [Member]
Derivative [Line Items]
Derivative, Notional Amount		$ 100,000,000
Derivative Asset, Fair Value, Gross Asset		12,200,000
Interest Rate Contract [Member] | 4.25% Notes Due 2046 [Member] | Cash Flow Hedging [Member]
Derivative [Line Items]
Derivative, Notional Amount	$ 250,000,000
Debt Instrument, Face Amount	$ 500,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.25%
Net payment on financial derivatives	$ 19,300,000
Commodity Contract [Member]
Derivative [Line Items]
Gain (Loss) from Components Excluded from Assessment of Fair Value Hedge Effectiveness		$ 2,400,000	$ 5,200,000	$ 1,000,000

Derivative Financial Instrume75

Derivative Financial Instruments (Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements) (Details) bbl in Millions	Dec. 31, 2017bbl
Economic Hedges [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	4.4
Economic Hedges Futures [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	1.5

Derivative Financial Instrume76

Derivative Financial Instruments (Schedule of Derivative Offset Amounts) (Details) - Exchange Traded [Member] - USD ($) $ in Thousands		Dec. 31, 2017		Dec. 31, 2016
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Liability		$ (38,936)		$ (36,798)
Derivative Asset, Fair Value, Gross Asset		12,851		6,060
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		(26,085)	[1]	(30,738)
Derivative, Collateral, Obligation to Return Cash		(36,690)		(49,899)
Amount After Offset	[2]	10,605		$ 19,161
Other Current Liabilities [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		(25,694)
Other Noncurrent Liabilities [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral		$ (391)
[1]	Net amount includes energy commodity derivative contracts classified as current liabilities of $25,694 and noncurrent liabilities of $391.
[2]	This represents the maximum amount of loss we would incur if our counterparties failed to perform on their derivative contracts.

Derivative Financial Instrume77

Derivative Financial Instruments (Amounts Included in AOCL) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017		Dec. 31, 2016	Dec. 31, 2015
Derivative Gains Included in Accumulated Other Comprehensive Loss [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	$ (34,776)		$ (30,126)	$ (16,587)
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	(1,937)	[1]	(6,699)	(14,904)
Reclassification of net loss (gain) on cash flow hedges to income(1)	2,958	[1]	2,049	1,365
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	$ (33,755)		$ (34,776)	$ (30,126)
[1]	{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmI4ZWY2YmRkMDE5ZjRhMTFiODJmNTYxMDNiZTMwMmU3fFRleHRTZWxlY3Rpb246ODcyODM2MDY1QTcyMEYwQUExNzY1MjlEODQ3QjQ0MTcM}

Derivative Financial Instrume78

Derivative Financial Instruments (Derivatives And Hedging-Cash Flow Hedges) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017		Dec. 31, 2016	Dec. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	$ (1,937)	[1]	$ (6,699)	$ (14,904)
Cash Flow Hedging [Member] | Designated as Hedging Instrument [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	(1,937)		(6,699)	(14,904)
Cash Flow Hedging [Member] | Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Loss Reclassified from Accumulated OCI into Income, Effective Portion	(2,958)		(2,049)	(1,365)
Other Comprehensive Income (Loss), Reclassification Adjustment from AOCI on Derivatives, Net of Tax	$ 0		$ 0	$ 0
[1]	{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmI4ZWY2YmRkMDE5ZjRhMTFiODJmNTYxMDNiZTMwMmU3fFRleHRTZWxlY3Rpb246ODcyODM2MDY1QTcyMEYwQUExNzY1MjlEODQ3QjQ0MTcM}

Derivative Financial Instrume79

Derivative Financial Instruments (Fair Value Hedging Disclosures) (Details) - Commodity Contract [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Increase (Decrease) in Fair Value of Price Risk Fair Value Hedging Instruments	$ 4.8	$ (9)	$ 15.6
Increase (Decrease) in Fair Value of Hedged Item in Price Risk Fair Value Hedge	$ (4.8)	$ 9	$ (15.6)

