Buckeye Partners (BPL) 10-Q 1 Aug 19 2019 Q2 Quarterly report Financial data

Cover Page

Cover Page - shares	6 Months Ended
	Jun. 30, 2019	Jul. 26, 2019
Cover page.
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2019
Document Transition Report	false
Entity File Number	1-9356
Entity Registrant Name	BUCKEYE PARTNERS, L.P.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	23-2432497
Entity Address, Address Line One	One Greenway Plaza
Entity Address, Address Line Two	Suite 600
Entity Address, City or Town	Houston,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77046
City Area Code	832
Local Phone Number	615-8600
Title of 12(b) Security	Limited partner units representing limited partnership interests
Trading Symbol	BPL
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		153,921,387
Entity Central Index Key	0000805022
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q2

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Revenue:
Total revenue from contracts with customers	$ 655,847	$ 783,196	$ 1,484,066	$ 1,763,458
Total revenue	791,702	940,839	1,820,674	2,123,944
Costs and expenses:
Cost of product sales	416,397	552,399	1,071,504	1,337,726
Operating expenses	156,554	156,505	309,452	311,373
Depreciation and amortization	65,859	66,569	129,743	130,707
General and administrative	18,306	21,792	39,956	45,081
Other, net	(3,007)	(2,123)	(1,794)	(16,153)
Total costs and expenses	654,109	795,142	1,548,861	1,808,734
Operating income	137,593	145,697	271,813	315,210
Other (expense) income:
Earnings from equity investments	2,871	8,265	6,216	15,754
Interest and debt expense	(49,574)	(59,566)	(101,742)	(118,671)
Other expense, net	(78)	(297)	(3,917)	(612)
Total other expense, net	(46,781)	(51,598)	(99,443)	(103,529)
Income before taxes	90,812	94,099	172,370	211,681
Income tax expense	(297)	(782)	(595)	(1,272)
Net income	90,515	93,317	171,775	210,409
Less: Net income attributable to noncontrolling interests	(496)	(1,413)	(994)	(6,132)
Net income attributable to Buckeye Partners, L.P.	$ 90,019	$ 91,904	$ 170,781	$ 204,277
Earnings per unit attributable to Buckeye Partners, L.P.:
Basic (in dollars per share)	$ 0.58	$ 0.59	$ 1.10	$ 1.34
Diluted (in dollars per share)	$ 0.58	$ 0.59	$ 1.09	$ 1.33
Weighted average units outstanding:
Basic (in shares)	153,918	153,258	153,882	151,093
Diluted (in shares)	154,742	153,989	154,639	151,770
Product sales
Revenue:
Total revenue from contracts with customers	$ 420,573	$ 556,850	$ 1,083,569	$ 1,349,037
Transportation, storage and other services
Revenue:
Total revenue from contracts with customers	$ 371,129	$ 383,989	$ 737,105	$ 774,907

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Statement of Comprehensive Income [Abstract]
Net income	$ 90,515	$ 93,317	$ 171,775	$ 210,409
Other comprehensive income (loss):
Unrealized (losses) gains on derivative instruments, net	(823)	8,936	(722)	23,074
Reclassification of derivative losses to net income, net	2,296	2,295	4,592	4,632
Changes in benefit plan assets and benefit obligations	(66)	(18)	(821)	0
Other comprehensive loss from equity method investments	0	(21,720)	0	(7,757)
Total other comprehensive income (loss)	1,407	(10,507)	3,049	19,949
Comprehensive income	91,922	82,810	174,824	230,358
Less: Comprehensive income attributable to noncontrolling interests	(496)	(1,413)	(994)	(6,132)
Comprehensive income attributable to Buckeye Partners, L.P.	$ 91,426	$ 81,397	$ 173,830	$ 224,226

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 6,291	$ 1,830
Accounts receivable, net	217,430	219,751
Construction and pipeline relocation receivables	13,339	14,259
Inventories	130,737	210,884
Derivative assets	2,756	18,019
Prepaid and other current assets	65,165	58,894
Total current assets	435,718	523,637
Property, plant and equipment	8,421,105	8,258,694
Less: Accumulated depreciation	(1,438,994)	(1,343,898)
Property, plant and equipment, net	6,982,111	6,914,796
Equity investments	169,400	1,111,793
Goodwill	470,875	470,875
Intangible assets	610,900	610,900
Less: Accumulated amortization	(349,797)	(317,589)
Intangible assets, net	261,103	293,311
Other non-current assets	171,951	41,138
Total assets	8,491,158	9,355,550
Current liabilities:
Line of credit	109,820	177,727
Current portion of long-term debt	0	525,000
Accounts payable	99,270	147,525
Derivative liabilities	824	1,320
Accrued and other current liabilities	268,866	276,193
Total current liabilities	478,780	1,127,765
Long-term debt	3,730,161	4,011,715
Other non-current liabilities	197,596	84,900
Total liabilities	4,406,537	5,224,380
Commitments and contingent liabilities (Note 4 - Commitments and Contingencies)
Buckeye Partners, L.P. capital:
Limited Partners (153,921,257 and 153,755,031 units outstanding as of June 30, 2019 and December 31, 2018, respectively)	4,110,729	4,160,143
Accumulated other comprehensive loss	(37,012)	(40,061)
Total Buckeye Partners, L.P. capital	4,073,717	4,120,082
Noncontrolling interests	10,904	11,088
Total partners’ capital	4,084,621	4,131,170
Total liabilities and partners’ capital	$ 8,491,158	$ 9,355,550

