Magellan Midstream Partners (MMP) 10-Q 2 Aug 18 2018 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	6 Months Ended
	Jun. 30, 2018	Aug. 01, 2018
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q2
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

Consolidated Statements Of Inco

Consolidated Statements Of Income - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Income Statement [Abstract]
Transportation and terminals revenue	$ 472,248	$ 433,239	$ 904,185	$ 825,910
Product sales revenue	166,797	182,004	408,389	427,624
Affiliate management fee revenue	5,046	4,197	10,296	7,980
Total revenue	644,091	619,440	1,322,870	1,261,514
Costs and expenses:
Operating	159,845	145,294	303,141	276,886
Cost of product sales	153,679	145,975	353,271	318,851
Depreciation and amortization	53,619	48,896	105,498	96,194
General and administrative	53,290	43,393	99,846	83,674
Total costs and expenses	420,433	383,558	861,756	775,605
Earnings of non-controlled entities	42,510	25,576	77,048	47,022
Operating profit	266,168	261,458	538,162	532,931
Interest expense	56,750	51,546	113,402	102,758
Interest capitalized	(5,608)	(3,183)	(10,255)	(7,380)
Interest income	(380)	(256)	(959)	(548)
Other (income) expense	(119)	2,043	8,605	3,213
Income before provision for income taxes	215,525	211,308	427,369	434,888
Provision for income taxes	1,116	908	2,050	1,752
Net income	$ 214,409	$ 210,400	$ 425,319	$ 433,136
Basic net income per limited partner unit (in dollars per share)	$ 0.94	$ 0.92	$ 1.86	$ 1.90
Diluted net income per limited partner unit (in dollars per share)	$ 0.94	$ 0.92	$ 1.86	$ 1.90
Weighted average number of limited partner units outstanding used for basic net income per unit calculation (in dollars per share)	228,387	228,192	228,354	228,151
Weighted average number of limited partner units outstanding used for diluted net income per unit calculation (in dollars per share)	228,425	228,245	228,393	228,202

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Statement of Comprehensive Income [Abstract]
Net income	$ 214,409	$ 210,400	$ 425,319	$ 433,136
Other comprehensive income:
Net gain (loss) on cash flow hedges	1,697	(2,802)	7,111	(1,507)
Reclassification of net loss on cash flow hedges to income	739	739	1,479	1,479
Net actuarial loss	653	0	(5,291)	0
Amortization of prior service credit	(46)	(46)	(91)	(91)
Amortization of actuarial loss	1,703	1,983	6,817	3,211
Settlement cost	0	361	0	1,726
Total other comprehensive income	4,746	235	10,025	4,818
Comprehensive income	$ 219,155	$ 210,635	$ 435,344	$ 437,954

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 2,467	$ 160,840
Trade accounts receivable	106,679	138,779
Other accounts receivable	21,922	14,561
Inventory	183,578	182,345
Energy commodity derivatives deposits	35,610	36,690
Other current assets	75,282	63,396
Total current assets	425,538	596,611
Property, plant and equipment	7,443,095	7,235,468
Less: accumulated depreciation	1,783,036	1,682,633
Net property, plant and equipment	5,660,059	5,552,835
Investments in non-controlled entities	1,210,259	1,082,511
Long-term receivables	23,875	27,676
Goodwill	53,260	53,260
Other intangibles (less accumulated amortization of $1,389 and $2,035 at December 31, 2017 and June 30, 2018, respectively)	52,118	52,764
Restricted cash	101,590	15,228
Other noncurrent assets	11,603	13,490
Total assets	7,538,302	7,394,375
Current liabilities:
Accounts payable	125,216	104,852
Accrued payroll and benefits	45,191	56,261
Accrued interest payable	70,595	70,657
Accrued taxes other than income	41,144	51,343
Environmental liabilities	5,424	6,235
Deferred revenue	120,134	117,795
Accrued product liabilities	64,017	96,159
Energy commodity derivatives contracts, net	27,368	25,694
Current portion of long-term debt, net	250,046	250,974
Other current liabilities	33,603	56,540
Total current liabilities	782,738	836,510
Long-term debt, net	4,392,027	4,273,518
Long-term pension and benefits	127,849	111,305
Other noncurrent liabilities	69,526	30,350
Environmental liabilities	11,870	13,039
Commitments and contingencies
Partners’ capital:
Limited partner unitholders (228,025 units and 228,195 units outstanding at December 31, 2017 and June 30, 2018, respectively)	2,281,845	2,267,231
Accumulated other comprehensive loss	(127,553)	(137,578)
Total partners’ capital	2,154,292	2,129,653
Total liabilities and partners’ capital	$ 7,538,302	$ 7,394,375

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Other intangibles, accumulated amortization	$ 2,035	$ 1,389
Limited partner unitholders, units outstanding (in shares)	228,195,160	228,024,556

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Operating Activities:
Net income	$ 425,319	$ 433,136
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	105,498	96,194
Loss on sale and retirement of assets	4,586	5,331
Earnings of non-controlled entities	(77,048)	(47,022)
Distributions of earnings from investments in non-controlled entities	94,661	57,906
Equity-based incentive compensation expense	16,679	10,717
Settlement cost, amortization of prior service credit and actuarial loss	6,726	4,846
Changes in operating assets and liabilities:
Trade accounts receivable and other accounts receivable	24,739	2,681
Inventory	(1,233)	14,927
Energy commodity derivatives contracts, net of derivatives deposits	2,363	10,538
Accounts payable	18,843	13,132
Accrued payroll and benefits	(11,070)	(5,509)
Accrued interest payable	(62)	(184)
Accrued taxes other than income	(10,199)	(6,757)
Accrued product liabilities	(32,142)	(4,797)
Deferred revenue	4,240	13,132
Current and noncurrent environmental liabilities	(1,980)	(5,189)
Other current and noncurrent assets and liabilities	(5,854)	(9,519)
Net cash provided by operating activities	564,066	583,563
Investing Activities:
Additions to property, plant and equipment, net	(219,442)	(281,504)
Proceeds from sale and disposition of assets	241	4,886
Investments in non-controlled entities	(144,859)	(55,273)
Deposits received from undivided joint interest partner	41,571	0
Net cash used by investing activities	(322,489)	(331,891)
Financing Activities:
Distributions paid	(423,873)	(393,912)
Net commercial paper borrowings	119,896	146,885
Debt placement costs	(326)	0
Payments associated with settlement of equity-based incentive compensation	(9,285)	(13,875)
Net cash used by financing activities	(313,588)	(260,902)
Change in cash, cash equivalents and restricted cash	(72,011)	(9,230)
Cash, cash equivalents and restricted cash at beginning of period	176,068	14,701
Cash, cash equivalents and restricted cash at end of period	104,057	5,471
Supplemental non-cash investing and financing activities:
Issuance of limited partner units in settlement of equity-based incentive plan awards	120	1,669
Additions to property, plant and equipment	(219,828)	(289,570)
Changes in accounts payable and other current liabilities related to capital expenditures	386	8,066
Additions to property, plant and equipment, net	$ (219,442)	$ (281,504)

Organization, Description of Bu

Organization, Description of Business And Basis Of Presentation	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization, Description of Business and Basis of Presentation	Organization, Description of Business and Basis of Presentation Organization Unless indicated otherwise, the terms “our,” “we,” “us” and similar language refer to Magellan Midstream Partners, L.P. together with its subsidiaries. Magellan Midstream Partners, L.P. is a Delaware limited partnership and its limited partner units are traded on the New York Stock Exchange under the ticker symbol “MMP.” Magellan GP, LLC, a wholly-owned Delaware limited liability company, serves as 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 June 30, 2018 , 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 storage capacity of approximately 28 million barrels, of which approximately 17 million barrels 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. 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, aviation fuel, kerosene 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. Basis of Presentation In the opinion of management, our accompanying consolidated financial statements which are unaudited, except for the consolidated balance sheet as of December 31, 2017 , which is derived from our audited financial statements, include all normal and recurring adjustments necessary to present fairly our financial position as of June 30, 2018 , the results of operations for the three and six months ended June 30, 2017 and 2018 and cash flows for the six months ended June 30, 2017 and 2018 . The results of operations for the six months ended June 30, 2018 are not necessarily indicative of the results to be expected for the full year ending December 31, 2018 for several reasons. Profits from our butane blending activities are realized largely during the first and fourth quarters of each year. Additionally, gasoline demand, which drives transportation volumes and revenues on our refined products pipeline system, generally trends higher during the summer driving months. Further, the volatility of commodity prices impacts the profits from our commodity activities and, to a lesser extent, the volume of petroleum products we transport on our pipelines. Pursuant to the rules and regulations of the Securities and Exchange Commission, the financial statements in this report do not include all of the information and notes normally included with financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”). These financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2017 . Reclassifications. Prior year amounts related to restricted cash have been reclassified to conform with the current period’s presentation. Use of Estimates The preparation of our consolidated financial statements in conformity with 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. Restricted Cash Restricted cash includes cash held by us, which is contractually required to be used for the construction of fixed assets, and is unavailable for general use. It is classified as noncurrent due to its designation to be used for the acquisition or construction of noncurrent assets. Correction of Actuarial Valuation Error In first quarter 2018, an error was discovered in our third-party actuary’s valuation of our pension liabilities and net periodic pension expenses dating back to 2010. The impacts of the error were not material to any of our prior period financial statements and the cumulative impact was corrected with a one-time adjustment in the first quarter of 2018. As a result, during first quarter 2018, net periodic pension expenses were increased by $16.0 million ( $5.7 million operating expense, $3.4 million general and administrative (“G&A”) costs and $6.9 million other expense below operating profit on our consolidated statements of income). In addition, long-term pension and benefits was increased $18.8 million and accumulated other comprehensive loss was increased by $2.8 million on our consolidated balance sheets. New Accounting Pronouncements In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-02, Leases (Topic 842). This ASU requires lessees to recognize a right of use asset and lease liability on the balance sheet 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. New Accounting Pronouncements - Adopted January 1, 2018 In August 2017, the FASB issued 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 early-adopted the new standard on January 1, 2018. The adoption of this ASU did not have a material impact on our consolidated 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 includes a requirement to make an accounting policy election to classify distributions received from equity method investees under either (1) the cumulative earnings approach, where distributions in excess of equity earnings are considered a return of capital and classified as cash inflows from investing activities, or (2) the nature of the distribution approach, where each distribution is evaluated on the basis of the source of the payment and classified as either operating or investing cash inflows. We adopted this standard on January 1, 2018 using the retrospective transition method and made an accounting policy election to use the nature of the distribution approach, which resulted in the following adjustments to our June 30, 2017 comparative statement of cash flows (in thousands): Six Months Ended June 30, 2017, as Reported ASU 2016-15 Adjustment Six Months Ended June 30, 2017, as Adjusted Operating activities: Distributions of earnings from investments in non-controlled entities $ 46,754 $ 11,152 $ 57,906 Net cash provided by operating activities $ 572,411 $ 11,152 $ 583,563 Investing activities: Distributions in excess of earnings of non-controlled entities $ 11,152 $ (11,152 ) $ — Net cash used by investing activities $ (320,739 ) $ (11,152 ) $ (331,891 ) In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). 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. On January 1, 2018, we adopted the new Accounting Standards Codification (“ASC”) 606, Revenue from Contracts with Customers and all the related amendments using the modified retrospective method. We recognized the cumulative effect of initially applying the new revenue standard as an adjustment to the opening balance of partners’ capital. The comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. The cumulative effect of the changes made to our consolidated January 1, 2018 balance sheet resulting from the adoption of the new revenue standard was as follows (in thousands): Balance at December 31, 2017 Adjustments Due to ASU 2014-09 Balance at January 1, 2018 Assets: Property, plant and equipment $ 7,235,468 $ 8,516 $ 7,243,984 Accumulated depreciation (1,682,633 ) (325 ) (1,682,958 ) Net property, plant and equipment $ 5,552,835 $ 8,191 $ 5,561,026 Investments in non-controlled entities $ 1,082,511 $ 502 $ 1,083,013 Liabilities: Deferred revenue $ 117,795 $ (1,901 ) $ 115,894 Other noncurrent liabilities $ 30,350 $ 4,619 $ 34,969 Partners’ capital: Limited partner unitholders $ 2,267,231 $ 5,975 $ 2,273,206 The primary changes impacting our financial statements under the new revenue standard include the requirement for us to estimate deficiencies in our customers’ use of our services contracted as minimum commitments and adjust the amount of revenue recognized in proportion to our customers’ pattern of exercised rights. This change results in accelerating the timing of revenue recognized for specific contracts for which we estimate our customers will not ship their minimum commitments. In addition, we periodically receive payments from customers seeking to expand their access to our pipeline systems and terminals. Prior to the adoption of the new revenue standard, these payments were recorded as reductions to our property, plant and equipment (“PP&E”) expenditures. Under the new revenue standard, these payments are recorded to deferred revenue and other noncurrent liabilities and are recognized as revenue in proportion to the related services provided. The impact of this change increases our revenues, contract liabilities, PP&E and depreciation expense. We expect the impact of the adoption of the new revenue standard, including these changes, to be immaterial to our net income on an ongoing basis.