Derivative Financial Instrume80

Derivative Financial Instruments (Derivatives And Hedging-Overall-Subsequent Measurement) (Details) - Not Designated as Hedging Instrument [Member] - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ (27,770)	$ (32,586)	$ 71,248
Sales [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(56,338)	(38,584)	68,426
Cost of Sales [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	25,566	10,998	(8,997)
Operating Expenses [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 3,002	$ (5,000)	$ 11,819

Derivative Financial Instrume81

Derivative Financial Instruments (Derivatives And Hedging-Designated) (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 12,177	$ 14,114
Derivative Liability, Fair Value, Gross Liability	173	3,079
Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	0
Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	173	3,079
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	12,177	14,114
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	0	0
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	12,851
Derivative Liability, Fair Value, Gross Liability	38,763
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	12,605	6,060
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	38,126	$ 33,719
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	246
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	$ 637

Leases (Narrative) (Details)

Leases (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)mi	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Operating Leases [Line Items]
Operating Leases, Income Statement, Contingent Revenue	$ 24.9
Total rent expense	$ 34.8	$ 30.2	$ 25.7
Minimum [Member]
Operating Leases [Line Items]
Lessor, Operating Lease, Term of Contract	1 year
Maximum [Member]
Operating Leases [Line Items]
Lessor, Operating Lease, Term of Contract	20 years
Texas and New Mexico Pipeline (Leased) [Member]
Operating Leases [Line Items]
Pipeline, Length | mi	40

Leases (Lessee, future minimum

Leases (Lessee, future minimum rental payments) (Details) $ in Millions	Dec. 31, 2017USD ($)
Leases [Abstract]
2,018	$ 34.5
2,019	30.9
2,020	27.5
2,021	27.1
2,022	26.5
Thereafter	116
Total	$ 262.5

Leases (Lessor, future minimum

Leases (Lessor, future minimum payments receivable) (Details) $ in Millions	Dec. 31, 2017USD ($)
Leases [Abstract]
2,018	$ 262.9
2,019	246.6
2,020	178.5
2,021	119.6
2,022	82.9
Thereafter	168.4
Total	$ 1,058.9

Leases (Investment in Direct Fi

Leases (Investment in Direct Financing Lease) (Details) $ in Millions	Dec. 31, 2017USD ($)mi	Dec. 31, 2016USD ($)
Direct Financing Lease [Line Items]
Direct Financing Lease, Minimum Payments to be Received	$ 19.2	$ 23.3
Direct Financing Lease, Unearned Income	4.1	4.8
Direct Financing Lease, Net Investment	15.1	18.5
Direct Financing Leases, Future Minimum Payments Receivable, Next Twelve Months	1.7
Direct Financing Leases, Future Minimum Payments, Receivable in Two Years	1.7
Direct Financing Leases, Future Minimum Payments Due in Three Years	1.7
Direct Financing Leases, Future Minimum Payments, Receivable in Four Years	1.7
Direct Financing Leases, Future Minimum Payments Due in Five Years	1.7
Other Current Assets [Member]
Direct Financing Lease [Line Items]
Direct Financing Lease, Net Investment	1.1	3.4
Other Noncurrent Assets [Member]
Direct Financing Lease [Line Items]
Direct Financing Lease, Net Investment	$ 14	$ 15.1
Texas and New Mexico Pipeline (Leased) [Member]
Direct Financing Lease [Line Items]
Pipeline, Length | mi	40

Long-Term Incentive Plan (Narra

Long-Term Incentive Plan (Narrative) (Details) shares in Millions	12 Months Ended
	Dec. 31, 2017shares
Long Term Incentive Plan [Line Items]
Board of Director Deferred Award Days to Payment	60 days
Limited partners' capital account, units issued	11.9
Limited partner unitholders, units remaining available	2.7
Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Equity Based Compensation, Award Payout Percentage, Minimum	0.00%
Equity Based Compensation, Award Payout Percentage, Maximum	200.00%
Equity Based Compensation Award Payout Fluctuation Of Award Market	50.00%
Minimum [Member]
Long Term Incentive Plan [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Maximum [Member]
Long Term Incentive Plan [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	4 years