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Jun. 30, 2019	Dec. 31, 2018
Statement of Financial Position [Abstract]
Limited Partners, units outstanding	153,921,257	153,755,031

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Cash flows from operating activities:
Net income	$ 171,775	$ 210,409
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation and amortization	129,743	130,707
Amortization of debt issuance costs, discounts and terminated interest rate swaps	7,588	7,828
Non-cash unit-based compensation expense	15,681	16,772
Gain on asset impairments, disposals and recoveries, net	596	(15,655)
Changes in fair value of derivatives, net	14,927	190
Earnings from equity investments	(6,216)	(15,754)
Distributions of earnings from equity investments	5,075	15,613
Other non-cash items	2,980	1,785
Change in assets and liabilities, net of amounts related to acquisitions:
Accounts receivable, net	4,103	49,409
Construction and pipeline relocation receivables	920	(482)
Inventories	79,782	145,516
Prepaid and other current assets	(16,271)	(29,275)
Accounts payable	(42,792)	(79,125)
Accrued and other current liabilities	(13,091)	(24,036)
Other non-current assets and liabilities	(5,199)	17,239
Net cash provided by operating activities	349,601	431,141
Cash flows from investing activities:
Capital expenditures	(191,166)	(250,035)
Proceeds from sale of VTTI and DPTS asset package	985,000	0
Contribution to equity investment	(38,196)	(28,361)
Distributions from equity investments in excess of earnings	6,583	32,928
Acquisition of business, net of cash acquired	0	883
Proceeds from property disposals and recoveries	9,336	9,388
Net cash provided by (used in) investing activities	771,557	(235,197)
Cash flows from financing activities:
Net proceeds from issuance of Units and exercise of Unit options	0	262,042
Payment of tax withholding on vesting of LTIP awards	(2,310)	(6,728)
Proceeds from issuance of long-term debt, net of issuance costs	0	394,936
Loss on early extinguishment of debt	(3,647)	0
Repayment of long-term debt	(525,000)	(300,000)
Borrowings under the BPL Credit Facility	404,515	1,294,180
Repayments under the BPL Credit Facility	(688,662)	(1,172,340)
Net repayments under the BMSC Credit Facility	(67,910)	(81,198)
Acquisition of noncontrolling interest	0	(210,000)
Contributions from noncontrolling interests	0	7,400
Distributions paid to noncontrolling interests	(1,905)	(12,602)
Distributions to LP unitholders	(231,778)	(372,157)
Net cash used in financing activities	(1,116,697)	(196,467)
Net increase (decrease) in cash and cash equivalents	4,461	(523)
Cash and cash equivalents — Beginning of period	1,830	2,180
Cash and cash equivalents — End of period	$ 6,291	$ 1,657

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS' CAPITAL - USD ($) $ in Thousands	Total	Accumulated Other Comprehensive (Loss) Income	Noncontrolling Interests	Limited Partners
Beginning balance at Dec. 31, 2017	$ 4,868,322	$ 28,631	$ 277,385	$ 4,562,306
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	210,409		6,132	204,277
Acquisition of noncontrolling interest	(210,000)		(267,006)	57,006
Distributions paid to unitholders	(372,157)		1,372	(373,529)
Net proceeds from issuance of Units	262,086			262,086
Amortization of unit-based compensation awards	16,772			16,772
Payment of tax withholding on vesting of LTIP awards	(6,728)			(6,728)
Distributions paid to noncontrolling interest	(14,034)		(14,034)
Contributions from noncontrolling interests	7,400		7,400
Accrual for distribution equivalent rights	(2,386)			(2,386)
Other	(44)			(44)
Other comprehensive income	19,949	19,949
Ending balance at Jun. 30, 2018	4,779,589	48,580	11,249	4,719,760
Beginning balance at Mar. 31, 2018	5,089,188	59,087	279,440	4,750,661
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	93,317		1,413	91,904
Acquisition of noncontrolling interest	(210,000)		(267,006)	57,006
Distributions paid to unitholders	(186,088)		677	(186,765)
Net proceeds from issuance of Units	20			20
Amortization of unit-based compensation awards	8,008			8,008
Payment of tax withholding on vesting of LTIP awards	(132)			(132)
Distributions paid to noncontrolling interest	(6,275)		(6,275)
Contributions from noncontrolling interests	3,000		3,000
Accrual for distribution equivalent rights	(898)			(898)
Other	(44)			(44)
Other comprehensive income	(10,507)	(10,507)
Ending balance at Jun. 30, 2018	4,779,589	48,580	11,249	4,719,760
Beginning balance at Dec. 31, 2018	4,131,170	(40,061)	11,088	4,160,143
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	171,775		994	170,781
Distributions paid to unitholders	(231,778)		727	(232,505)
Amortization of unit-based compensation awards	15,681			15,681
Payment of tax withholding on vesting of LTIP awards	(2,310)			2,310
Distributions paid to noncontrolling interest	(1,905)		(1,905)
Accrual for distribution equivalent rights	(1,058)			(1,058)
Other	(3)			(3)
Other comprehensive income	3,049	3,049
Ending balance at Jun. 30, 2019	4,084,621	(37,012)	10,904	4,110,729
Beginning balance at Mar. 31, 2019	4,104,396	(38,419)	11,017	4,131,798
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	90,515		496	90,019
Distributions paid to unitholders	(115,926)		349	(116,275)
Amortization of unit-based compensation awards	5,769			5,769
Payment of tax withholding on vesting of LTIP awards	(65)			(65)
Distributions paid to noncontrolling interest	(958)		(958)
Accrual for distribution equivalent rights	(517)		0	(517)
Other comprehensive income	1,407	1,407
Ending balance at Jun. 30, 2019	$ 4,084,621	$ (37,012)	$ 10,904	$ 4,110,729