Revenue from Contract with Cust

Revenue from Contract with Customers	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer	Revenue from Contracts with Customers Adoption of ASC 606, Revenue from Contracts with Customers The table below provides the amount by which financial statement line items are affected in the current reporting period by the application of the new revenue standard, as compared with the guidance that was in effect before the change (in thousands): As Reported Amounts without adoption of ASC 606 Effect of Change Higher/(Lower) Statements of Income: Three Months Ended June 30, 2018 Transportation and terminals revenue $ 472,248 $ 465,079 $ 7,169 Depreciation and amortization $ 53,619 $ 53,555 $ 64 Six Months Ended June 30, 2018 Transportation and terminals revenue $ 904,185 $ 896,603 $ 7,582 Depreciation and amortization $ 105,498 $ 105,378 $ 120 Balance Sheet: As of June 30, 2018 Assets: Property, plant and equipment $ 7,443,095 $ 7,433,091 $ 10,004 Accumulated depreciation 1,783,036 1,782,591 445 Net property, plant and equipment $ 5,660,059 $ 5,650,500 $ 9,559 Investments in non-controlled entities $ 1,210,259 $ 1,209,757 $ 502 Liabilities: Deferred revenue $ 120,134 $ 128,349 $ (8,215 ) Other noncurrent liabilities $ 69,526 $ 64,687 $ 4,839 Partners’ capital: Limited partner unitholders $ 2,281,845 $ 2,268,408 $ 13,437 Revenue recognition policies Revenue is recognized upon the satisfaction of each performance obligation required by our customer contracts. Transportation and terminals revenue is recognized over time as our customers receive the benefits of our service as it is performed on their behalf using an output method based on actual deliveries. Revenue for our storage services is recognized over time using an output method based on the capacity of storage under contract with our customers. Product sales revenue is recognized at a point in time when our customers take control of the commodities purchased. We record back-to-back purchases and sales of petroleum products where we are acting as an agent on a net basis. We recognize pipeline transportation revenue for crude oil and ammonia shipments when our customers’ product arrives at the customer-designated destination. For shipments of refined products 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 contracts that require counterparties to ship a minimum volume over an agreed-upon time period, which are contracted as minimum dollar or volume commitments. Revenue pursuant to these take-or-pay contracts is recognized when the customers utilize their committed volumes. Additionally, when we estimate that the customers will not utilize all or a portion of their committed volumes, we recognize revenue in proportion to the pattern of exercised rights for the respective commitment period. Our interstate common carrier petroleum products pipeline operations are subject to rate regulation by the Federal Energy Regulatory Commission (“FERC”) under the Interstate Commerce Act, the Energy Policy Act of 1992 and rules and orders promulgated pursuant thereto. FERC regulation requires that interstate pipeline rates be filed with the FERC, be posted publicly and be nondiscriminatory and “just and reasonable.” The rates on approximately 40% of the shipments on our refined products pipeline system are regulated by the FERC primarily through an index methodology. As an alternative to cost-of-service or index-based rates, interstate pipeline companies may establish rates by obtaining authority to charge market-based rates in competitive markets or by negotiation with unaffiliated shippers. Approximately 60% of our refined products pipeline system’s markets are either subject to regulations by the states in which we operate or are approved for market-based rates by the FERC, and in both cases these rates can generally be adjusted at our discretion based on market factors. Most of the tariffs on our crude oil pipelines are established by negotiated rates that generally provide for annual adjustments in line with changes in the FERC index, subject to certain modifications. For both our index-based rates and our market-based rates, our published tariffs serve as contracts, and shippers nominate the volume to be shipped up to a month in advance. These tariffs include provisions which allow us to deduct from our customer’s inventory a small percentage of the products our customers transport on our pipeline systems. We refer to this non-monetary consideration as tender deduction revenue. We receive tender deductions from our customers as consideration for product losses during the transportation of petroleum products within our pipeline systems. Tender deduction revenue is generally recognized as transportation revenue when the customer's transported commodities reach their destination and is recorded at the fair value of the product received on the date received or the contract date, as applicable. Product sales revenue pricing is contractually specified, and we have determined that each barrel sold represents a separate performance obligation. Transaction prices for our other services including terminalling, storage and ancillary services are typically contracted as a single performance obligation with our customers. In circumstances where multiple performance obligations are contractually required, we allocate the transaction price to the various performance obligations based on their relative standalone selling price. Statement of Income Disclosures The following tables provide details of our revenues disaggregated by key activities that comprise our performance obligations by operating segment (in thousands): Three Months Ended June 30, 2018 Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation $ 184,596 $ 84,755 $ — $ — $ 269,351 Terminalling 50,574 — 592 — 51,166 Storage 24,969 28,536 33,319 (915 ) 85,909 Ancillary services 28,459 8,199 6,037 — 42,695 Lease revenue 2,466 16,463 4,198 — 23,127 Transportation and terminals revenue 291,064 137,953 44,146 (915 ) 472,248 Product sales revenue 150,934 13,282 2,581 — 166,797 Affiliate management fee revenue 352 3,849 845 — 5,046 Total revenue 442,350 155,084 47,572 (915 ) 644,091 Revenue not under the guidance of ASC 606: Lease revenue (1) (2,466 ) (16,463 ) (4,198 ) — (23,127 ) Losses from futures contracts included in product sales revenue (2) 34,840 3,570 — — 38,410 Affiliate management fee revenue (352 ) (3,849 ) (845 ) — (5,046 ) Total revenue from contracts with customers under ASC 606 $ 474,372 $ 138,342 $ 42,529 $ (915 ) $ 654,328 (1) Lease revenue is accounted for under ASC 840, Leases . (2) The impact on product sales revenue from futures contracts falls under the guidance of ASC 815, Derivatives and Hedging . Six Months Ended June 30, 2018 Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation $ 351,498 $ 163,878 $ — $ — $ 515,376 Terminalling 89,922 — 1,304 — 91,226 Storage 50,216 58,526 67,530 (1,830 ) 174,442 Ancillary services 54,247 13,234 13,071 — 80,552 Lease revenue 5,575 28,573 8,441 — 42,589 Transportation and terminals revenue 551,458 264,211 90,346 (1,830 ) 904,185 Product sales revenue 383,708 19,721 4,960 — 408,389 Affiliate management fee revenue 649 7,865 1,782 — 10,296 Total revenue 935,815 291,797 97,088 (1,830 ) 1,322,870 Revenue not under the guidance of ASC 606: Lease revenue (1) (5,575 ) (28,573 ) (8,441 ) — (42,589 ) Losses from futures contracts included in product sales revenue (2) 40,305 5,480 — — 45,785 Affiliate management fee revenue (649 ) (7,865 ) (1,782 ) — (10,296 ) Total revenue from contracts with customers under ASC 606 $ 969,896 $ 260,839 $ 86,865 $ (1,830 ) $ 1,315,770 (1) Lease revenue is accounted for under ASC 840, Leases . (2) The impact on product sales revenue from futures contracts falls under the guidance of ASC 815, Derivatives and Hedging . Balance Sheet Disclosures We invoice customers on our refined products pipelines 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 contract liability. This liability is presented as deferred revenue on our consolidated balance sheets. Deferred revenue is also recorded for pre-payments received in conjunction with take-or-pay contracts, storage contracts and other service offerings in which the service to our customers remains unfulfilled. Additionally, at each period end, we defer the direct costs we have incurred associated with our customers’ in-transit products as contract assets. Contract assets are presented on our consolidated balance sheets as other current assets. These direct costs are estimated based on our per-barrel direct delivery cost for the current period 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 of 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 contract assets and contract liabilities are determined using judgments and assumptions that management considers reasonable. The following table summarizes our accounts receivable, contract assets and contract liabilities resulting from contracts with customers (in thousands): January 1, 2018 June 30, 2018 Accounts receivable from contracts with customers $ 133,084 $ 102,837 Contract assets $ 8,615 $ 8,916 Contract liabilities $ 106,933 $ 113,207 For the three and six months ended June 30, 2018 , we recognized $10.8 million and $66.3 million , respectively, of transportation and terminals revenue that was recorded in deferred revenue as of January 1, 2018. Unfulfilled Performance Obligations We have certain contracts with customers that represent customer commitments to purchase a minimum amount of our services over specified time periods. These contracts require us to provide services to our customers in the future and result in our having unfulfilled performance obligations (“UPOs”) to our customers related to the periods remaining under each contract. We have UPOs in many of our core business services, including transportation, terminalling and storage services. The UPOs will be recognized as revenue in the future as our customers utilize our services or when we estimate that our customers are not likely to use all or a portion of their commitments. The following table provides the aggregate amount of the transaction price allocated to our UPOs as of June 30, 2018 by operating segment, including the range of years remaining on our contracts with customers and an estimate of revenues expected to be recognized over the next 12 months (dollars in thousands): Refined Products Crude Oil Marine Storage Total Balances at June 30, 2018 $ 1,439,706 $ 1,210,098 $ 359,935 $ 3,009,739 Remaining terms 1 - 20 years 1 - 10 years 1 - 6 years Estimated revenues from UPOs to be recognized in the next 12 months $ 287,311 $ 333,215 $ 152,248 $ 772,774 In computing the value of these future revenues, we have used the current rates in effect as of June 30, 2018 and have not included any estimates for future rate changes due to changes in the FERC index or other contractually negotiated rate escalations. Our UPO balances include the full amount of our customer commitments as of June 30, 2018 through the expiration of the related contracts. The UPO balances disclosed exclude all performance obligations for which the original expected term is one year or less, the consideration is variable or the future use of our services is fully at the discretion of our customers.

Segment Disclosures

Segment Disclosures	6 Months Ended
	Jun. 30, 2018
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 as 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. Three Months Ended June 30, 2017 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 277,883 $ 108,455 $ 47,794 $ (893 ) $ 433,239 Product sales revenue 161,723 19,403 878 — 182,004 Affiliate management fee revenue 353 3,474 370 — 4,197 Total revenue 439,959 131,332 49,042 (893 ) 619,440 Operating expenses 100,713 31,410 15,375 (2,204 ) 145,294 Cost of product sales 125,220 18,607 2,148 — 145,975 Earnings of non-controlled entities (422 ) (24,494 ) (660 ) — (25,576 ) Operating margin 214,448 105,809 32,179 1,311 353,747 Depreciation and amortization expense 27,005 12,507 8,073 1,311 48,896 G&A expense 26,720 11,071 5,602 — 43,393 Operating profit $ 160,723 $ 82,231 $ 18,504 $ — $ 261,458 Three Months Ended June 30, 2018 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 291,064 $ 137,953 $ 44,146 $ (915 ) $ 472,248 Product sales revenue 150,934 13,282 2,581 — 166,797 Affiliate management fee revenue 352 3,849 845 — 5,046 Total revenue 442,350 155,084 47,572 (915 ) 644,091 Operating expenses 113,342 31,177 17,693 (2,367 ) 159,845 Cost of product sales 137,543 13,761 2,375 — 153,679 (Earnings) losses of non-controlled entities 97 (41,851 ) (756 ) — (42,510 ) Operating margin 191,368 151,997 28,260 1,452 373,077 Depreciation and amortization expense 30,508 12,741 8,918 1,452 53,619 G&A expense 33,187 13,455 6,648 — 53,290 Operating profit $ 127,673 $ 125,801 $ 12,694 $ — $ 266,168

Investments in Non-Controlled E

Investments in Non-Controlled Entities	6 Months Ended
	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Investments in Non-Controlled Entities	Investments in Non-Controlled Entities Our investments in non-controlled entities at June 30, 2018 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% We serve as operator of BridgeTex, HoustonLink, MVP, Powder Springs, Saddlehorn, Texas Frontera and the pipeline activities of Seabrook. We receive fees for management services 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 $1.4 million and $1.2 million during the three months ended June 30, 2017 and 2018 , respectively, and $2.4 million and $1.7 million during the six months ended June 30, 2017 and 2018 , respectively. We recorded the following revenue and expense transactions from certain of these non-controlled entities in our consolidated statements of income (in millions): Three Months Ended June 30, Six Months Ended June 30, 2017 2018 2017 2018 Transportation and terminals revenue: BridgeTex, pipeline capacity $ 9.0 $ 9.7 $ 17.9 $ 19.6 Double Eagle, throughput revenue $ 1.0 $ 1.4 $ 1.8 $ 2.9 Saddlehorn, storage revenue $ 0.6 $ 0.6 $ 1.1 $ 1.1 Product sales revenue: Powder Springs, butane sales $ — $ 2.2 $ — $ 4.9 Cost of product sales Powder Springs, butane purchases $ — $ 0.4 $ — $ 0.4 Our consolidated balance sheets reflected the following balances related to our investments in non-controlled entities (in millions): December 31, 2017 June 30, 2018 Trade Accounts Receivable Other Accounts Receivable Other Accounts Payable Trade Accounts Receivable Other Accounts Receivable BridgeTex $ — $ — $ — $ 0.2 $ 0.1 Double Eagle $ 0.5 $ — $ — $ 0.4 $ — HoustonLink $ — $ — $ 0.1 $ — $ — MVP $ — $ 0.4 $ — $ — $ 1.1 Powder Springs $ — $ 0.9 $ — $ — $ 2.1 Saddlehorn $ — $ 0.1 $ — $ — $ 0.1 Seabrook $ — $ 0.2 $ — $ — $ 0.4 We have entered into an agreement to guarantee our 50% pro rata share, up to $25.0 million , of obligations under Powder Springs’ credit facility. As of June 30, 2018 , our consolidated balance sheets reflected a $0.4 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. The financial results from MVP and Texas Frontera are included in our marine storage segment, the financial results from BridgeTex, Double Eagle, HoustonLink, 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 follows (in thousands): Investments at December 31, 2017 $ 1,082,511 Additional investment 144,859 Other adjustments 502 Earnings of non-controlled entities: Proportionate share of earnings 78,251 Amortization of excess investment and capitalized interest (1,203 ) Earnings of non-controlled entities 77,048 Less: Distributions of earnings from investments in non-controlled entities 94,661 Investments at June 30, 2018 $ 1,210,259

Inventory

Inventory	6 Months Ended
	Jun. 30, 2018
Inventory Disclosure [Abstract]
Inventory	Inventory Inventory at December 31, 2017 and June 30, 2018 was as follows (in thousands): December 31, 2017 June 30, Refined products $ 73,845 $ 60,794 Liquefied petroleum gases 45,553 57,260 Transmix 33,319 37,346 Crude oil 23,763 21,837 Additives 5,865 6,341 Total inventory $ 182,345 $ 183,578