Long-Term Incentive Plan (Chang

Long-Term Incentive Plan (Changes In Non-Vested Unit Awards) (Details) - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Non-vested units - 1/1/2017	396,114
Units granted	220,148
Units vested during 2017	(178,432)
Units forfeited during 2017	(20,658)
Non-vested units - 12/31/17	417,172	396,114
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 - 1/1/2017	$ 77.47
Units granted during 2017	81.89
Units vested during 2017	86.99
Units forfeited during 2017	78.93
Non-vested units - 12/31/17	$ 75.66	$ 77.47
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 - 1/1/2017	313,696
Units granted	189,544	193,344	148,028
Units vested during 2017	(128,333)
Units forfeited during 2017	(18,839)
Non-vested units - 12/31/17	356,068	313,696
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 - 1/1/2017	$ 78.03
Units granted during 2017	82.34	$ 70.29	$ 88.78
Units vested during 2017	88.75
Units forfeited during 2017	79.11
Non-vested units - 12/31/17	$ 76.40	$ 78.03
Time-Based 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 - 1/1/2017	82,418
Units granted	30,604	39,301	26,421
Units vested during 2017	(50,099)
Units forfeited during 2017	(1,819)
Non-vested units - 12/31/17	61,104	82,418
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 - 1/1/2017	$ 75.36
Units granted during 2017	79.10	$ 64.76	$ 81.51
Units vested during 2017	82.46
Units forfeited during 2017	77.05
Non-vested units - 12/31/17	$ 71.36	$ 75.36

Long-Term Incentive Plan (Total

Long-Term Incentive Plan (Total Non-Vested Unit Awards) (Details) - USD ($) $ in Millions		Dec. 31, 2017	Dec. 31, 2016
Long Term Incentive Plan [Line Items]
Non-vested units		417,172	396,114
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results		43,861
Total Unit Award Accrual		461,033
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	[1]	$ 17.2
Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Non-vested units		356,068	313,696
Time-Based Awards [Member]
Long Term Incentive Plan [Line Items]
Non-vested units		61,104	82,418
2016 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Non-vested units		175,445
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results		43,861
Total Unit Award Accrual		219,306
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	[1]	$ 5
2017 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Non-vested units		180,623
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results		0
Total Unit Award Accrual		180,623
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	[1]	$ 9.8
Retention Awards Vesting 2018 [Member] | Time-Based Awards [Member]
Long Term Incentive Plan [Line Items]
Non-vested units		31,174
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results		0
Total Unit Award Accrual		31,174
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	[1]	$ 0.7
Retention Awards Vesting 2019 [Member] | Time-Based Awards [Member]
Long Term Incentive Plan [Line Items]
Non-vested units		28,214
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results		0
Total Unit Award Accrual		28,214
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	[1]	$ 1.6
Retention Awards Vesting 2020 [Member] | Time-Based Awards [Member]
Long Term Incentive Plan [Line Items]
Non-vested units		1,716
Adjustment to Unit Awards in Anticipation of Achieving Above- Target Financial Results		0
Total Unit Award Accrual		1,716
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	[1]	$ 0.1
[1]	Unrecognized compensation expense will be recognized over the remaining vesting period of the awards.