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS' CAPITAL (Parenthetical) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Statement of Partners' Capital [Abstract]
Distribution per LP unit (in dollars per share)	$ 0.75	$ 1.2625	$ 1.5	$ 2.5250

ORGANIZATION AND BASIS OF PRESE

ORGANIZATION AND BASIS OF PRESENTATION	6 Months Ended
	Jun. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
ORGANIZATION AND BASIS OF PRESENTATION	1. ORGANIZATION AND BASIS OF PRESENTATION Organization Buckeye Partners, L.P. is a publicly traded Delaware master limited partnership (“MLP”), and its limited partner units representing limited partnership interests (“LP Units”), are listed on the New York Stock Exchange under the ticker symbol “BPL.” Buckeye GP LLC (“Buckeye GP”) is our general partner. As used in these Notes to Unaudited Condensed Consolidated Financial Statements, “ we ,” “ us ,” “ our ” and “ Buckeye ” mean Buckeye Partners, L.P. and, where the context requires, include our subsidiaries. We own and operate a diversified global network of integrated assets providing midstream logistic solutions, primarily consisting of the transportation, storage, processing and marketing of liquid petroleum products. We are one of the largest independent liquid petroleum products pipeline operators in the United States in terms of volumes delivered, with approximately 6,000 miles of pipeline. We also use our service expertise to operate and/or maintain third-party pipelines and terminals and perform certain engineering and construction services for our customers. Our global terminal network comprises more than 115 liquid petroleum products terminals with aggregate tank capacity of over 118 million barrels across our portfolio of pipelines, inland terminals and marine terminals located primarily in key petroleum logistics hubs in the East Coast, Midwest and Gulf Coast regions of the United States as well as in the Caribbean. Our terminal assets facilitate global flows of crude oil and refined petroleum products, offering our customers connectivity between supply areas and market centers through some of the world’s most important bulk liquid storage and blending hubs. Our wholly-owned flagship marine terminal in The Bahamas, Buckeye Bahamas Hub Limited (“BBH”), is one of the largest marine crude oil and refined petroleum products storage facilities in the world and provides an array of logistics and blending services for the global flow of petroleum products. Our Gulf Coast regional hub, Buckeye Texas Partners LLC (“Buckeye Texas”), offers world-class marine terminalling, storage and processing capabilities. We are also a wholesale distributor of refined petroleum products in certain areas served by our pipelines and terminals. Merger Agreement On May 10, 2019, we entered into an Agreement and Plan of Merger (the “Merger Agreement”) with Hercules Intermediate Holdings LLC, a Delaware limited liability company and an affiliate of IFM Global Infrastructure Fund (“Parent”), Hercules Merger Sub LLC, a Delaware limited liability company and a wholly owned subsidiary of Parent (“Merger Sub”), Buckeye Pipe Line Services Company, a Pennsylvania corporation (“ServiceCo”), and Buckeye GP. The Merger Agreement, which has been unanimously approved by the board of directors of Buckeye GP (the “Board”) on our behalf, provides for the merger of Merger Sub with and into Buckeye (the “Merger”), with Buckeye surviving the Merger as a wholly owned subsidiary of Parent. After the Merger, Buckeye’s LP Units will cease to be publicly traded. Subject to the terms and conditions set forth in the Merger Agreement, at the effective time of the Merger (the “Effective Time”), each of our issued and outstanding LP Units (other than LP Units owned immediately prior to the Effective Time by us, by Parent or any of its affiliates or under certain circumstances by ServiceCo), will be converted into the right to receive $41.50 in cash per LP Unit (the “Merger Consideration”), without interest. Completion of the Merger is subject to customary closing conditions, including unitholder and certain regulatory approvals. On July 31, 2019, the Merger Agreement and the transactions contemplated thereby were approved by the affirmative vote of the holders of a majority of the outstanding LP Units entitled to vote thereon. We expect the Merger to close during the fourth quarter of 2019. For more information regarding the Merger and the Merger Agreement, please see our Form 8-K filed with the U.S. Securities and Exchange Commission (“SEC”) on May 10, 2019 and our Schedule 14A filed with the SEC on June 25, 2019, as supplemented by the Form 8-K we filed with the SEC on July 22, 2019. Basis of Presentation and Principles of Consolidation The unaudited condensed consolidated financial statements and the accompanying notes are prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and the rules of the SEC. Accordingly, our financial statements reflect all normal and recurring adjustments that are, in the opinion of management, necessary for a fair presentation of our results of operations for the interim periods. The unaudited condensed consolidated financial statements include the accounts of our subsidiaries controlled by us and variable interest entities of which we are the primary beneficiary. Intercompany transactions are eliminated in consolidation. The preparation of consolidated financial statements in conformity with GAAP requires our management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenue and expenses during the reporting period and disclosure of contingent assets and liabilities at the date of the consolidated financial statements. Estimates and assumptions about future events and their effects cannot be made with certainty. Estimates may change as new events occur, when additional information becomes available and if our operating environment changes. Actual results could differ from our estimates. We believe that the disclosures in these unaudited condensed consolidated financial statements are adequate to make the information presented not misleading. These interim financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto contained in our Annual Report on Form 10-K for the year ended December 31, 2018 . Recently Adopted Accounting Standards Derivatives and Hedging . Effective January 1, 2019, we adopted Accounting Standards Update (“ASU”) 2017-12, which amends and simplifies the existing standard in order to improve the financial reporting of hedging relationships to better align risk management activities in financial statements and make targeted improvements to simplify the application of the current standard related to the assessment of hedge effectiveness. In October 2018, the Financial Accounting Standards Board (“FASB”) issued ASU 2018-16, which includes the Overnight Index Swap Rate based on Secured Overnight Financing Rate as a U.S. benchmark interest rate for hedge accounting purposes under Accounting Standards Codification (“ASC”) Topic 815, Derivatives and Hedging. The adoption of this standard did not have a material impact on our unaudited condensed consolidated financial statements and disclosures. Leases . Effective January 1, 2019, we adopted ASC Topic 842, Leases (“ASC 842”), applying the modified