Employee Benefit Plans

Employee Benefit Plans	6 Months Ended
	Jun. 30, 2018
Retirement Benefits [Abstract]
Employee Benefit Plans	Employee Benefit Plans 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 $2.1 million and $2.3 million for the three months ended June 30, 2017 and 2018 , respectively, and $5.4 million and $6.1 million for the six months ended June 30, 2017 and 2018 , respectively. Additionally, we sponsor two union pension plans that cover certain union employees, a pension plan for all non-union employees and a postretirement benefit plan for certain employees. Net periodic benefit expense for the three and six months ended June 30, 2017 and 2018 was as follows (in thousands): Three Months Ended Three Months Ended June 30, 2017 June 30, 2018 Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Components of net periodic benefit costs: Service cost $ 5,230 $ 66 $ 6,269 $ 51 Interest cost 2,582 123 2,795 102 Expected return on plan assets (2,646 ) — (3,024 ) — Amortization of prior service credit (46 ) — (46 ) — Amortization of actuarial loss 1,783 200 1,569 134 Settlement cost 361 — — — Net periodic benefit cost $ 7,264 $ 389 $ 7,563 $ 287 Six Months Ended Six Months Ended June 30, 2017 June 30, 2018 Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Components of net periodic benefit costs: Service cost $ 10,248 $ 131 $ 21,969 $ 116 Interest cost 4,932 245 9,238 208 Expected return on plan assets (5,133 ) — (6,002 ) — Amortization of prior service credit (91 ) — (91 ) — Amortization of actuarial loss 2,811 400 6,523 294 Settlement cost 1,726 — — — Net periodic benefit cost $ 14,493 $ 776 $ 31,637 $ 618 The service component of our net periodic benefit costs is presented in operating expense and G&A expense, and the non-service components are presented in other expense in our consolidated statements of income. The changes in accumulated other comprehensive loss (“AOCL”) related to employee benefit plan assets and benefit obligations for the three and six months ended June 30, 2017 and 2018 were as follows (in thousands): Three Months Ended Three Months Ended June 30, 2017 June 30, 2018 Gains (Losses) Included in AOCL Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Beginning balance $ (56,236 ) $ (7,681 ) $ (98,261 ) $ (6,437 ) Net actuarial gain — — 386 267 Amortization of prior service credit (46 ) — (46 ) — Amortization of actuarial loss 1,783 200 1,569 134 Settlement cost 361 — — — Ending balance $ (54,138 ) $ (7,481 ) $ (96,352 ) $ (6,036 ) Six Months Ended Six Months Ended June 30, 2017 June 30, 2018 Gains (Losses) Included in AOCL Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Beginning balance $ (58,584 ) $ (7,881 ) $ (97,226 ) $ (6,597 ) Net actuarial gain (loss) — — (5,558 ) 267 Amortization of prior service credit (91 ) — (91 ) — Amortization of actuarial loss 2,811 400 6,523 294 Settlement cost 1,726 — — — Ending balance $ (54,138 ) $ (7,481 ) $ (96,352 ) $ (6,036 ) The net periodic benefit costs and AOCL presented in the tables above for the six month period ending June 30, 2018 include one-time corrections made in first quarter 2018 resulting from an error in our third-party actuary’s valuation of our pension liabilities and net periodic pension expenses. See Note 1 – Organization, Description of Business and Basis of Presentation for more details regarding this error correction. Contributions estimated to be paid into the plans in 2018 are $31.7 million and $0.5 million for the pension plans and other postretirement benefit plan, respectively.

Debt

Debt	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Debt	Debt Long-term debt at December 31, 2017 and June 30, 2018 was as follows (in thousands): December 31, June 30, Commercial paper $ — $ 120,000 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 500,000 500,000 Face value of long-term debt 4,550,000 4,670,000 Unamortized debt issuance costs (1) (29,472 ) (28,327 ) Net unamortized debt premium (discount) (1) 215 (1,418 ) Net unamortized amount of gains from historical fair value hedges (1) 3,749 1,818 Long-term debt, net, including current portion 4,524,492 4,642,073 Less: current portion of long-term debt, net 250,974 250,046 Long-term debt, net $ 4,273,518 $ 4,392,027 (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. Other Debt Revolving Credit Facilities. At June 30, 2018 , 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 this 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 between 0.100% and 0.275% depending on our credit ratings. The unused commitment fee was 0.125% at June 30, 2018 . Borrowings under this facility may be used for general partnership purposes, including capital expenditures. As of both December 31, 2017 and June 30, 2018 , 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 this facility. 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 1.3% for the year ended December 31, 2017 and 2.1% for the six months ended June 30, 2018 .

Derivative Financial Instrument

Derivative Financial Instruments	6 Months Ended
	Jun. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	Derivative Financial Instruments 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 second quarter 2018, we entered into $100.0 million of treasury lock agreements to protect against the risk of variability of a portion of debt we anticipate issuing in 2019. We previously entered into $100.0 million of interest rate swap agreements to protect against the risk of variability of future interest payments on a portion of debt we anticipate issuing in 2018. The fair value of these interest rate derivative agreements at June 30, 2018 was a net asset of $19.3 million (recorded as $19.5 million current assets, $0.2 million non-current assets and $0.4 million non-current liabilities on our consolidated balance sheets), with the offset recorded to other comprehensive income. We account for these agreements as cash flow hedges. 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-traded 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 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 June 30, 2018 were as follows: Type of Contract/Accounting Methodology Product Represented by the Contract and Associated Barrels Maturity Dates Futures - Economic Hedges 5.4 million barrels of refined products and crude oil Between July 2018 and April 2019 Futures - Economic Hedges 2.3 million barrels of butane and natural gasoline Between July 2018 and April 2019 Energy Commodity Derivatives Contracts and Deposits Offsets At December 31, 2017 and June 30, 2018 , we had margin deposits of $36.7 million and $35.6 million , respectively, for our future contracts with our counterparties, which were recorded as current assets 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, 2017 and June 30, 2018 (in thousands): Description 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 (2) Margin Deposit Amounts Not Offset in the Consolidated Balance Sheets Net Asset Amount (1) As of December 31, 2017 $ (38,936 ) $ 12,851 $ (26,085 ) $ 36,690 $ 10,605 As of June 30, 2018 $ (37,657 ) $ 10,289 $ (27,368 ) $ 35,610 $ 8,242 (1) Amount represents the maximum loss we would incur if all of 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 at December 31, 2017. Net amount includes energy commodity derivative contracts classified as current liabilities of $27,368 at June 30, 2018 . Impact of Derivatives on Our Financial Statements Comprehensive Income The changes in derivative activity included in AOCL for the three and six months ended June 30, 2017 and 2018 were as follows (in thousands): Three Months Ended Six Months Ended June 30, June 30, Derivative Losses Included in AOCL 2017 2018 2017 2018 Beginning balance $ (32,741 ) $ (27,601 ) $ (34,776 ) $ (33,755 ) Net gain (loss) on cash flow hedges (2,802 ) 1,697 (1,507 ) 7,111 Reclassification of net loss on cash flow hedges to income 739 739 1,479 1,479 Ending balance $ (34,804 ) $ (25,165 ) $ (34,804 ) $ (25,165 ) The following is a summary of the effect on our consolidated statements of income for the three and six months ended June 30, 2017 and 2018 of derivatives that were designated as cash flow hedges (in thousands): Interest Rate Contracts Amount of Gain (Loss) Recognized in AOCL on Derivative Location of Loss Reclassified from AOCL into Income Amount of Loss Reclassified from AOCL into Income Three Months Ended June 30, 2017 $ (2,802 ) Interest expense $ (739 ) Three Months Ended June 30, 2018 $ 1,697 Interest expense $ (739 ) Six Months Ended June 30, 2017 $ (1,507 ) Interest expense $ (1,479 ) Six Months Ended June 30, 2018 $ 7,111 Interest expense $ (1,479 ) As of June 30, 2018 , 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 contracts over the life of the related debt instruments. We 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 permanent portion of the 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 crude oil, and there was no ineffectiveness recognized. 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 crude oil were as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2017 2018 2017 2018 Gain (loss) recognized in other income/expense on derivatives (futures contracts) $ 3,370 $ (368 ) $ 6,768 (549 ) Gain (loss) recognized in other income/expense on hedged item (crude oil) $ (3,370 ) $ 368 $ (6,768 ) 549 The differential between the current spot price and forward price was excluded from the assessment of hedge effectiveness for these fair value hedges. For the three and six months ended June 30, 2017 , we recognized a gain of $0.3 million and $1.7 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 three and six months ended June 30, 2017 and 2018 of derivatives accounted for as economic hedges (in thousands): Amount of Gain (Loss) Recognized on Derivatives Three Months Ended Six Months Ended Location of Gain (Loss) Recognized on Derivatives June 30, June 30, Derivative Instrument 2017 2018 2017 2018 Futures contracts Product sales revenue $ 14,214 $ (38,411 ) $ 42,894 $ (45,786 ) Futures contracts Cost of product sales (1,184 ) 8,337 53 4,393 Total $ 13,030 $ (30,074 ) $ 42,947 $ (41,393 ) 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, 2017 and June 30, 2018 (in thousands): 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 June 30, 2018 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 $ 722 Interest rate contracts Other current assets 19,508 Other current liabilities — Interest rate contracts Other noncurrent assets 157 Other noncurrent liabilities 377 Total $ 19,665 Total $ 1,099 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, 2017 and June 30, 2018 (in thousands): 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 June 30, 2018 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value Futures contracts Energy commodity derivatives contracts, net $ 10,289 Energy commodity derivatives contracts, net $ 36,935

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Butane Blending Patent Infringement Proceeding On October 4, 2017, Sunoco Partners Marketing & Terminals L.P. (“Sunoco”) brought an action for patent infringement in the U.S. District Court for the District of Delaware alleging Magellan Midstream Partners, L.P. (“Magellan”) and Powder Springs Logistics, LLC (“Powder Springs”) have infringed patents relating to butane blending at the Powder Springs facility located in Powder Springs, Georgia. On July 31, 2018, Sunoco submitted a pleading alleging that Magellan has infringed various patents relating to butane blending at our Greensboro, North Carolina, Chattanooga, Tennessee and East Houston, Texas terminals and stated that it intends to assert similar accusations against all other similar blending systems. Sunoco is seeking an undetermined amount of damages, attorneys’ fees and a permanent injunction enjoining Magellan and Powder Springs from infringing on the subject patents. We deny and are vigorously defending against all claims asserted by Sunoco. Although it is not possible to predict the ultimate outcome, we believe, based on our current understanding of the applicable facts and law, that the ultimate resolution of this matter will not have a material adverse impact on our results of operations, financial position or cash flows. Environmental Liabilities Liabilities recognized for estimated environmental costs were $19.3 million and $17.3 million at December 31, 2017 and June 30, 2018 , 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 generally included in operating expenses on our consolidated statements of income. Environmental expenses were $0.2 million and $2.8 million for the three months ended June 30, 2017 and 2018 , respectively, and $4.5 million and $5.3 million for the six months ended June 30, 2017 and 2018 , respectively. Environmental Receivables Receivables from insurance carriers and other third parties related to environmental matters were $7.2 million at December 31, 2017 , 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. Receivables from insurance carriers and other third parties related to environmental matters were $4.7 million at June 30, 2018 , of which $0.6 million and $4.1 million were recorded to other accounts receivable and long-term receivables, respectively, on our consolidated balance sheets. 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. 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.

Long-Term Incentive Plan

Long-Term Incentive Plan	6 Months Ended
	Jun. 30, 2018
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 payout of 11.9 million of our limited partner units. The estimated units remaining available under the LTIP at June 30, 2018 total 2.1 million . Our equity-based incentive compensation expense was as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2017 2018 2017 2018 Performance-based awards $ 5,910 $ 9,165 $ 9,391 $ 15,089 Time-based awards 660 882 1,326 1,590 Total $ 6,570 $ 10,047 $ 10,717 $ 16,679 Allocation of LTIP expense on our consolidated statements of income: G&A expense $ 6,514 $ 9,968 $ 10,632 $ 16,545 Operating expense 56 79 85 134 Total $ 6,570 $ 10,047 $ 10,717 $ 16,679 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 three -year vesting period that will end on December 31, 2020. Basic and Diluted Net Income Per Limited Partner Unit The difference between our actual limited partner units outstanding and our weighted-average number of limited partner units outstanding used to calculate basic net income per unit is due to the impact of: (i) the unit awards issued to non-employee directors 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 unit awards associated with our LTIP that have not yet vested.

Partners' Capital and Distribut

Partners' Capital and Distributions	6 Months Ended
	Jun. 30, 2018
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 have been issued pursuant to this program. The following table details the changes in the number of our limited partner units outstanding from January 1, 2018 through June 30, 2018 : Limited partner units outstanding on January 1, 2018 228,024,556 January 2018–Settlement of employee LTIP awards 168,913 During 2018–Other (a) 1,691 Limited partner units outstanding on June 30, 2018 228,195,160 (a) Limited partner units issued to settle the equity-based retainer paid to an independent director of our general partner. Distributions Distributions we paid during 2017 and 2018 were as follows (in thousands, except per unit amounts): Payment Date Per Unit Cash Distribution Amount Total Cash Distribution to Limited Partners 02/14/2017 $ 0.8550 $ 194,961 05/15/2017 0.8725 198,951 Through 06/30/2017 1.7275 393,912 08/14/2017 0.8900 202,942 11/14/2017 0.9050 206,362 Total $ 3.5225 $ 803,216 02/14/2018 $ 0.9200 $ 209,940 05/15/2018 0.9375 213,933 Through 06/30/2018 1.8575 423,873 08/14/2018 (a) 0.9575 218,497 Total $ 2.8150 $ 642,370 (a) Our general partner’s board of directors declared this cash distribution in July 2018 to be paid on August 14, 2018 to unitholders of record at the close of business on August 7, 2018 .