Long-Term Incentive Plan (Weigh

Long-Term Incentive Plan (Weighted-Average Grant Date Fair Values) (Details) - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Long Term Incentive Plan [Line Items]
Units granted	220,148
Weighted-Average Grant Date Fair Value	$ 81.89
Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Units granted	189,544	193,344	148,028
Weighted-Average Grant Date Fair Value	$ 82.34	$ 70.29	$ 88.78
Time-Based Awards [Member]
Long Term Incentive Plan [Line Items]
Units granted	30,604	39,301	26,421
Weighted-Average Grant Date Fair Value	$ 79.10	$ 64.76	$ 81.51

Long-Term Incentive Plan (Veste

Long-Term Incentive Plan (Vested Unit Awards) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Nonvested Total Unit Award Accrual Number	266,028	361,711	506,393
Fair Value of Unit Awards on Vesting Date (in millions)	$ 19.9	$ 22.6	$ 27.7
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Vested	$ 18.9	$ 27.4	$ 34.4

Long-Term Incentive Plan (Cash

Long-Term Incentive Plan (Cash Flow Effects Of LTIP Settlements) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Partners' Capital Account, Units, Unit-based Compensation	216,679	350,552	354,529
Settlement of tax withholdings on long-term incentive compensation	$ 13,875	$ 14,376	$ 17,784
Payments for Other Taxes	1,200	1,400	1,700
Total Cash Taxes Paid (in millions)	$ 15,100	$ 15,800	$ 19,500

Long-Term Incentive Plan (Equit

Long-Term Incentive Plan (Equity-Based Incentive Compensation Expense) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	$ 20,641	$ 19,358	$ 24,245
G&A Expense [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	20,463	19,204	23,937
Operating Expenses [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	178	154	308
Time-Based Awards [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	2,818	2,252	1,199
2013 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	0	0	10,658
2014 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	28	7,928	7,471
2015 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	6,645	4,874	4,917
2016 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	6,125	4,304	0
2017 Awards [Member] | Performance Shares [Member]
Long Term Incentive Plan [Line Items]
Allocation of LTIP expense on Consolidated Statements of Income	$ 5,025	$ 0	$ 0

Segment Disclosures (Segment Re

Segment Disclosures (Segment Reporting Information By Segment) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Transportation and terminals revenue	$ 1,731,775	$ 1,591,119	$ 1,544,746
Product sales revenue	758,206	599,602	629,836
Affiliate management fee revenue	17,680	14,689	13,871
Total revenue	2,507,661	2,205,410	2,188,453
Operating expenses	577,978	528,672	523,650
Cost of product sales	635,617	493,338	447,273
Earnings of non-controlled entities	(120,994)	(78,696)	(66,483)
Operating margin	1,415,060	1,262,096	1,284,013
Depreciation and amortization expense	196,630	178,142	166,812
G&A expenses	165,717	147,165	149,948
Operating profit	1,052,713	936,789	967,253
Total assets	7,394,375	6,772,073	6,041,567
Goodwill	53,260	53,260	53,260
Investments in non-controlled entities	1,082,511	931,255	765,628
Operating Segments [Member]
Segment Reporting Information [Line Items]
Additions to long-lived assets	564,687	646,363	671,048
Total assets	7,188,235	6,712,139	5,982,346
Operating Segments [Member] | Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue	1,096,040	1,002,368	974,505
Product sales revenue	717,140	561,759	623,102
Affiliate management fee revenue	1,388	765	0
Total revenue	1,814,568	1,564,892	1,597,607
Operating expenses	400,439	380,347	376,279
Cost of product sales	586,751	459,989	442,621
Earnings of non-controlled entities	1,632	968	193
Operating margin	825,746	723,588	778,514
Depreciation and amortization expense	109,434	103,388	96,244
G&A expenses	103,225	91,372	93,567
Operating profit	613,087	528,828	588,703
Additions to long-lived assets	269,369	291,202	310,907
Total assets	3,499,492	3,289,600	2,991,322
Goodwill	38,369	38,369	38,369
Investments in non-controlled entities	29,578	31,029	12,381
Operating Segments [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue	458,455	407,837	394,098
Product sales revenue	35,053	31,170	3,587
Affiliate management fee revenue	13,950	12,533	12,495
Total revenue	507,458	451,540	410,180
Operating expenses	120,920	88,528	89,001
Cost of product sales	41,325	31,657	3,278
Earnings of non-controlled entities	(120,173)	(76,972)	(63,918)
Operating margin	465,386	408,327	381,819
Depreciation and amortization expense	48,796	38,081	35,681
G&A expenses	41,490	36,165	35,721
Operating profit	375,100	334,081	310,417
Additions to long-lived assets	168,306	250,433	289,851
Total assets	2,817,186	2,631,407	2,313,110
Goodwill	12,082	12,082	12,082
Investments in non-controlled entities	961,032	886,920	739,470
Operating Segments [Member] | Marine Storage Segment [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue	180,683	181,721	176,143
Product sales revenue	6,013	6,673	3,147
Affiliate management fee revenue	2,342	1,391	1,376
Total revenue	189,038	189,785	180,666
Operating expenses	65,296	65,559	62,221
Cost of product sales	7,541	1,692	1,374
Earnings of non-controlled entities	(2,453)	(2,692)	(2,758)
Operating margin	118,654	125,226	119,829
Depreciation and amortization expense	33,126	31,718	31,036
G&A expenses	21,002	19,628	20,660
Operating profit	64,526	73,880	68,133
Additions to long-lived assets	127,012	104,728	70,290
Total assets	871,557	791,132	677,914
Goodwill	2,809	2,809	2,809
Investments in non-controlled entities	91,901	13,306	13,777
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Total assets	206,140	59,934	59,221
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue	(3,403)	(807)	0
Product sales revenue	0	0	0
Affiliate management fee revenue	0	0	0
Total revenue	(3,403)	(807)	0
Operating expenses	(8,677)	(5,762)	(3,851)
Cost of product sales	0	0	0
Earnings of non-controlled entities	0	0	0
Operating margin	5,274	4,955	3,851
Depreciation and amortization expense	5,274	4,955	3,851
G&A expenses	0	0	0
Operating profit	$ 0	$ 0	$ 0