retrospective transition method. We applied the transition provision for ASC 842 at our adoption date instead of at the earliest comparative period presented in our financial statements and, therefore, we recognized and measured leases existing at January 1, 2019, but without retrospective application. ASC 842 requires lessees to recognize a right-of-use (“ROU”) lease asset and a lease liability on the balance sheet for leases with lease terms greater than twelve months. ASC 842 also requires enhanced disclosures regarding the amount, timing and uncertainty of cash flows arising from leases. The most significant impact was the recognition of ROU lease assets and lease liabilities for operating leases on our unaudited condensed consolidated balance sheet along with certain incremental disclosures. No impact was recorded to the income statement or beginning retained earnings upon our adoption of ASC 842. See Note 9 - Leases for further discussion. Improvements to Nonemployee Share-Based Payment Accounting. Effective January 1, 2019, we adopted ASU 2018-07, which conformed the current nonemployee share-based accounting with employee share-based accounting. The adoption of this standard did not have a material impact on our unaudited condensed consolidated financial statements and disclosures. Recent Accounting Standards Not Yet Adopted Codification Improvements . In April 2019, the FASB issued ASU 2019-04, which clarifies certain aspects of accounting for credit losses, hedging activities, and financial instruments (addressed by ASUs 2016-13, 2017-12, and 2016-01, respectively). The amendments clarify the scope of the credit losses standard (ASU 2016-13) and address issues related to accrued interest receivable balances, recoveries, variable interest rates and prepayments. The amendments on recognizing and measuring financial instruments (ASU 2016-01), address the scope of the guidance, the requirement for remeasurement under ASC 820 when using the measurement alternative, certain disclosure requirements and which equity securities have to be remeasured at historical exchange rates. The amendments to the credit losses and hedging standards have the same effective dates as those standards, unless an entity has already adopted the standards. The amendments to the recognition and measurement guidance are effective for fiscal years beginning after December 15, 2019. Early adoption is permitted. We adopted the amendments related to hedging and financial instruments effective June 30, 2019, which did not have an impact on our unaudited condensed consolidated financial statements. We expect to adopt the amendments related to credit losses concurrently with the adoption of ASU 2016-13. Collaborative Arrangements. In November 2018, the FASB issued ASU 2018-18, which clarifies whether certain transactions between collaborative arrangement participants should be accounted for as revenue under ASC Topic 606, Revenue from Contracts with Customers (“ASC 606”). The new standard also provides more comparability in the presentation of revenue for certain transactions between collaborative arrangement participants. The standard is effective for fiscal years beginning after December 15, 2019 and interim periods within those fiscal years, with early adoption permitted. The standard should be applied retrospectively to the date of initial application of ASC 606. We expect to adopt this standard effective January 1, 2020 and are currently evaluating the impact that it will have on our consolidated financial statements and disclosures. Targeted Improvements to Related Party Guidance for Variable Interest Entities. In October 2018, the FASB issued ASU 2018-17 that changes the standard for determining whether a decision-making fee is a variable interest. The standard provides that indirect interests held through related parties under common control will be considered on a proportional basis when determining whether certain decision-making fees are variable interests. The standard is effective for fiscal years beginning after December 15, 2019 and interim periods within those fiscal years, with early adoption permitted. The standard should be applied retrospectively, with a cumulative effect adjustment to retained earnings. We expect to adopt this standard effective January 1, 2020 and are currently evaluating the impact that it will have on our consolidated financial statements and disclosures. Cloud Computing Arrangements. In August 2018, the FASB issued ASU 2018-15, which aligns a customer’s accounting for capitalizing implementation costs in a cloud computing service arrangement that is hosted by the vendor with the requirements for capitalizing implementation costs incurred to develop or obtain an internal-use software license. The standard is effective for fiscal years beginning after December 15, 2019 and interim periods within those fiscal years, with early adoption permitted. The standard can be applied prospectively or retrospectively. We expect to adopt this standard effective January 1, 2020 and are currently evaluating the impact that it will have on our consolidated financial statements and disclosures. Changes to the Disclosure Requirements for Defined Benefit Plans. In August 2018, the FASB issued ASU 2018-14, which amends the existing standard on disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The new standard is effective for fiscal years ending after December 15, 2020, with early adoption permitted. The new standard requires retrospective application. We expect to adopt this standard effective January 1, 2021 and are currently evaluating the impact that it will have on our disclosures. Changes to the Disclosure Requirements for Fair Value Measurement. In August 2018, the FASB issued ASU 2018-13, which amends the existing standard on disclosure requirements for fair value measurements. The new standard is effective for fiscal years beginning after December 15, 2019 and interim periods within those fiscal years, with early adoption permitted. The new standard requires prospective application on changes in unrealized gains and losses, the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements, and the narrative description of measurement uncertainty. The effects of other amendments must be applied retrospectively to all periods presented. We expect to adopt this standard effective January 1, 2020 and are currently evaluating the impact that it will have on our disclosures. Measurement of Credit Losses on Financial Instruments. In June 2016, the FASB issued ASU 2016-13, which replaces the current incurred loss impairment method with a method that reflects expected credit losses on financial instruments. In November 2018, the FASB issued update ASU 2018-19 that clarifies the scope of the standard in the amendments in ASU 2016-13. In May 2019, the FASB issued ASU 2019-05, which provides entities with an option to irrevocably elect the fair value option for certain financial instruments. The new standard is effective as of January 1, 2020, and early adoption is permitted as of January 1, 2019. We expect to adopt this standard effective January 1, 2020 and are currently evaluating the impact that the adoption of this standard will have on our consolidated financial statements and disclosures.