Fair Value

Fair Value	6 Months Ended
	Jun. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value	Fair Value Fair Value Methods and Assumptions - Financial Assets and Liabilities. We used the following methods and assumptions in estimating fair value of 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 8 – Derivative Financial Instruments for further disclosures regarding these contracts. • Interest rate contracts. These include interest rate hedge agreements to protect against the risk of variability of interest payments on future debt. These contracts are carried at fair value on our consolidated balance sheets and are valued based on an assumed exchange, at the end of each period, in an orderly transaction with a market participant in the market in which the financial instrument is traded. The exchange value was calculated using present value techniques on estimated future cash flows based on forward interest rate curves. See Note 8 – Derivative Financial Instruments for further disclosures regarding these contracts. • Long-term receivables. These 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, 2017 and June 30, 2018 ; 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, 2017 and June 30, 2018 based on the three levels established by ASC 820, Fair Value Measurements and Disclosures (in thousands): December 31, 2017 Assets (Liabilities) Fair Value Measurements using: 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 ) $ — June 30, 2018 Assets (Liabilities) Fair Value Measurements using: 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 $ (27,368 ) $ (27,368 ) $ (27,368 ) $ — $ — Interest rate contracts $ 19,288 $ 19,288 $ — $ 19,288 $ — Long-term receivables $ 23,875 $ 23,875 $ — $ — $ 23,875 Debt $ (4,642,073 ) $ (4,706,966 ) $ — $ (4,706,966 ) $ —

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2018
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions Stacy P. Methvin is an independent member of our general partner’s board of directors and is also a director of one of our customers. We received tariff and other ancillary revenue from this customer of $4.3 million and $4.6 million for the three months ended June 30, 2017 and 2018 , respectively, and $8.4 million for each of the six months ended June 30, 2017 and 2018, respectively. We recorded receivables of $1.6 million and $2.0 million from this customer at December 31, 2017 and June 30, 2018 , 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 ventures.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2018
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Recognizable events No recognizable events occurred subsequent to June 30, 2018 . Non-recognizable events Cash Distribution. In July 2018, our general partner’s board of directors declared a quarterly distribution of $0.9575 per unit for the period of April 1, 2018 through June 30, 2018. This quarterly cash distribution will be paid on August 14, 2018 to unitholders of record on August 7, 2018 . The total cash distributions expected to be paid under this declaration are approximately $218.5 million .

Organization, Description of 21

Organization, Description of Business And Basis Of Presentation (Accounting Policies) (Policies)	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation In the opinion of management, our accompanying consolidated financial statements which are unaudited, except for the consolidated balance sheet as of December 31, 2017 , which is derived from our audited financial statements, include all normal and recurring adjustments necessary to present fairly our financial position as of June 30, 2018 , the results of operations for the three and six months ended June 30, 2017 and 2018 and cash flows for the six months ended June 30, 2017 and 2018 . The results of operations for the six months ended June 30, 2018 are not necessarily indicative of the results to be expected for the full year ending December 31, 2018 for several reasons. Profits from our butane blending activities are realized largely during the first and fourth quarters of each year. Additionally, gasoline demand, which drives transportation volumes and revenues on our refined products pipeline system, generally trends higher during the summer driving months. Further, the volatility of commodity prices impacts the profits from our commodity activities and, to a lesser extent, the volume of petroleum products we transport on our pipelines. Pursuant to the rules and regulations of the Securities and Exchange Commission, the financial statements in this report do not include all of the information and notes normally included with financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”). These financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2017 .
Use of Estimates	Use of Estimates The preparation of our consolidated financial statements in conformity with 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.
Reclassifications	Reclassifications. Prior year amounts related to restricted cash have been reclassified to conform with the current period’s presentation.
Restricted Cash	Restricted Cash Restricted cash includes cash held by us, which is contractually required to be used for the construction of fixed assets, and is unavailable for general use. It is classified as noncurrent due to its designation to be used for the acquisition or construction of noncurrent assets.
New Accounting Pronouncements	New Accounting Pronouncements In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-02, Leases (Topic 842). This ASU requires lessees to recognize a right of use asset and lease liability on the balance sheet 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. New Accounting Pronouncements - Adopted January 1, 2018 In August 2017, the FASB issued 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 early-adopted the new standard on January 1, 2018. The adoption of this ASU did not have a material impact on our consolidated 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 includes a requirement to make an accounting policy election to classify distributions received from equity method investees under either (1) the cumulative earnings approach, where distributions in excess of equity earnings are considered a return of capital and classified as cash inflows from investing activities, or (2) the nature of the distribution approach, where each distribution is evaluated on the basis of the source of the payment and classified as either operating or investing cash inflows. We adopted this standard on January 1, 2018 using the retrospective transition method and made an accounting policy election to use the nature of the distribution approach, which resulted in the following adjustments to our June 30, 2017 comparative statement of cash flows (in thousands): Six Months Ended June 30, 2017, as Reported ASU 2016-15 Adjustment Six Months Ended June 30, 2017, as Adjusted Operating activities: Distributions of earnings from investments in non-controlled entities $ 46,754 $ 11,152 $ 57,906 Net cash provided by operating activities $ 572,411 $ 11,152 $ 583,563 Investing activities: Distributions in excess of earnings of non-controlled entities $ 11,152 $ (11,152 ) $ — Net cash used by investing activities $ (320,739 ) $ (11,152 ) $ (331,891 ) In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). 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. On January 1, 2018, we adopted the new Accounting Standards Codification (“ASC”) 606, Revenue from Contracts with Customers and all the related amendments using the modified retrospective method. We recognized the cumulative effect of initially applying the new revenue standard as an adjustment to the opening balance of partners’ capital. The comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. The cumulative effect of the changes made to our consolidated January 1, 2018 balance sheet resulting from the adoption of the new revenue standard was as follows (in thousands): Balance at December 31, 2017 Adjustments Due to ASU 2014-09 Balance at January 1, 2018 Assets: Property, plant and equipment $ 7,235,468 $ 8,516 $ 7,243,984 Accumulated depreciation (1,682,633 ) (325 ) (1,682,958 ) Net property, plant and equipment $ 5,552,835 $ 8,191 $ 5,561,026 Investments in non-controlled entities $ 1,082,511 $ 502 $ 1,083,013 Liabilities: Deferred revenue $ 117,795 $ (1,901 ) $ 115,894 Other noncurrent liabilities $ 30,350 $ 4,619 $ 34,969 Partners’ capital: Limited partner unitholders $ 2,267,231 $ 5,975 $ 2,273,206 The primary changes impacting our financial statements under the new revenue standard include the requirement for us to estimate deficiencies in our customers’ use of our services contracted as minimum commitments and adjust the amount of revenue recognized in proportion to our customers’ pattern of exercised rights. This change results in accelerating the timing of revenue recognized for specific contracts for which we estimate our customers will not ship their minimum commitments. In addition, we periodically receive payments from customers seeking to expand their access to our pipeline systems and terminals. Prior to the adoption of the new revenue standard, these payments were recorded as reductions to our property, plant and equipment (“PP&E”) expenditures. Under the new revenue standard, these payments are recorded to deferred revenue and other noncurrent liabilities and are recognized as revenue in proportion to the related services provided. The impact of this change increases our revenues, contract liabilities, PP&E and depreciation expense. We expect the impact of the adoption of the new revenue standard, including these changes, to be immaterial to our net income on an ongoing basis.
Revenue Recognition	Revenue recognition policies Revenue is recognized upon the satisfaction of each performance obligation required by our customer contracts. Transportation and terminals revenue is recognized over time as our customers receive the benefits of our service as it is performed on their behalf using an output method based on actual deliveries. Revenue for our storage services is recognized over time using an output method based on the capacity of storage under contract with our customers. Product sales revenue is recognized at a point in time when our customers take control of the commodities purchased. We record back-to-back purchases and sales of petroleum products where we are acting as an agent on a net basis. We recognize pipeline transportation revenue for crude oil and ammonia shipments when our customers’ product arrives at the customer-designated destination. For shipments of refined products 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 contracts that require counterparties to ship a minimum volume over an agreed-upon time period, which are contracted as minimum dollar or volume commitments. Revenue pursuant to these take-or-pay contracts is recognized when the customers utilize their committed volumes. Additionally, when we estimate that the customers will not utilize all or a portion of their committed volumes, we recognize revenue in proportion to the pattern of exercised rights for the respective commitment period. Our interstate common carrier petroleum products pipeline operations are subject to rate regulation by the Federal Energy Regulatory Commission (“FERC”) under the Interstate Commerce Act, the Energy Policy Act of 1992 and rules and orders promulgated pursuant thereto. FERC regulation requires that interstate pipeline rates be filed with the FERC, be posted publicly and be nondiscriminatory and “just and reasonable.” The rates on approximately 40% of the shipments on our refined products pipeline system are regulated by the FERC primarily through an index methodology. As an alternative to cost-of-service or index-based rates, interstate pipeline companies may establish rates by obtaining authority to charge market-based rates in competitive markets or by negotiation with unaffiliated shippers. Approximately 60% of our refined products pipeline system’s markets are either subject to regulations by the states in which we operate or are approved for market-based rates by the FERC, and in both cases these rates can generally be adjusted at our discretion based on market factors. Most of the tariffs on our crude oil pipelines are established by negotiated rates that generally provide for annual adjustments in line with changes in the FERC index, subject to certain modifications. For both our index-based rates and our market-based rates, our published tariffs serve as contracts, and shippers nominate the volume to be shipped up to a month in advance. These tariffs include provisions which allow us to deduct from our customer’s inventory a small percentage of the products our customers transport on our pipeline systems. We refer to this non-monetary consideration as tender deduction revenue. We receive tender deductions from our customers as consideration for product losses during the transportation of petroleum products within our pipeline systems. Tender deduction revenue is generally recognized as transportation revenue when the customer's transported commodities reach their destination and is recorded at the fair value of the product received on the date received or the contract date, as applicable. Product sales revenue pricing is contractually specified, and we have determined that each barrel sold represents a separate performance obligation. Transaction prices for our other services including terminalling, storage and ancillary services are typically contracted as a single performance obligation with our customers. In circumstances where multiple performance obligations are contractually required, we allocate the transaction price to the various performance obligations based on their relative standalone selling price.
Revenue Recognition, Deferred Revenue	Balance Sheet Disclosures We invoice customers on our refined products pipelines 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 contract liability. This liability is presented as deferred revenue on our consolidated balance sheets. Deferred revenue is also recorded for pre-payments received in conjunction with take-or-pay contracts, storage contracts and other service offerings in which the service to our customers remains unfulfilled. Additionally, at each period end, we defer the direct costs we have incurred associated with our customers’ in-transit products as contract assets. Contract assets are presented on our consolidated balance sheets as other current assets. These direct costs are estimated based on our per-barrel direct delivery cost for the current period 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 of 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 contract assets and contract liabilities are determined using judgments and assumptions that management considers reasonable.

Organization, Description of 22

Organization, Description of Business and Basis of Presentation (Tables)	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	We adopted this standard on January 1, 2018 using the retrospective transition method and made an accounting policy election to use the nature of the distribution approach, which resulted in the following adjustments to our June 30, 2017 comparative statement of cash flows (in thousands): Six Months Ended June 30, 2017, as Reported ASU 2016-15 Adjustment Six Months Ended June 30, 2017, as Adjusted Operating activities: Distributions of earnings from investments in non-controlled entities $ 46,754 $ 11,152 $ 57,906 Net cash provided by operating activities $ 572,411 $ 11,152 $ 583,563 Investing activities: Distributions in excess of earnings of non-controlled entities $ 11,152 $ (11,152 ) $ — Net cash used by investing activities $ (320,739 ) $ (11,152 ) $ (331,891 ) In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). 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. On January 1, 2018, we adopted the new Accounting Standards Codification (“ASC”) 606, Revenue from Contracts with Customers and all the related amendments using the modified retrospective method. We recognized the cumulative effect of initially applying the new revenue standard as an adjustment to the opening balance of partners’ capital. The comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. The cumulative effect of the changes made to our consolidated January 1, 2018 balance sheet resulting from the adoption of the new revenue standard was as follows (in thousands): Balance at December 31, 2017 Adjustments Due to ASU 2014-09 Balance at January 1, 2018 Assets: Property, plant and equipment $ 7,235,468 $ 8,516 $ 7,243,984 Accumulated depreciation (1,682,633 ) (325 ) (1,682,958 ) Net property, plant and equipment $ 5,552,835 $ 8,191 $ 5,561,026 Investments in non-controlled entities $ 1,082,511 $ 502 $ 1,083,013 Liabilities: Deferred revenue $ 117,795 $ (1,901 ) $ 115,894 Other noncurrent liabilities $ 30,350 $ 4,619 $ 34,969 Partners’ capital: Limited partner unitholders $ 2,267,231 $ 5,975 $ 2,273,206