Commitments and Contingencies94

Commitments and Contingencies (Details) (Narrative) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies	$ 19.3	$ 24
Environmental Remediation Expense	9	5.9	$ 8.4
Recorded Third-Party Environmental Recoveries Receivable	7.2	4.1
Recorded Third-Party Environmental Recoveries, Amount	0.7	0.9	$ 0.5
Accounts Receivable [Member]
Loss Contingencies [Line Items]
Recorded Third-Party Environmental Recoveries Receivable	0.5	0.6
Other Noncurrent Assets [Member]
Loss Contingencies [Line Items]
Recorded Third-Party Environmental Recoveries Receivable	$ 6.7	$ 3.5

Fair Value Disclosures (Details

Fair Value Disclosures (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term receivables	$ 0	$ 0
Debt	0	0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term receivables	0	0
Debt	(4,826,480)	(4,262,321)
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term receivables	27,676	23,870
Debt	0	0
Commodity Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	(26,085)	(30,738)
Commodity Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	0	0
Commodity Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	0	0
Interest Rate Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	0	0
Interest Rate Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	12,177	14,114
Interest Rate Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	0	0
Reported Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term receivables	27,676	23,870
Debt	(4,524,492)	(4,087,192)
Reported Value Measurement [Member] | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	(26,085)	(30,738)
Reported Value Measurement [Member] | Interest Rate Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	12,177	14,114
Estimate of Fair Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term receivables	27,676	23,870
Debt	(4,826,480)	(4,262,321)
Estimate of Fair Value Measurement [Member] | Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	(26,085)	(30,738)
Estimate of Fair Value Measurement [Member] | Interest Rate Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	$ 12,177	$ 14,114