REVENUE

REVENUE	6 Months Ended
	Jun. 30, 2019
Revenue from Contract with Customer [Abstract]
REVENUE	2. REVENUE The majority of our service-based revenue is derived from fee-based transportation, terminalling, and storage services that we provide to our customers. We also generate revenue from the marketing and sale of petroleum products. We recognize revenues from customer fees for services rendered or by selling petroleum products. Under ASC 606, we recognize revenue over time or at a point in time, depending on the nature of the performance obligations contained in the respective contract with our customer. A performance obligation is a promise in a contract to transfer goods or services to the customer. The contract transaction price is allocated to each performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. In certain situations, we recognize revenue pursuant to accounting standards other than ASC 606. These situations primarily relate to leases and derivatives. We have appropriately applied the guidance in ASC Topic 340-40, Other Assets and Deferred Costs: Contracts with Customers , for determining whether to capitalize costs to fulfill a contract. Contract Balances At June 30, 2019 and December 31, 2018 , receivables from contracts with customers was $204.2 million and $199.3 million , respectively. The following table presents the activity in our contract assets and contract liabilities (in thousands): Six Months Ended 2019 2018 Contract Assets: Balance as of January 1 $ 16,989 $ 13,999 Additions 17,133 25,633 Transfers to accounts receivable (16,890 ) (13,751 ) Balance as of June 30 $ 17,232 $ 25,881 Contract Liabilities: Balance as of January 1 $ (26,999 ) $ (15,778 ) Additions (18,654 ) (18,184 ) Transfers to revenues (1) 12,403 6,586 Balance as of June 30 $ (33,250 ) $ (27,376 ) (1) For the three months ended June 30, 2019 and 2018, $0.8 million and $1.0 million , respectively, related to contract liabilities were transferred to revenue. Contract assets and liabilities are included in Prepaid and other current assets and Other non-current liabilities, respectively, with the current portion of contract liabilities included in Accrued and other current liabilities, on our unaudited condensed consolidated balance sheets. The following table includes estimated revenue associated with contractual commitments in place related to future performance obligations as of the end of the reporting period, which are expected to be recognized in revenue in the specified periods (in thousands): Revenue from Contracts with Customers Revenue from Leases Total Remainder of 2019 $ 197,741 $ 114,522 $ 312,263 2020 240,599 233,800 474,399 2021 152,116 206,213 358,329 2022 73,399 141,156 214,555 2023 67,108 27,153 94,261 Thereafter 304,739 24,283 329,022 Total $ 1,035,702 $ 747,127 $ 1,782,829 Our contractually committed revenue disclosure, for purposes of the tabular presentation above, excludes estimates of variable rate escalation clauses in our contracts with customers and is generally limited to our contracts with fixed pricing and minimum volume components. Our contractually committed revenue disclosure generally excludes remaining performance obligations on contracts with index-based pricing or variable volume attributes. Lessor We account for certain customer contracts for tolling, storage, and pipeline transportation services as leases in which we are the lessor. Accordingly, such revenues are presented separately in the revenue disaggregation tables in Note 17 - Business Segments. As of June 30, 2019 , assets recorded under revenue operating leases were $241.2 million and accumulated depreciation associated with operating leases was $31.7 million . Depreciation expense was $0.9 million for both of the three months ended June 30, 2019 and 2018 and $1.8 million for both of the six months ended June 30, 2019 and 2018 . These assets primarily consist of our pipelines and terminals, docks and processing facilities. We determined the contracts referenced above contain leases because their commercial provisions convey to the customers the right to effectively control the use of the underlying identified property and equipment assets through the right to obtain substantially all of the economic benefit from the use of the assets and the right to direct the use of these assets, despite our continued operatorship of the assets. Our lessor lease population is classified as revenue operating leases and does not currently have any material sales-type or financing leases. None of these customers are related parties. We have lease contracts with lease and non-lease components, which we account for separately. Our lessor leases do not have variable minimum lease payments; however, the lease payments under these contracts are subject to additional revenues, correlated only to excess product volumes processed, stored, or transported. Certain of our leases include one or more customer options to renew the lease term beyond the initial term of the agreement. Some of our lease terms also include the option for our customers to extend or terminate the lease. Following the end of the lease term, control of the use of these assets reverts to us, and considering our continued ownership of the assets, as well as the assets’ remaining useful lives, we have the ability to seek further commercial opportunities to derive revenue from these assets.