Revenue from Contract with Cu23

Revenue from Contract with Customers (Tables)	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
Schedule of Prospective Adoption of New Accounting Pronouncements	The table below provides the amount by which financial statement line items are affected in the current reporting period by the application of the new revenue standard, as compared with the guidance that was in effect before the change (in thousands): As Reported Amounts without adoption of ASC 606 Effect of Change Higher/(Lower) Statements of Income: Three Months Ended June 30, 2018 Transportation and terminals revenue $ 472,248 $ 465,079 $ 7,169 Depreciation and amortization $ 53,619 $ 53,555 $ 64 Six Months Ended June 30, 2018 Transportation and terminals revenue $ 904,185 $ 896,603 $ 7,582 Depreciation and amortization $ 105,498 $ 105,378 $ 120 Balance Sheet: As of June 30, 2018 Assets: Property, plant and equipment $ 7,443,095 $ 7,433,091 $ 10,004 Accumulated depreciation 1,783,036 1,782,591 445 Net property, plant and equipment $ 5,660,059 $ 5,650,500 $ 9,559 Investments in non-controlled entities $ 1,210,259 $ 1,209,757 $ 502 Liabilities: Deferred revenue $ 120,134 $ 128,349 $ (8,215 ) Other noncurrent liabilities $ 69,526 $ 64,687 $ 4,839 Partners’ capital: Limited partner unitholders $ 2,281,845 $ 2,268,408 $ 13,437
Revenue from External Customers by Products and Services	The following tables provide details of our revenues disaggregated by key activities that comprise our performance obligations by operating segment (in thousands): Three Months Ended June 30, 2018 Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation $ 184,596 $ 84,755 $ — $ — $ 269,351 Terminalling 50,574 — 592 — 51,166 Storage 24,969 28,536 33,319 (915 ) 85,909 Ancillary services 28,459 8,199 6,037 — 42,695 Lease revenue 2,466 16,463 4,198 — 23,127 Transportation and terminals revenue 291,064 137,953 44,146 (915 ) 472,248 Product sales revenue 150,934 13,282 2,581 — 166,797 Affiliate management fee revenue 352 3,849 845 — 5,046 Total revenue 442,350 155,084 47,572 (915 ) 644,091 Revenue not under the guidance of ASC 606: Lease revenue (1) (2,466 ) (16,463 ) (4,198 ) — (23,127 ) Losses from futures contracts included in product sales revenue (2) 34,840 3,570 — — 38,410 Affiliate management fee revenue (352 ) (3,849 ) (845 ) — (5,046 ) Total revenue from contracts with customers under ASC 606 $ 474,372 $ 138,342 $ 42,529 $ (915 ) $ 654,328 (1) Lease revenue is accounted for under ASC 840, Leases . (2) The impact on product sales revenue from futures contracts falls under the guidance of ASC 815, Derivatives and Hedging . Six Months Ended June 30, 2018 Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation $ 351,498 $ 163,878 $ — $ — $ 515,376 Terminalling 89,922 — 1,304 — 91,226 Storage 50,216 58,526 67,530 (1,830 ) 174,442 Ancillary services 54,247 13,234 13,071 — 80,552 Lease revenue 5,575 28,573 8,441 — 42,589 Transportation and terminals revenue 551,458 264,211 90,346 (1,830 ) 904,185 Product sales revenue 383,708 19,721 4,960 — 408,389 Affiliate management fee revenue 649 7,865 1,782 — 10,296 Total revenue 935,815 291,797 97,088 (1,830 ) 1,322,870 Revenue not under the guidance of ASC 606: Lease revenue (1) (5,575 ) (28,573 ) (8,441 ) — (42,589 ) Losses from futures contracts included in product sales revenue (2) 40,305 5,480 — — 45,785 Affiliate management fee revenue (649 ) (7,865 ) (1,782 ) — (10,296 ) Total revenue from contracts with customers under ASC 606 $ 969,896 $ 260,839 $ 86,865 $ (1,830 ) $ 1,315,770 (1) Lease revenue is accounted for under ASC 840, Leases . (2) The impact on product sales revenue from futures contracts falls under the guidance of ASC 815, Derivatives and Hedging .
Contract with Customer, Asset and Liability	The following table summarizes our accounts receivable, contract assets and contract liabilities resulting from contracts with customers (in thousands): January 1, 2018 June 30, 2018 Accounts receivable from contracts with customers $ 133,084 $ 102,837 Contract assets $ 8,615 $ 8,916 Contract liabilities $ 106,933 $ 113,207
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	The following table provides the aggregate amount of the transaction price allocated to our UPOs as of June 30, 2018 by operating segment, including the range of years remaining on our contracts with customers and an estimate of revenues expected to be recognized over the next 12 months (dollars in thousands): Refined Products Crude Oil Marine Storage Total Balances at June 30, 2018 $ 1,439,706 $ 1,210,098 $ 359,935 $ 3,009,739 Remaining terms 1 - 20 years 1 - 10 years 1 - 6 years Estimated revenues from UPOs to be recognized in the next 12 months $ 287,311 $ 333,215 $ 152,248 $ 772,774

Segment Disclosures (Tables)

Segment Disclosures (Tables)	6 Months Ended
	Jun. 30, 2018
Segment Reporting [Abstract]
Schedule of Business Segment Reporting Information	Three Months Ended June 30, 2017 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 277,883 $ 108,455 $ 47,794 $ (893 ) $ 433,239 Product sales revenue 161,723 19,403 878 — 182,004 Affiliate management fee revenue 353 3,474 370 — 4,197 Total revenue 439,959 131,332 49,042 (893 ) 619,440 Operating expenses 100,713 31,410 15,375 (2,204 ) 145,294 Cost of product sales 125,220 18,607 2,148 — 145,975 Earnings of non-controlled entities (422 ) (24,494 ) (660 ) — (25,576 ) Operating margin 214,448 105,809 32,179 1,311 353,747 Depreciation and amortization expense 27,005 12,507 8,073 1,311 48,896 G&A expense 26,720 11,071 5,602 — 43,393 Operating profit $ 160,723 $ 82,231 $ 18,504 $ — $ 261,458 Three Months Ended June 30, 2018 (in thousands) Refined Products Crude Oil Marine Storage Intersegment Eliminations Total Transportation and terminals revenue $ 291,064 $ 137,953 $ 44,146 $ (915 ) $ 472,248 Product sales revenue 150,934 13,282 2,581 — 166,797 Affiliate management fee revenue 352 3,849 845 — 5,046 Total revenue 442,350 155,084 47,572 (915 ) 644,091 Operating expenses 113,342 31,177 17,693 (2,367 ) 159,845 Cost of product sales 137,543 13,761 2,375 — 153,679 (Earnings) losses of non-controlled entities 97 (41,851 ) (756 ) — (42,510 ) Operating margin 191,368 151,997 28,260 1,452 373,077 Depreciation and amortization expense 30,508 12,741 8,918 1,452 53,619 G&A expense 33,187 13,455 6,648 — 53,290 Operating profit $ 127,673 $ 125,801 $ 12,694 $ — $ 266,168

Investments in Non-Controlled25

Investments in Non-Controlled Entities (Tables)	6 Months Ended
	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	Our investments in non-controlled entities at June 30, 2018 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% We serve as operator of BridgeTex, HoustonLink, MVP, Powder Springs, Saddlehorn, Texas Frontera and the pipeline activities of Seabrook. We receive fees for management services 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 $1.4 million and $1.2 million during the three months ended June 30, 2017 and 2018 , respectively, and $2.4 million and $1.7 million during the six months ended June 30, 2017 and 2018 , respectively. We recorded the following revenue and expense transactions from certain of these non-controlled entities in our consolidated statements of income (in millions): Three Months Ended June 30, Six Months Ended June 30, 2017 2018 2017 2018 Transportation and terminals revenue: BridgeTex, pipeline capacity $ 9.0 $ 9.7 $ 17.9 $ 19.6 Double Eagle, throughput revenue $ 1.0 $ 1.4 $ 1.8 $ 2.9 Saddlehorn, storage revenue $ 0.6 $ 0.6 $ 1.1 $ 1.1 Product sales revenue: Powder Springs, butane sales $ — $ 2.2 $ — $ 4.9 Cost of product sales Powder Springs, butane purchases $ — $ 0.4 $ — $ 0.4 Our consolidated balance sheets reflected the following balances related to our investments in non-controlled entities (in millions): December 31, 2017 June 30, 2018 Trade Accounts Receivable Other Accounts Receivable Other Accounts Payable Trade Accounts Receivable Other Accounts Receivable BridgeTex $ — $ — $ — $ 0.2 $ 0.1 Double Eagle $ 0.5 $ — $ — $ 0.4 $ — HoustonLink $ — $ — $ 0.1 $ — $ — MVP $ — $ 0.4 $ — $ — $ 1.1 Powder Springs $ — $ 0.9 $ — $ — $ 2.1 Saddlehorn $ — $ 0.1 $ — $ — $ 0.1 Seabrook $ — $ 0.2 $ — $ — $ 0.4 We have entered into an agreement to guarantee our 50% pro rata share, up to $25.0 million , of obligations under Powder Springs’ credit facility. As of June 30, 2018 , our consolidated balance sheets reflected a $0.4 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. The financial results from MVP and Texas Frontera are included in our marine storage segment, the financial results from BridgeTex, Double Eagle, HoustonLink, 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 follows (in thousands): Investments at December 31, 2017 $ 1,082,511 Additional investment 144,859 Other adjustments 502 Earnings of non-controlled entities: Proportionate share of earnings 78,251 Amortization of excess investment and capitalized interest (1,203 ) Earnings of non-controlled entities 77,048 Less: Distributions of earnings from investments in non-controlled entities 94,661 Investments at June 30, 2018 $ 1,210,259

Inventory (Tables)

Inventory (Tables)	6 Months Ended
	Jun. 30, 2018
Inventory Disclosure [Abstract]
Schedule of Inventory	Inventory at December 31, 2017 and June 30, 2018 was as follows (in thousands): December 31, 2017 June 30, Refined products $ 73,845 $ 60,794 Liquefied petroleum gases 45,553 57,260 Transmix 33,319 37,346 Crude oil 23,763 21,837 Additives 5,865 6,341 Total inventory $ 182,345 $ 183,578

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	6 Months Ended
	Jun. 30, 2018
Retirement Benefits [Abstract]
Schedule of Consolidated Net Periodic Benefit Costs	Net periodic benefit expense for the three and six months ended June 30, 2017 and 2018 was as follows (in thousands): Three Months Ended Three Months Ended June 30, 2017 June 30, 2018 Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Components of net periodic benefit costs: Service cost $ 5,230 $ 66 $ 6,269 $ 51 Interest cost 2,582 123 2,795 102 Expected return on plan assets (2,646 ) — (3,024 ) — Amortization of prior service credit (46 ) — (46 ) — Amortization of actuarial loss 1,783 200 1,569 134 Settlement cost 361 — — — Net periodic benefit cost $ 7,264 $ 389 $ 7,563 $ 287 Six Months Ended Six Months Ended June 30, 2017 June 30, 2018 Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Components of net periodic benefit costs: Service cost $ 10,248 $ 131 $ 21,969 $ 116 Interest cost 4,932 245 9,238 208 Expected return on plan assets (5,133 ) — (6,002 ) — Amortization of prior service credit (91 ) — (91 ) — Amortization of actuarial loss 2,811 400 6,523 294 Settlement cost 1,726 — — — Net periodic benefit cost $ 14,493 $ 776 $ 31,637 $ 618 The service component of our net periodic benefit costs is presented in operating expense and G&A expense, and the non-service components are presented in other expense in our consolidated statements of income.
Schedule of Amounts Recognized in Other Comprehensive Loss	The changes in accumulated other comprehensive loss (“AOCL”) related to employee benefit plan assets and benefit obligations for the three and six months ended June 30, 2017 and 2018 were as follows (in thousands): Three Months Ended Three Months Ended June 30, 2017 June 30, 2018 Gains (Losses) Included in AOCL Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Beginning balance $ (56,236 ) $ (7,681 ) $ (98,261 ) $ (6,437 ) Net actuarial gain — — 386 267 Amortization of prior service credit (46 ) — (46 ) — Amortization of actuarial loss 1,783 200 1,569 134 Settlement cost 361 — — — Ending balance $ (54,138 ) $ (7,481 ) $ (96,352 ) $ (6,036 ) Six Months Ended Six Months Ended June 30, 2017 June 30, 2018 Gains (Losses) Included in AOCL Pension Benefits Other Postretirement Benefits Pension Benefits Other Postretirement Benefits Beginning balance $ (58,584 ) $ (7,881 ) $ (97,226 ) $ (6,597 ) Net actuarial gain (loss) — — (5,558 ) 267 Amortization of prior service credit (91 ) — (91 ) — Amortization of actuarial loss 2,811 400 6,523 294 Settlement cost 1,726 — — — Ending balance $ (54,138 ) $ (7,481 ) $ (96,352 ) $ (6,036 )

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Consolidated Debt	Long-term debt at December 31, 2017 and June 30, 2018 was as follows (in thousands): December 31, June 30, Commercial paper $ — $ 120,000 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 500,000 500,000 Face value of long-term debt 4,550,000 4,670,000 Unamortized debt issuance costs (1) (29,472 ) (28,327 ) Net unamortized debt premium (discount) (1) 215 (1,418 ) Net unamortized amount of gains from historical fair value hedges (1) 3,749 1,818 Long-term debt, net, including current portion 4,524,492 4,642,073 Less: current portion of long-term debt, net 250,974 250,046 Long-term debt, net $ 4,273,518 $ 4,392,027 (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 Instrume29