Partners' Capital and Distrib96

Partners' Capital and Distributions (Changes In Limited Partner Units Outstanding) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Capital Unit [Line Items]
Amount Authorized Under Equity Distribution Agreement		$ 750
Limited Partners' Capital Account [Roll Forward]
Limited partner unitholders, units outstanding		227,783,916	227,427,247	227,068,257
Partners' Capital Account, Units, Unit-based Compensation		216,679	350,552	354,529
Limited partner unitholders, units outstanding		228,024,556	227,783,916	227,427,247
Limited Partners' Capital Account, Right to Receive Distribution in Cash, Period		45 days
Limited Partners' Capital Account, Removal of Magellan GP, LLC, Percentage Vote		100.00%
Limited Partners' Capital Account, Annual Report Available, Period		120 days
Limited Partners' Capital Account, Tax Reporting Information, Period		90 days
Management [Member]
Limited Partners' Capital Account [Roll Forward]
Partners' Capital Account, Units, Unit-based Compensation		216,679	350,552	354,529
Director [Member]
Limited Partners' Capital Account [Roll Forward]
Partners' Capital Account, Units, Unit-based Compensation	[1]	23,961	6,117	4,461
[1]	Limited partner units issued to settle the equity-based retainer paid to independent directors of our general partner.

Partners' Capital and Distrib97

Partners' Capital and Distributions Partners' Capital and Distributions (Distributions) (Details) - USD ($) $ / shares in Units, $ in Thousands	Nov. 14, 2017	Aug. 14, 2017	May 15, 2017	Feb. 14, 2017	Nov. 14, 2016	Aug. 12, 2016	May 13, 2016	Feb. 12, 2016	Nov. 13, 2015	Aug. 14, 2015	May 15, 2015	Feb. 13, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Partners' Capital Notes [Abstract]
Partners' Capital Account, Distribution Per Unit of Limited Partner Interest	$ 0.9050	$ 0.8900	$ 0.8725	$ 0.8550	$ 0.83750	$ 0.8200	$ 0.8025	$ 0.7850	$ 0.7625	$ 0.7400	$ 0.7175	$ 0.6950	$ 3.5225	$ 3.245	$ 2.915
Limited Partners' Capital Account, Distribution Amount	$ 206,362	$ 202,942	$ 198,951	$ 194,961	$ 190,769	$ 186,783	$ 182,797	$ 178,808	$ 173,413	$ 168,296	$ 163,178	$ 158,061	$ 803,216	$ 739,157	$ 662,948

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Thousands		Feb. 14, 2018	Feb. 01, 2018	Jan. 31, 2018	Nov. 14, 2017	Aug. 14, 2017	May 15, 2017	Feb. 14, 2017	Nov. 14, 2016	Aug. 12, 2016	May 13, 2016	Feb. 12, 2016	Nov. 13, 2015	Aug. 14, 2015	May 15, 2015	Feb. 13, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Subsequent Event [Line Items]
Partners' Capital Account, Units, Unit-based Compensation																	216,679	350,552	354,529
Units granted																	220,148
Partners' Capital Account, Distribution Per Unit of Limited Partner Interest					$ 0.9050	$ 0.8900	$ 0.8725	$ 0.8550	$ 0.83750	$ 0.8200	$ 0.8025	$ 0.7850	$ 0.7625	$ 0.7400	$ 0.7175	$ 0.6950	$ 3.5225	$ 3.245	$ 2.915
Total cash distributions					$ 206,362	$ 202,942	$ 198,951	$ 194,961	$ 190,769	$ 186,783	$ 182,797	$ 178,808	$ 173,413	$ 168,296	$ 163,178	$ 158,061	$ 803,216	$ 739,157	$ 662,948
Subsequent Event [Member]
Subsequent Event [Line Items]
Partners' Capital Account, Units, Unit-based Compensation				170,604
Units granted			294,054
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			3 years
Partners' Capital Account, Distribution Per Unit of Limited Partner Interest		$ 0.920
Total cash distributions		$ 209,900
Management [Member]
Subsequent Event [Line Items]
Partners' Capital Account, Units, Unit-based Compensation																	216,679	350,552	354,529
Management [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Partners' Capital Account, Units, Unit-based Compensation				168,913
Director [Member]
Subsequent Event [Line Items]
Partners' Capital Account, Units, Unit-based Compensation	[1]																23,961	6,117	4,461
Director [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Partners' Capital Account, Units, Unit-based Compensation				1,691
[1]	Limited partner units issued to settle the equity-based retainer paid to independent directors of our general partner.