ACQUISITIONS, INVESTMENTS AND D

ACQUISITIONS, INVESTMENTS AND DISPOSITIONS	6 Months Ended
	Jun. 30, 2019
Business Combinations [Abstract]
ACQUISITIONS, INVESTMENTS AND DISPOSITIONS	3. ACQUISITIONS, INVESTMENTS AND DISPOSITIONS 2019 Transaction VTTI Divestiture In January 2019, we completed the sale of our 50% equity interest in VTTI B.V. (“VTTI”) for approximately $975.0 million , excluding transaction costs of approximately $4.0 million incurred in 2019. 2018 Transactions Domestic Asset Divestiture On December 17, 2018, we sold certain domestic pipeline and terminal assets, which included (i) our jet fuel pipeline from Port Everglades, Florida to Ft. Lauderdale-Hollywood International Airport and Miami International Airport; (ii) our pipelines and terminal facilities serving Reno-Tahoe International Airport, San Diego International Airport, and the Federal Express Corporation terminal at the Memphis International Airport; and (iii) our refined petroleum product terminals in Sacramento, California and Stockton, California. The final payment of $10.0 million was received in June 2019. South Texas Transactions In April 2018, as part of our strategy to serve the volume growth in crude oil and related products from the Permian Basin, we expanded our marine terminal presence in Corpus Christi, Texas, through the following transactions: (i) acquired our business partner’s 20% interest in our Buckeye Texas consolidated subsidiary for $210 million , which was accounted for as an equity transaction, representing the acquisition of a non-controlling interest, and (ii) formed a joint venture with Phillips 66 Partners LP (“Phillips 66 Partners”) and Gray Oak Gateway Holdings (“Marathon”), a subsidiary of Marathon Petroleum Corporation, to develop a new deep-water, open-access marine terminal in Ingleside, Texas at the mouth of Corpus Christi Bay (“STG Terminal”). STG Terminal will be constructed and operated by us. We continue to secure additional minimum volume throughput commitments and storage contracts from customers. The initial scope of this project has now increased from 3.4 million barrels of storage to approximately 7.0 million barrels, based on current contracted throughput and storage volumes, and includes two deep-water vessel docks capable of berthing very large crude carrier tankers. Our construction plan also includes connectivity to multiple pipelines delivering volumes into the Corpus Christi market from the growing Permian Basin production and other sources. STG Terminal is expected to commence and ramp up operations by mid-2020 and is supported by long-term minimum volume throughput commitments and storage contracts from credit-worthy customers, including our joint-venture partners. We own a 50% interest in STG Terminal, and Phillips 66 Partners and Marathon each own a 25% interest. To date, our net investment is $72.5 million , including $31.8 million of net contributions during the six months ended June 30, 2019 . We account for our interest in STG Terminal, which is included in our Global Marine Terminals segment, using the equity method of accounting.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	6 Months Ended
	Jun. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	4. COMMITMENTS AND CONTINGENCIES Claims and Legal Proceedings In the ordinary course of business, we are involved in various claims and legal proceedings, some of which are covered by insurance. We are generally unable to predict the timing or outcome of these claims and proceedings. Based upon our evaluation of existing claims and proceedings and the probability of losses resulting from such contingencies, we have accrued certain amounts relating to such claims and proceedings, none of which are considered material. Unitholder Litigation On June 13, 2019, a purported unitholder of Buckeye filed a complaint in a putative class action in the United States District Court for the Southern District of Texas, Houston Division, captioned Harry Curtis, individually and on behalf of all others similarly situated, v. Buckeye Partners, L.P., et al., Case No. 4:19-cv-2147 (the “Curtis Action”). On June 18, 2019, a purported unitholder of Buckeye filed a complaint in a putative class action in the United States District Court for the District of Delaware, captioned Michael Kent, individually and on behalf of all others similarly situated, v. Buckeye Partners, L.P., et al., Case No. 1:19-cv-01128 (the “Kent Action”). On June 19, 2019, a purported unitholder of Buckeye filed a complaint in the United States District Court for the Southern District of New York, captioned John Greer v. Buckeye Partners, L.P., et al., Case No. 1:19-cv-05741 (the “Greer Action”). On June 20, 2019, a purported unitholder of Buckeye filed a complaint in the United States District Court for the Southern District of New York, captioned Anthony Luers v. Buckeye Partners, L.P., et al., Case No. 1:19-cv-05767 (the “Luers Action”). On June 26, 2019, a purported unitholder of Buckeye filed a complaint in the United States District Court for the District of Delaware, captioned Michael Weston, individually and on behalf of all others similarly situated, v. Buckeye Partners, L.P., et al., Case No. 1:19-cv-01208 (the “Weston Action”). On June 26, 2019, a purported unitholder of Buckeye filed a complaint in the United States District Court for the Southern District of New York, captioned Heather McManus, individually and on behalf of all others similarly situated, v. Buckeye Partners, L.P., et al., Case No. 1:19-cv-06000 (the “McManus Action”). On June 28, 2019, a purported unitholder of Buckeye filed a complaint in the United States District Court for the Southern District of New York, captioned John Ingalls, individually and on behalf of all others similarly situated, v. Buckeye Partners, L.P., et al., Case No. 1:19-cv-06098 (the “Ingalls Action”). On June 28, 2019, a purported unitholder of Buckeye filed a complaint in the United States District Court for the District of Delaware, captioned Michael Riss, on behalf of himself and all others similarly situated, v. Buckeye Partners, L.P., et al., Case No. 1:19-cv-01241 (the “Riss Action” and, together with the Curtis Action, the Kent Action, the Greer Action, the Luers Action, the Weston Action, the McManus Action and the Ingalls Action, the “Federal Merger Litigation”). On June 28, 2019, Buckeye also received a joint demand letter from the plaintiffs of each of the Curtis Action, the Kent Action and the Greer Action reiterating the claims contained in each of those actions. On July 18, 2019, the Greer Action, the Luers Action, the McManus Action and the Ingalls Action were transferred to the United States District Court for Southern District of Texas, Houston. These cases are now docketed as Case No. 