Derivative Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements	open futures contracts at June 30, 2018 were as follows: Type of Contract/Accounting Methodology Product Represented by the Contract and Associated Barrels Maturity Dates Futures - Economic Hedges 5.4 million barrels of refined products and crude oil Between July 2018 and April 2019 Futures - Economic Hedges 2.3 million barrels of butane and natural gasoline Between July 2018 and April 2019
Derivatives and Offset Amounts	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, 2017 and June 30, 2018 (in thousands): Description 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 (2) Margin Deposit Amounts Not Offset in the Consolidated Balance Sheets Net Asset Amount (1) As of December 31, 2017 $ (38,936 ) $ 12,851 $ (26,085 ) $ 36,690 $ 10,605 As of June 30, 2018 $ (37,657 ) $ 10,289 $ (27,368 ) $ 35,610 $ 8,242 (1) Amount represents the maximum loss we would incur if all of 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 at December 31, 2017. Net amount includes energy commodity derivative contracts classified as current liabilities of $27,368 at June 30, 2018 .
Derivative Gains Included in Accumulated Other Comprehensive Loss (AOCL)	The changes in derivative activity included in AOCL for the three and six months ended June 30, 2017 and 2018 were as follows (in thousands): Three Months Ended Six Months Ended June 30, June 30, Derivative Losses Included in AOCL 2017 2018 2017 2018 Beginning balance $ (32,741 ) $ (27,601 ) $ (34,776 ) $ (33,755 ) Net gain (loss) on cash flow hedges (2,802 ) 1,697 (1,507 ) 7,111 Reclassification of net loss on cash flow hedges to income 739 739 1,479 1,479 Ending balance $ (34,804 ) $ (25,165 ) $ (34,804 ) $ (25,165 )
Derivatives and Hedging-Cash Flow Hedges	The following is a summary of the effect on our consolidated statements of income for the three and six months ended June 30, 2017 and 2018 of derivatives that were designated as cash flow hedges (in thousands): Interest Rate Contracts Amount of Gain (Loss) Recognized in AOCL on Derivative Location of Loss Reclassified from AOCL into Income Amount of Loss Reclassified from AOCL into Income Three Months Ended June 30, 2017 $ (2,802 ) Interest expense $ (739 ) Three Months Ended June 30, 2018 $ 1,697 Interest expense $ (739 )
Schedule of Fair Value Hedging Instruments, Statements of Financial Performance and Financial Position, Location	Three Months Ended June 30, Six Months Ended June 30, 2017 2018 2017 2018 Gain (loss) recognized in other income/expense on derivatives (futures contracts) $ 3,370 $ (368 ) $ 6,768 (549 ) Gain (loss) recognized in other income/expense on hedged item (crude oil) $ (3,370 ) $ 368 $ (6,768 ) 549
Derivatives and Hedging-Overall-Subsequent Measurement	The following table provides a summary of the effect on our consolidated statements of income for the three and six months ended June 30, 2017 and 2018 of derivatives accounted for as economic hedges (in thousands): Amount of Gain (Loss) Recognized on Derivatives Three Months Ended Six Months Ended Location of Gain (Loss) Recognized on Derivatives June 30, June 30, Derivative Instrument 2017 2018 2017 2018 Futures contracts Product sales revenue $ 14,214 $ (38,411 ) $ 42,894 $ (45,786 ) Futures contracts Cost of product sales (1,184 ) 8,337 53 4,393 Total $ 13,030 $ (30,074 ) $ 42,947 $ (41,393 )
Derivatives and Hedging-Designated	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, 2017 and June 30, 2018 (in thousands): 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 June 30, 2018 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 $ 722 Interest rate contracts Other current assets 19,508 Other current liabilities — Interest rate contracts Other noncurrent assets 157 Other noncurrent liabilities 377 Total $ 19,665 Total $ 1,099 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, 2017 and June 30, 2018 (in thousands): 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 June 30, 2018 Asset Derivatives Liability Derivatives Derivative Instrument Balance Sheet Location Fair Value Balance Sheet Location Fair Value Futures contracts Energy commodity derivatives contracts, net $ 10,289 Energy commodity derivatives contracts, net $ 36,935

Long-Term Incentive Plan (Table

Long-Term Incentive Plan (Tables)	6 Months Ended
	Jun. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Equity-Based Incentive Compensation Expense	Our equity-based incentive compensation expense was as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2017 2018 2017 2018 Performance-based awards $ 5,910 $ 9,165 $ 9,391 $ 15,089 Time-based awards 660 882 1,326 1,590 Total $ 6,570 $ 10,047 $ 10,717 $ 16,679 Allocation of LTIP expense on our consolidated statements of income: G&A expense $ 6,514 $ 9,968 $ 10,632 $ 16,545 Operating expense 56 79 85 134 Total $ 6,570 $ 10,047 $ 10,717 $ 16,679

Partners' Capital and Distrib31

Partners' Capital and Distributions (Tables)	6 Months Ended
	Jun. 30, 2018
Partners' Capital Notes [Abstract]
Schedule of Capital Units	The following table details the changes in the number of our limited partner units outstanding from January 1, 2018 through June 30, 2018 : Limited partner units outstanding on January 1, 2018 228,024,556 January 2018–Settlement of employee LTIP awards 168,913 During 2018–Other (a) 1,691 Limited partner units outstanding on June 30, 2018 228,195,160 (a) Limited partner units issued to settle the equity-based retainer paid to an independent director of our general partner.
Schedule of Distributions	Distributions we paid during 2017 and 2018 were as follows (in thousands, except per unit amounts): Payment Date Per Unit Cash Distribution Amount Total Cash Distribution to Limited Partners 02/14/2017 $ 0.8550 $ 194,961 05/15/2017 0.8725 198,951 Through 06/30/2017 1.7275 393,912 08/14/2017 0.8900 202,942 11/14/2017 0.9050 206,362 Total $ 3.5225 $ 803,216 02/14/2018 $ 0.9200 $ 209,940 05/15/2018 0.9375 213,933 Through 06/30/2018 1.8575 423,873 08/14/2018 (a) 0.9575 218,497 Total $ 2.8150 $ 642,370 (a) Our general partner’s board of directors declared this cash distribution in July 2018 to be paid on August 14, 2018 to unitholders of record at the close of business on August 7, 2018 .

Fair Value (Tables)

Fair Value (Tables)	6 Months Ended
	Jun. 30, 2018
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following tables summarize the carrying amounts, fair values and fair value measurements recorded or disclosed as of December 31, 2017 and June 30, 2018 based on the three levels established by ASC 820, Fair Value Measurements and Disclosures (in thousands): December 31, 2017 Assets (Liabilities) Fair Value Measurements using: 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 ) $ — June 30, 2018 Assets (Liabilities) Fair Value Measurements using: 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 $ (27,368 ) $ (27,368 ) $ (27,368 ) $ — $ — Interest rate contracts $ 19,288 $ 19,288 $ — $ 19,288 $ — Long-term receivables $ 23,875 $ 23,875 $ — $ — $ 23,875 Debt $ (4,642,073 ) $ (4,706,966 ) $ — $ (4,706,966 ) $ —

Organization, Description of 33

Organization, Description of Business and Basis of Presentation (Narrative) (Details) $ in Thousands, bbl in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2018USD ($)Terminalbblmi	Mar. 31, 2018USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)Terminalbblmi	Jun. 30, 2017USD ($)	Dec. 31, 2017USD ($)
Organization and Description of Business [Line Items]
Operating	$ 159,845		$ 145,294	$ 303,141	$ 276,886
General and administrative	53,290		43,393	99,846	83,674
Other (income) expense	(119)		$ 2,043	8,605	$ 3,213
Long-term pension and benefits	127,849			127,849		$ 111,305
Accumulated other comprehensive loss	$ 127,553			$ 127,553		$ 137,578
Refined Products Segment [Member]
Organization and Description of Business [Line Items]
Number of Pipeline Terminals | Terminal	53			53
Number of Independent Terminals | Terminal	26			26
Refined Products Segment [Member] | Refined Products Transportation Services [Member]
Organization and Description of Business [Line Items]
Pipeline Length | mi	9,700			9,700
Refined Products Segment [Member] | Ammonia Transportation Services [Member]
Organization and Description of Business [Line Items]
Pipeline Length | mi	1,100			1,100
Crude Oil Pipeline and Terminals Segment [Member]
Organization and Description of Business [Line Items]
Pipeline Length | mi	2,200			2,200
Storage Capacity | bbl	28			28
Contracted Storage | bbl	17			17
Marine Storage Segment [Member]
Organization and Description of Business [Line Items]
Number of Independent Terminals | Terminal	5			5
Storage Capacity | bbl	26			26
Error in Actuarial Assumptions [Member]
Organization and Description of Business [Line Items]
Net periodic benefit cost (credit)		$ 16,000
Operating		5,700
General and administrative		3,400
Other (income) expense		6,900
Long-term pension and benefits		18,800
Accumulated other comprehensive loss		$ 2,800

Organization, Description of 34

Organization, Description of Business and Basis of Presentation (Changes from New Accounting Pronouncements) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jan. 01, 2018	Dec. 31, 2017
Item Effected [Line Items]
Distributions of earnings from investments in non-controlled entities	$ 94,661	$ 57,906
Net Cash Provided by (Used in) Operating Activities	564,066	583,563
Distributions in excess of earnings of non-controlled entities		0
Net Cash Provided by (Used in) Investing Activities	(322,489)	(331,891)
Property, Plant and Equipment, Gross	7,443,095			$ 7,235,468
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	(1,783,036)			(1,682,633)
Property, Plant and Equipment, Net	5,660,059			5,552,835
Investments in non-controlled entities	1,210,259			1,082,511
Deferred revenue	120,134			117,795
Other noncurrent liabilities	69,526			30,350
Limited partner unitholders	2,281,845			2,267,231
Accounting Standards Update 2014-09 [Member]
Item Effected [Line Items]
Property, Plant and Equipment, Gross	7,443,095		$ 7,243,984
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	(1,783,036)		(1,682,958)
Property, Plant and Equipment, Net	5,660,059		5,561,026
Investments in non-controlled entities	1,210,259		1,083,013
Deferred revenue	120,134		115,894
Other noncurrent liabilities	69,526		34,969
Limited partner unitholders	2,281,845		2,273,206
Scenario, Previously Reported [Member]
Item Effected [Line Items]
Distributions of earnings from investments in non-controlled entities		46,754
Net Cash Provided by (Used in) Operating Activities		572,411
Distributions in excess of earnings of non-controlled entities		11,152
Net Cash Provided by (Used in) Investing Activities		(320,739)
Restatement Adjustment [Member] | Accounting Standards Update 2016-15 [Member]
Item Effected [Line Items]
Distributions of earnings from investments in non-controlled entities		11,152
Net Cash Provided by (Used in) Operating Activities		11,152
Distributions in excess of earnings of non-controlled entities		(11,152)
Net Cash Provided by (Used in) Investing Activities		$ (11,152)
Calculated under Revenue Guidance in Effect before Topic 606 [Member] | Accounting Standards Update 2014-09 [Member]
Item Effected [Line Items]
Property, Plant and Equipment, Gross	7,433,091			7,235,468
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	(1,782,591)			(1,682,633)
Property, Plant and Equipment, Net	5,650,500			5,552,835
Investments in non-controlled entities	1,209,757			1,082,511
Deferred revenue	128,349			117,795
Other noncurrent liabilities	64,687			30,350
Limited partner unitholders	2,268,408			$ 2,267,231
Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | Accounting Standards Update 2014-09 [Member]
Item Effected [Line Items]
Property, Plant and Equipment, Gross	10,004		8,516
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	(445)		(325)
Property, Plant and Equipment, Net	9,559		8,191
Investments in non-controlled entities	502		502
Deferred revenue	(8,215)		(1,901)
Other noncurrent liabilities	4,839		4,619
Limited partner unitholders	$ 13,437		$ 5,975

Revenue from Contract with Cu35

Revenue from Contract with Customers (Narrative) (Details) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2018USD ($)	Jun. 30, 2018USD ($)
Revenue from Contract with Customer [Abstract]
Average Delivery Point of Barrels in Pipeline System	50.00%	50.00%
Deferred Revenue, Revenue Recognized	$ 10.8	$ 66.3

Revenue from Contract with Cu36

Revenue from Contract with Customers (Schedule of Prospective Adoption) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Jan. 01, 2018	Dec. 31, 2017
Item Effected [Line Items]
Transportation and terminals revenue	$ 472,248	$ 433,239	$ 904,185	$ 825,910
Depreciation and amortization	53,619	$ 48,896	105,498	$ 96,194
Property, Plant and Equipment, Gross	7,443,095		7,443,095			$ 7,235,468
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	1,783,036		1,783,036			1,682,633
Property, Plant and Equipment, Net	5,660,059		5,660,059			5,552,835
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	1,210,259		1,210,259			1,082,511
Deferred revenue	120,134		120,134			117,795
Other noncurrent liabilities	69,526		69,526			30,350
Limited partner unitholders	2,281,845		2,281,845			2,267,231
Accounting Standards Update 2014-09 [Member]
Item Effected [Line Items]
Transportation and terminals revenue	472,248		904,185
Depreciation and amortization	53,619		105,498
Property, Plant and Equipment, Gross	7,443,095		7,443,095		$ 7,243,984
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	1,783,036		1,783,036		1,682,958
Property, Plant and Equipment, Net	5,660,059		5,660,059		5,561,026
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	1,210,259		1,210,259		1,083,013
Deferred revenue	120,134		120,134		115,894
Other noncurrent liabilities	69,526		69,526		34,969
Limited partner unitholders	2,281,845		2,281,845		2,273,206
Accounting Standards Update 2014-09 [Member] | Calculated under Revenue Guidance in Effect before Topic 606 [Member]
Item Effected [Line Items]
Transportation and terminals revenue	465,079		896,603
Depreciation and amortization	53,555		105,378
Property, Plant and Equipment, Gross	7,433,091		7,433,091			7,235,468
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	1,782,591		1,782,591			1,682,633
Property, Plant and Equipment, Net	5,650,500		5,650,500			5,552,835
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	1,209,757		1,209,757			1,082,511
Deferred revenue	128,349		128,349			117,795
Other noncurrent liabilities	64,687		64,687			30,350
Limited partner unitholders	2,268,408		2,268,408			$ 2,267,231
Accounting Standards Update 2014-09 [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member]
Item Effected [Line Items]
Transportation and terminals revenue	7,169		7,582
Depreciation and amortization	64		120
Property, Plant and Equipment, Gross	10,004		10,004		8,516
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	445		445		325
Property, Plant and Equipment, Net	9,559		9,559		8,191
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	502		502		502
Deferred revenue	(8,215)		(8,215)		(1,901)
Other noncurrent liabilities	4,839		4,839		4,619
Limited partner unitholders	$ 13,437		$ 13,437		$ 5,975