4:19-cv-02648, 4:19-cv-02647, 4:19-cv-02644 and 4:19-cv-02645, respectively. The Curtis Action alleges, among other things, that in pursuing the Merger, the Board breached its express and implied contractual duties pursuant to Buckeye’s limited partnership agreement and its fiduciary duties to Buckeye’s unitholders in agreeing to enter into the Merger Agreement by means of an allegedly unfair process and for an allegedly unfair price. The Curtis Action, the Kent Action, the Greer Action, the Luers Action, the Weston Action and the McManus Action each further alleges that (i) Buckeye’s preliminary proxy statement, filed with the SEC on June 7, 2019 (the “Preliminary Proxy Statement”), omits material information with respect to the Merger, rendering it false and misleading and, as a result, that Buckeye and the members of the Board violated Section 14(a) of the Exchange Act, and Rule 14a-9 promulgated thereunder, and (ii) the members of the Board, as alleged control persons of Buckeye, violated Section 20(a) of the Exchange Act in connection with the filing of the allegedly materially deficient Preliminary Proxy Statement. The Ingalls Action and the Riss Action each alleges that (i) Buckeye’s definitive proxy statement, filed with the SEC on June 25, 2019 (the “Proxy Statement”), omits material information with respect to the Merger, rendering it false and misleading and, as a result, that Buckeye and the members of the Board violated Section 14(a) of the Exchange Act, and Rule 14a-9 promulgated thereunder, and (ii) the members of the Board, as alleged control persons of Buckeye, violated Section 20(a) of the Exchange Act in connection with the filing of the allegedly materially deficient Proxy Statement. The Curtis Action seeks, among other things, to enjoin the Merger, the disclosure of all material information concerning the Merger, an order rescinding the consummation of the Merger or an award of rescissory damages (in the event the Merger is consummated), an award of damages and an award of attorneys’ and experts’ fees and expenses. The Kent Action and the Greer Action each seeks, among other things, to enjoin the Merger, an order rescinding the consummation of the Merger or an award of rescissory damages (in the event the Merger is consummated), an order directing that the Board disseminate a proxy statement that does not contain any untrue statements of material fact and that states all material facts required or necessary to make the statements contained therein not misleading, a declaration that the defendants violated Sections 14(a) and/or 20(a) of the Exchange Act, as well as Rule 14a-9 promulgated thereunder, and an award of attorneys’ and experts’ fees and expenses. The Luers Action and the Ingalls Action each seeks, among other things, to enjoin the Merger until disclosure of the allegedly omitted material information identified in the Luers Action and the Ingalls Action, respectively, is provided, an order rescinding the Merger Agreement or any of the terms thereof or an award of rescissory damages (in the event the Merger is consummated), an award of damages and an award of attorneys’ and experts’ fees and expenses. The Weston Action seeks, among other things, to enjoin the unitholder vote on the Merger or the consummation of the Merger until disclosure of the allegedly omitted material information identified in the Weston Action is provided, an order directing defendants to account for all damages sustained, an award of damages and an award of attorneys’ and experts’ fees and expenses. The McManus Action seeks, among other things, to enjoin the consummation of the Merger, an order directing that the Board disseminate an amendment to the Preliminary Proxy Statement that does not contain any untrue statements of material fact and that states all material facts required or necessary to make the statements contained therein not misleading, an order directing defendants to account for all damages sustained and an award of attorneys’ and experts’ fees and expenses. The Riss Action seeks, among other things, to enjoin the Merger until disclosure of the allegedly omitted material information identified in the Riss Action is provided, an order rescinding the Merger Agreement or any of the terms thereof or an award of rescissory damages (in the event the Merger is consummated), a declaration that the defendants violated Sections 14(a) and/or 20(a) of the Exchange Act, as well as Rule 14a-9 promulgated thereunder, and an award of attorneys’ and experts’ fees and expenses. Buckeye believes that each of the Federal Merger Litigation is without merit and no supplemental disclosure is required under applicable law. However, in order to avoid the risk of the Federal Merger Litigation delaying or adversely affecting the Merger and to minimize the costs, risks and uncertainties inherent in litigation, and without admitting any liability or wrongdoing, on July 22, 2019, Buckeye filed with the SEC a Current Report on Form 8-K and a Schedule 14A supplementing certain of the allegedly misleading proxy statement disclosures identified in the Federal Merger Litigation. Each plaintiff agreed that the disclosure contained in the Current Report on Form 8-K and Schedule 14A mooted his or her disclosure claims. It is possible that additional, similar complaints may be filed or the complaints described above may be amended. If this occurs, Buckeye does not intend to announce the filing of each additional, similar complaint or any amended complaint. On June 14, 2019, Buckeye also received a demand letter from Walter E. Ryan Jr. (“Mr. Ryan”), a purported unitholder of Buckeye, requesting access to certain books and records of Buckeye to investigate possible mismanagement and/or breaches of fiduciary duty by the Board in connection with the Merger (the “Ryan Demand Letter”). On June 21, 2019, Buckeye responded to the Ryan Demand Letter denying the requests and allegations contained therein. On July 2, 2019, Buckeye received a revised demand letter from Mr. Ryan, which reiterated the demands contained in the Ryan Demand Letter (the “Revised Ryan Demand Letter”). On July 10, 2019, Buckeye responded to the Revised Ryan Demand Letter again denying the requests and allegations contained therein. Environmental Contingencies At June 30, 2019 and December 31, 2018 , we had $35.5 million and $39.0 million , respectively, of environmental remediation liabilities. Costs ultimately incurred may be in excess of our estimates, which may have a material impact on our financial condition, results of operations or cash flows. At June 30, 2019 and December 31, 2018 , we had $3.9 million and $4.2 million , respectively, of receivables related to these environmental remediation liabilities covered by insurance or third-party claims.