Revenue from Contract with Cu37

Revenue from Contract with Customers ( Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	$ 472,248	$ 433,239	$ 904,185	$ 825,910
Product sales revenue	166,797	182,004	408,389	427,624
Affiliate management fee revenue	(5,046)	(4,197)	(10,296)	(7,980)
Total revenue	644,091	619,440	1,322,870	1,261,514
Revenue from Contract with Customer, Including Assessed Tax	654,328		1,315,770
Operating Leases, Income Statement, Lease Revenue	(23,127)		(42,589)
Unrealized Gain (Loss) on Derivatives	38,410		45,785
Operating Segments [Member] | Refined Products Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	291,064	277,883	551,458	519,788
Product sales revenue	150,934	161,723	383,708	401,893
Affiliate management fee revenue	(352)	(353)	(649)	(682)
Total revenue	442,350	439,959	935,815	922,363
Revenue from Contract with Customer, Including Assessed Tax	474,372		969,896
Operating Leases, Income Statement, Lease Revenue	(2,466)		(5,575)
Unrealized Gain (Loss) on Derivatives	34,840		40,305
Operating Segments [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	137,953	108,455	264,211	213,508
Product sales revenue	13,282	19,403	19,721	22,506
Affiliate management fee revenue	(3,849)	(3,474)	(7,865)	(6,608)
Total revenue	155,084	131,332	291,797	242,622
Revenue from Contract with Customer, Including Assessed Tax	138,342		260,839
Operating Leases, Income Statement, Lease Revenue	(16,463)		(28,573)
Unrealized Gain (Loss) on Derivatives	3,570		5,480
Operating Segments [Member] | Marine Storage Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	44,146	47,794	90,346	94,201
Product sales revenue	2,581	878	4,960	3,225
Affiliate management fee revenue	(845)	(370)	(1,782)	(690)
Total revenue	47,572	49,042	97,088	98,116
Revenue from Contract with Customer, Including Assessed Tax	42,529		86,865
Operating Leases, Income Statement, Lease Revenue	(4,198)		(8,441)
Unrealized Gain (Loss) on Derivatives	0		0
Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	(915)	(893)	(1,830)	(1,587)
Product sales revenue	0	0	0	0
Affiliate management fee revenue	0	0	0	0
Total revenue	(915)	$ (893)	(1,830)	$ (1,587)
Revenue from Contract with Customer, Including Assessed Tax	(915)		(1,830)
Operating Leases, Income Statement, Lease Revenue	0		0
Unrealized Gain (Loss) on Derivatives	0		0
Transferred over Time [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	472,248		904,185
Transferred over Time [Member] | Transportation [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	269,351		515,376
Transferred over Time [Member] | Terminalling [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	51,166		91,226
Transferred over Time [Member] | Storage [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	85,909		174,442
Transferred over Time [Member] | Ancillary Services [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	42,695		80,552
Transferred over Time [Member] | Lease Revenue [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	23,127		42,589
Transferred over Time [Member] | Operating Segments [Member] | Refined Products Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	291,064		551,458
Transferred over Time [Member] | Operating Segments [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	137,953		264,211
Transferred over Time [Member] | Operating Segments [Member] | Marine Storage Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	44,146		90,346
Transferred over Time [Member] | Operating Segments [Member] | Transportation [Member] | Refined Products Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	184,596		351,498
Transferred over Time [Member] | Operating Segments [Member] | Transportation [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	84,755		163,878
Transferred over Time [Member] | Operating Segments [Member] | Transportation [Member] | Marine Storage Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	0		0
Transferred over Time [Member] | Operating Segments [Member] | Terminalling [Member] | Refined Products Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	50,574		89,922
Transferred over Time [Member] | Operating Segments [Member] | Terminalling [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	0		0
Transferred over Time [Member] | Operating Segments [Member] | Terminalling [Member] | Marine Storage Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	592		1,304
Transferred over Time [Member] | Operating Segments [Member] | Storage [Member] | Refined Products Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	24,969		50,216
Transferred over Time [Member] | Operating Segments [Member] | Storage [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	28,536		58,526
Transferred over Time [Member] | Operating Segments [Member] | Storage [Member] | Marine Storage Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	33,319		67,530
Transferred over Time [Member] | Operating Segments [Member] | Ancillary Services [Member] | Refined Products Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	28,459		54,247
Transferred over Time [Member] | Operating Segments [Member] | Ancillary Services [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	8,199		13,234
Transferred over Time [Member] | Operating Segments [Member] | Ancillary Services [Member] | Marine Storage Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	6,037		13,071
Transferred over Time [Member] | Operating Segments [Member] | Lease Revenue [Member] | Refined Products Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	2,466		5,575
Transferred over Time [Member] | Operating Segments [Member] | Lease Revenue [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	16,463		28,573
Transferred over Time [Member] | Operating Segments [Member] | Lease Revenue [Member] | Marine Storage Segment [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	4,198		8,441
Transferred over Time [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	(915)		(1,830)
Transferred over Time [Member] | Intersegment Eliminations [Member] | Transportation [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	0		0
Transferred over Time [Member] | Intersegment Eliminations [Member] | Terminalling [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	0		0
Transferred over Time [Member] | Intersegment Eliminations [Member] | Storage [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	(915)		(1,830)
Transferred over Time [Member] | Intersegment Eliminations [Member] | Ancillary Services [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	0		0
Transferred over Time [Member] | Intersegment Eliminations [Member] | Lease Revenue [Member]
Disaggregation of Revenue [Line Items]
Transportation and terminals revenue	0		0
Transferred at Point in Time [Member]
Disaggregation of Revenue [Line Items]
Product sales revenue	166,797		408,389
Transferred at Point in Time [Member] | Operating Segments [Member] | Refined Products Segment [Member]
Disaggregation of Revenue [Line Items]
Product sales revenue	150,934		383,708
Transferred at Point in Time [Member] | Operating Segments [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Disaggregation of Revenue [Line Items]
Product sales revenue	13,282		19,721
Transferred at Point in Time [Member] | Operating Segments [Member] | Marine Storage Segment [Member]
Disaggregation of Revenue [Line Items]
Product sales revenue	2,581		4,960
Transferred at Point in Time [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Product sales revenue	$ 0		$ 0

Revenue from Contract with Cu38

Revenue from Contract with Customers (Assets and Liabilities) (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Jan. 01, 2018
Revenue from Contract with Customer [Abstract]
Billed Contracts Receivable	$ 102,837	$ 133,084
Contract with Customer, Asset, Net	8,916	8,615
Deferred Revenue	$ 113,207	$ 106,933

Revenue from Contract with Cu39

Revenue from Contract with Customers (Performance Obligations) (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2018USD ($)
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation	$ 3,009,739
Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation	1,439,706
Crude Oil Pipeline and Terminals Segment [Member]
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation	1,210,098
Marine Storage Segment [Member]
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation	$ 359,935
Minimum [Member] | Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Maximum [Member] | Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	20 years

Revenue from Contract with Cu40

Revenue from Contract with Customers (Performance Obligations in Next 12 Months) (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2018USD ($)
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation	$ 3,009,739
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation	$ 772,774
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	12 months
Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation	$ 1,439,706
Refined Products Segment [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation	287,311
Crude Oil Pipeline and Terminals Segment [Member]
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation	1,210,098
Crude Oil Pipeline and Terminals Segment [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation	333,215
Marine Storage Segment [Member]
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation	359,935
Marine Storage Segment [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation	$ 152,248
Minimum [Member] | Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Minimum [Member] | Crude Oil Pipeline and Terminals Segment [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Minimum [Member] | Marine Storage Segment [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Maximum [Member] | Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	20 years
Maximum [Member] | Crude Oil Pipeline and Terminals Segment [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	10 years
Maximum [Member] | Marine Storage Segment [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Segment Reporting Information [Line Items]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	6 years

Segment Disclosures (Schedule O

Segment Disclosures (Schedule Of Business Segment Reporting Information) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Segment Reporting Information [Line Items]
Transportation and terminals revenue	$ 472,248	$ 433,239	$ 904,185	$ 825,910
Product sales revenue	166,797	182,004	408,389	427,624
Affiliate management fee revenue	5,046	4,197	10,296	7,980
Total revenue	644,091	619,440	1,322,870	1,261,514
Operating expenses	159,845	145,294	303,141	276,886
Cost of product sales	153,679	145,975	353,271	318,851
Earnings of non-controlled entities	(42,510)	(25,576)	(77,048)	(47,022)
Operating margin	373,077	353,747	743,506	712,799
Depreciation and amortization	53,619	48,896	105,498	96,194
G&A expense	53,290	43,393	99,846	83,674
Operating profit	266,168	261,458	538,162	532,931
Operating Segments [Member] | Refined Products Segment [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue	291,064	277,883	551,458	519,788
Product sales revenue	150,934	161,723	383,708	401,893
Affiliate management fee revenue	352	353	649	682
Total revenue	442,350	439,959	935,815	922,363
Operating expenses	113,342	100,713	207,391	194,246
Cost of product sales	137,543	125,220	327,876	292,901
Earnings of non-controlled entities	97	(422)	(2,221)	(533)
Operating margin	191,368	214,448	402,769	435,749
Depreciation and amortization	30,508	27,005	59,415	53,971
G&A expense	33,187	26,720	62,074	51,621
Operating profit	127,673	160,723	281,280	330,157
Operating Segments [Member] | Crude Oil Pipeline and Terminals Segment [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue	137,953	108,455	264,211	213,508
Product sales revenue	13,282	19,403	19,721	22,506
Affiliate management fee revenue	3,849	3,474	7,865	6,608
Total revenue	155,084	131,332	291,797	242,622
Operating expenses	31,177	31,410	64,768	58,828
Cost of product sales	13,761	18,607	20,811	21,184
Earnings of non-controlled entities	(41,851)	(24,494)	(73,459)	(45,144)
Operating margin	151,997	105,809	279,677	207,754
Depreciation and amortization	12,741	12,507	25,503	23,363
G&A expense	13,455	11,071	25,361	21,110
Operating profit	125,801	82,231	228,813	163,281
Operating Segments [Member] | Marine Storage Segment [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue	44,146	47,794	90,346	94,201
Product sales revenue	2,581	878	4,960	3,225
Affiliate management fee revenue	845	370	1,782	690
Total revenue	47,572	49,042	97,088	98,116
Operating expenses	17,693	15,375	35,657	28,030
Cost of product sales	2,375	2,148	4,584	4,766
Earnings of non-controlled entities	(756)	(660)	(1,368)	(1,345)
Operating margin	28,260	32,179	58,215	66,665
Depreciation and amortization	8,918	8,073	17,735	16,229
G&A expense	6,648	5,602	12,411	10,943
Operating profit	12,694	18,504	28,069	39,493
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Transportation and terminals revenue	(915)	(893)	(1,830)	(1,587)
Product sales revenue	0	0	0	0
Affiliate management fee revenue	0	0	0	0
Total revenue	(915)	(893)	(1,830)	(1,587)
Operating expenses	(2,367)	(2,204)	(4,675)	(4,218)
Cost of product sales	0	0	0	0
Earnings of non-controlled entities	0	0	0	0
Operating margin	1,452	1,311	2,845	2,631
Depreciation and amortization	1,452	1,311	2,845	2,631
G&A expense	0	0	0	0
Operating profit	$ 0	$ 0	$ 0	$ 0

Investments in Non-Controlled42

Investments in Non-Controlled Entities (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Schedule of Equity Method Investments [Line Items]
Transportation and terminals revenue	$ 472,248	$ 433,239	$ 904,185	$ 825,910
Product sales revenue	166,797	182,004	408,389	427,624
Cost of product sales	153,679	145,975	353,271	318,851
Trade accounts receivable	106,679		106,679		$ 138,779
Other accounts receivable	21,922		21,922		14,561
Change in Equity Method Investments [Roll Forward]
Investments at December 31, 2017			1,082,511
Additional investment			144,859
Other Adjustment to Equity Investment			502
Proportionate share of earnings			78,251
Amortization of excess investment and capitalized interest			(1,203)
Earnings of non-controlled entities	42,510	25,576	77,048	47,022
Distributions of earnings from investments in non-controlled entities			94,661	57,906
Distributions in excess of earnings of non-controlled entities				0
Investments at June 30, 2018	1,210,259		1,210,259
Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party	$ 1,200	1,400	$ 1,700	2,400
BridgeTex [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
BridgeTex [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Transportation and terminals revenue	$ 9,700	9,000	$ 19,600	17,900
Trade accounts receivable	200		200
Other accounts receivable	$ 100		$ 100
Double Eagle Pipeline Llc [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
Double Eagle Pipeline Llc [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Transportation and terminals revenue	$ 1,400	1,000	$ 2,900	1,800
Trade accounts receivable	$ 400		$ 400		500
HoustonLink Pipeline Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
HoustonLink Pipeline Company LLC [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Accounts Payable, Other, Current					100
MVP Terminalling, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
MVP Terminalling, LLC [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Other accounts receivable	$ 1,100		$ 1,100		400
Powder Springs Logistics, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
Powder Springs Logistics, LLC [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Product sales revenue	$ 2,200	0	$ 4,900	0
Cost of product sales	400	0	400	0
Other accounts receivable	$ 2,100		$ 2,100		900
Powder Springs Logistics, LLC [Member] | Equity Method Investee [Member] | Guarantee of Indebtedness of Others [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 25,000		$ 25,000
Guarantees, Fair Value Disclosure	$ 400		$ 400
Saddlehorn Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	40.00%		40.00%
Saddlehorn Pipeline Company [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Transportation and terminals revenue	$ 600	$ 600	$ 1,100	$ 1,100
Other accounts receivable	$ 100		$ 100		100
Seabrook Logistics, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%
Seabrook Logistics, LLC [Member] | Equity Method Investee [Member]
Schedule of Equity Method Investments [Line Items]
Other accounts receivable	$ 400		$ 400		$ 200
Texas Frontera Llc [Member]
Schedule of Equity Method Investments [Line Items]
Interest in equity method investment	50.00%		50.00%

Inventory (Details)

Inventory (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Inventory Disclosure [Abstract]
Refined products	$ 60,794	$ 73,845
Liquefied petroleum gases	57,260	45,553
Transmix	37,346	33,319
Crude oil	21,837	23,763
Additives	6,341	5,865
Total inventory	$ 183,578	$ 182,345

Employee Benefit Plans (Narrati

Employee Benefit Plans (Narrative) (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018USD ($)pension_plan	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)pension_plan	Jun. 30, 2017USD ($)
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Cost	$ 2.3	$ 2.1	$ 6.1	$ 5.4
Number Of Company Sponsored Union Pension Plans | pension_plan	2		2
Pension Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year	$ 31.7		$ 31.7
Other Postretirement Benefits Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year	$ 0.5		$ 0.5

Schedule Of Consolidated Net Pe

Schedule Of Consolidated Net Periodic Benefit Costs (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Pension Plan [Member]
Components of net periodic benefit costs:
Service cost	$ 6,269	$ 5,230	$ 21,969	$ 10,248
Interest cost	2,795	2,582	9,238	4,932
Expected return on plan assets	(3,024)	(2,646)	(6,002)	(5,133)
Amortization of prior service credit	(46)	(46)	(91)	(91)
Amortization of actuarial loss	1,569	1,783	6,523	2,811
Settlement cost	0	361	0	1,726
Net periodic benefit cost	7,563	7,264	31,637	14,493
Other Postretirement Benefits Plan [Member]
Components of net periodic benefit costs:
Service cost	51	66	116	131
Interest cost	102	123	208	245
Expected return on plan assets	0	0	0	0
Amortization of prior service credit	0	0	0	0
Amortization of actuarial loss	134	200	294	400
Settlement cost	0	0	0	0
Net periodic benefit cost	$ 287	$ 389	$ 618	$ 776

Employee Benefit Plans Schedule

Employee Benefit Plans Schedule of Amounts Recognized in Other Comprehensive Income (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Changes in AOCL [Roll Forward]
Accumulated other comprehensive loss (Beginning Bal)			$ (137,578)
Net actuarial loss	$ 653	$ 0	(5,291)	$ 0
Amortization of prior service credit	(46)	(46)	(91)	(91)
Amortization of actuarial loss	1,703	1,983	6,817	3,211
Settlement cost	0	361	0	1,726
Accumulated other comprehensive loss (Ending Bal)	(127,553)		(127,553)
Pension Plan [Member]
Changes in AOCL [Roll Forward]
Accumulated other comprehensive loss (Beginning Bal)	(98,261)	(56,236)	(97,226)	(58,584)
Net actuarial loss	386	0	(5,558)	0
Amortization of prior service credit	(46)	(46)	(91)	(91)
Amortization of actuarial loss	1,569	1,783	6,523	2,811
Settlement cost	0	361	0	1,726
Accumulated other comprehensive loss (Ending Bal)	(96,352)	(54,138)	(96,352)	(54,138)
Other Postretirement Benefits Plan [Member]
Changes in AOCL [Roll Forward]
Accumulated other comprehensive loss (Beginning Bal)	(6,437)	(7,681)	(6,597)	(7,881)
Net actuarial loss	267	0	267	0
Amortization of prior service credit	0	0	0	0
Amortization of actuarial loss	134	200	294	400
Settlement cost	0	0	0	0
Accumulated other comprehensive loss (Ending Bal)	$ (6,036)	$ (7,481)	$ (6,036)	$ (7,481)

Debt (Consolidated Debt) (Detai

Debt (Consolidated Debt) (Details) - USD ($)	Jun. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 4,670,000,000	$ 4,550,000,000
Unamortized debt issuance costs	(28,327,000)	(29,472,000)
Net unamortized premium (discount)	(1,418,000)	215,000
Net unamortized amount of gains from historical fair value hedges	1,818,000	3,749,000
Long-term Debt	4,642,073,000	4,524,492,000
Current portion of long-term debt, net	250,046,000	250,974,000
Long-term debt, net	4,392,027,000	4,273,518,000
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 2026 [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
Debt Instrument, Interest Rate, Stated Percentage	4.20%
Commercial Paper [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 120,000,000	$ 0

Debt (Narrative) (Details)

Debt (Narrative) (Details) - USD ($)	6 Months Ended	12 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Long term debt	$ 4,642,073,000	$ 4,524,492,000
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,000,000,000
Unused commitment fee	0.125%
Long term debt	$ 0	0
Obligation for letters of credit	$ 6,300,000	$ 6,300,000
Revolving Credit Facility [Member] | Minimum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.00%
Unused commitment fee	0.10%
Revolving Credit Facility [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.625%
Unused commitment fee	0.275%
Commercial Paper [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,000,000,000
Long-term Debt, Weighted Average Interest Rate, over Time	2.10%	1.30%
Commercial Paper [Member] | Maximum [Member]
Debt Instrument [Line Items]
Debt Instrument, Term	397 days

Derivative Financial Instrume49

Derivative Financial Instruments (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Derivative [Line Items]
Energy commodity derivatives deposits		$ 35,610		$ 36,690
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months		(3,000)
Commodity Contract [Member]
Derivative [Line Items]
Gain (Loss) from Components Excluded from Assessment of Fair Value Hedge Effectiveness, Net	$ 300		$ 1,700
Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Fair Value, Net		19,300
Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Other Current Assets [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset		19,500
Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Other Noncurrent Assets [Member]
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Asset		200
Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Other Noncurrent Liabilities [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Liability		400
Future Debt Issuance 2019 [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Notional Amount		100,000
Future Debt Issuance 2018 [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Derivative, Notional Amount		$ 100,000

Derivative Financial Instrume50

Derivative Financial Instruments (Schedule Of NYMEX Contracts And Butane Price Swap Purchase Agreements) (Details) bbl in Millions	Jun. 30, 2018bbl
Economic Hedges [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	5.4
Economic Hedges Futures [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	2.3

Derivative Financial Instrume51

Derivative Financial Instruments (Schedule of Derivative Offset Amounts) (Details) - Exchange Traded [Member] - USD ($) $ in Thousands		Jun. 30, 2018	Dec. 31, 2017
Derivative [Line Items]
Derivative Liability, Fair Value, Gross Liability		$ 37,657	$ 38,936
Derivative Asset, Fair Value, Gross Asset		10,289	12,851
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	[1]	(27,368)	(26,085)
Derivative, Collateral, Right to Reclaim Cash		35,610	36,690
Amount After Offset	[2]	8,242	10,605
Other Current Liabilities [Member]
Derivative [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral		$ (27,368)	(25,694)
Other Noncurrent Liabilities [Member]
Derivative [Line Items]
Derivative Liability, 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 at December 31, 2017. Net amount includes energy commodity derivative contracts classified as current liabilities of $27,368 at June 30, 2018.
[2]	Amount represents the maximum loss we would incur if all of our counterparties failed to perform on their derivative contracts.

Derivative Financial Instrume52

Derivative Financial Instruments (Derivative Gains Included In Accumulated Other Comprehensive Loss (AOCL) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Derivative Gains Included in AOCI [Roll Forward]
Beginning balance	$ (27,601)	$ (32,741)	$ (33,755)	$ (34,776)
Net gain (loss) on cash flow hedges	1,697	(2,802)	7,111	(1,507)
Reclassification of net loss (gain) on cash flow hedges to income	739	739	1,479	1,479
Ending balance	$ (25,165)	$ (34,804)	$ (25,165)	$ (34,804)

Derivative Financial Instrume53

Derivative Financial Instruments (Derivatives And Hedging-Cash Flow Hedges) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on cash flow hedges	$ 1,697	$ (2,802)	$ 7,111	$ (1,507)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss) on cash flow hedges	1,697	(2,802)	7,111	(1,507)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net	$ (739)	$ (739)	$ (1,479)	$ (1,479)

Derivative Financial Instrume54

Derivative Financial Instruments (Derivatives and Hedging-Fair Value Hedges) (Details) - Commodity Contract [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Derivative Instruments, Gain (Loss) [Line Items]
Increase (Decrease) in Fair Value of Price Risk Fair Value Hedging Instruments	$ (368)	$ 3,370	$ (549)	$ 6,768
Increase (Decrease) in Fair Value of Hedged Item in Price Risk Fair Value Hedge	$ 368	$ (3,370)	$ 549	$ (6,768)

Derivative Financial Instrume55

Derivative Financial Instruments (Derivatives And Hedging-Overall-Subsequent Measurement) (Details) - Not Designated as Hedging Instrument [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ (30,074)	$ 13,030	$ (41,393)	$ 42,947
Commodity Contract [Member] | Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(38,411)	14,214	(45,786)	42,894
Commodity Contract [Member] | Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 8,337	$ (1,184)	$ 4,393	$ 53

Derivative Financial Instrume56

Derivative Financial Instruments (Derivatives and Hedging - Designated) (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 19,665	$ 12,177
Derivative Liability, Fair Value, Gross Liability	1,099	173
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	722	173
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	19,508	12,177
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
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	157
Designated as Hedging Instrument [Member] | Interest Rate Contract [Member] | Other Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	377
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	10,289	12,605
Not Designated as Hedging Instrument [Member] | Commodity Contract [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	$ 36,935	38,126
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

Commitments and Contingencies (

Commitments and Contingencies (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Loss Contingencies [Line Items]
Liabilities recognized for estimated environmental costs	$ 17.3		$ 17.3		$ 19.3
Environmental expenses	2.8	$ 0.2	5.3	$ 4.5
Receivables from insurance carriers related to environmental matters	4.7		4.7		7.2
Accounts Receivable [Member]
Loss Contingencies [Line Items]
Receivables from insurance carriers related to environmental matters	0.6		0.6		0.5
Other Noncurrent Assets [Member]
Loss Contingencies [Line Items]
Receivables from insurance carriers related to environmental matters	$ 4.1		$ 4.1		$ 6.7

Long-Term Incentive Plan (Narra

Long-Term Incentive Plan (Narrative) (Details) - shares	Feb. 01, 2018	Jun. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Limited partners' capital account, units authorized for issuance (in shares)		11,900,000
Limited partner unitholders, units remaining available (in shares)		2,100,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period (in shares)	294,054
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years

Long-Term Incentive Plan (Equit

Long-Term Incentive Plan (Equity-Based Incentive Compensation Expense) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	$ 10,047	$ 6,570	$ 16,679	$ 10,717
G&A Expense [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	9,968	6,514	16,545	10,632
Operating Expenses [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	79	56	134	85
Performance Based Awards [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	9,165	5,910	15,089	9,391
Time-Based Awards [Member]
Share-based Compensation Arrangements by Share-based Payment Award [Line Items]
Allocation of LTIP expense on consolidated statements of income	$ 882	$ 660	$ 1,590	$ 1,326

Partners' Capital and Distrib60

Partners' Capital and Distributions (Narrative) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2018USD ($)
Partners' Capital [Abstract]
Amount Authorized Under Equity Distribution Agreement	$ 750

Partners' Capital and Distrib61

Partners' Capital and Distributions (Schedule of Capital Units) (Details)	6 Months Ended
	Jun. 30, 2018shares
Increase (Decrease) in Partners' Capital [Roll Forward]
Limited partner units outstanding on January 1, 2018 (in shares)	228,024,556
Limited partner units outstanding on March 31, 2018 (in shares)	228,195,160
Management [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
During 2018–Other (in shares)	168,913
Director [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
During 2018–Other (in shares)	1,691

Partners' Capital and Distrib62

Partners' Capital and Distributions (Schedule Of Distributions) (Details) - USD ($) $ / shares in Units, $ in Thousands	Aug. 14, 2018	May 15, 2018	Feb. 14, 2018	Nov. 14, 2017	Aug. 14, 2017	May 15, 2017	Feb. 14, 2017	Jun. 30, 2018	Jun. 30, 2017	Sep. 30, 2018	Dec. 31, 2017
Distribution Made to Limited Partner [Line Items]
Cash distribution per unit (in dollars per share)		$ 0.9375	$ 0.9200	$ 0.9050	$ 0.8900	$ 0.8725	$ 0.855	$ 1.8575	$ 1.7275		$ 3.5225
Total Cash Distribution to Limited Partners		$ 213,933	$ 209,940	$ 206,362	$ 202,942	$ 198,951	$ 194,961	$ 423,873	$ 393,912		$ 803,216
Scenario, Forecast
Distribution Made to Limited Partner [Line Items]
Cash distribution per unit (in dollars per share)	$ 0.9575									$ 2.8150
Total Cash Distribution to Limited Partners	$ 218,497									$ 642,370

Fair Value (Schedule Of Carryin

Fair Value (Schedule Of Carrying Amounts And Fair Values Of Financial Assets/Liabilities) (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Fair Value, Inputs, Level 1 [Member] | Commodity Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Liability	$ (27,368)	$ (26,085)
Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt	(4,706,966)	(4,826,480)
Significant Other Observable Inputs (Level 2) [Member] | Interest Rate Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	19,288	12,177
Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivables	23,875	27,676
Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivables	23,875	27,676
Debt	(4,642,073)	(4,524,492)
Reported Value Measurement [Member] | Commodity Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Liability	(27,368)	(26,085)
Reported Value Measurement [Member] | Interest Rate Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	19,288	12,177
Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term receivables	23,875	27,676
Debt	(4,706,966)	(4,826,480)
Estimate of Fair Value Measurement [Member] | Commodity Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Liability	(27,368)	(26,085)
Estimate of Fair Value Measurement [Member] | Interest Rate Contract [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	$ 19,288	$ 12,177

Related Party Transactions (Det

Related Party Transactions (Details) - Director [Member] - Methvin Company [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Related Party Transaction [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party	$ 4.6	$ 4.3	$ 8.4	$ 8.4
Accounts Receivable, Related Parties, Current	$ 2		$ 2		$ 1.6

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Thousands	Aug. 14, 2018	May 15, 2018	Feb. 14, 2018	Nov. 14, 2017	Aug. 14, 2017	May 15, 2017	Feb. 14, 2017	Jun. 30, 2018	Jun. 30, 2017	Sep. 30, 2018	Dec. 31, 2017
Subsequent Event [Line Items]
Cash distribution per unit (in dollars per share)		$ 0.9375	$ 0.9200	$ 0.9050	$ 0.8900	$ 0.8725	$ 0.855	$ 1.8575	$ 1.7275		$ 3.5225
Total cash distributions		$ 213,933	$ 209,940	$ 206,362	$ 202,942	$ 198,951	$ 194,961	$ 423,873	$ 393,912		$ 803,216
Scenario, Forecast
Subsequent Event [Line Items]
Cash distribution per unit (in dollars per share)	$ 0.9575									$ 2.8150
Total cash distributions	$ 218,497									$ 642,370