INVENTORIES

INVENTORIES	6 Months Ended
	Jun. 30, 2019
Inventory Disclosure [Abstract]
INVENTORIES	5. INVENTORIES Our inventory amounts were as follows at the dates indicated (in thousands): June 30, December 31, Liquid petroleum products (1) $ 105,724 $ 186,683 Materials and supplies 25,013 24,201 Total inventories $ 130,737 $ 210,884 (1) Ending inventory was 54.9 million and 114.7 million gallons of liquid petroleum products at June 30, 2019 and December 31, 2018 , respectively. At June 30, 2019 and December 31, 2018 , approximately 96% and 94% of our liquid petroleum products inventory volumes were designated in a fair value hedge relationship, respectively. Because we generally designate inventory as a hedged item upon purchase, hedged inventory is valued at current market prices with the change in value of the inventory reflected in our unaudited condensed consolidated statements of operations.

OTHER NON-CURRENT LIABILITIES

OTHER NON-CURRENT LIABILITIES	6 Months Ended
	Jun. 30, 2019
Other Liabilities, Noncurrent [Abstract]
OTHER NON-CURRENT LIABILITIES	OTHER NON-CURRENT LIABILITIES Other non-current liabilities consist of the following at the dates indicated (in thousands): June 30, December 31, Long-term lease liabilities (see Note 9) $ 120,545 $ — Accrued employee benefit liabilities 27,682 28,246 Accrued environmental remediation liabilities 24,820 27,358 Deferred consideration 11,805 20,232 Asset retirement obligations 4,337 4,349 Other 8,407 4,715 Total other non-current liabilities $ 197,596 $ 84,900

PREPAID AND OTHER CURRENT ASSET

PREPAID AND OTHER CURRENT ASSETS	6 Months Ended
	Jun. 30, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
PREPAID AND OTHER CURRENT ASSETS	7. PREPAID AND OTHER CURRENT ASSETS Prepaid and other current assets consist of the following at the dates indicated (in thousands): June 30, December 31, Prepaid insurance $ 17,863 $ 6,622 Margin deposits 5,093 8,684 Contract assets 17,232 16,989 Prepaid taxes 8,916 5,311 Other 16,061 21,288 Total prepaid and other current assets $ 65,165 $ 58,894

EQUITY INVESTMENTS

EQUITY INVESTMENTS	6 Months Ended
	Jun. 30, 2019
Equity Method Investments and Joint Ventures [Abstract]
EQUITY INVESTMENTS	8. EQUITY INVESTMENTS The following table presents earnings (losses) from equity investments for the periods indicated (in thousands): Three Months Ended Six Months Ended Segment 2019 2018 2019 2018 VTTI B.V. (1) Global Marine Terminals $ — $ 4,882 $ — $ 9,272 West Shore Pipe Line Company Domestic Pipelines & Terminals 2,469 2,466 5,085 4,792 Muskegon Pipeline LLC Domestic Pipelines & Terminals (23 ) 431 461 756 Transport4, LLC Domestic Pipelines & Terminals 222 221 489 450 South Portland Terminal LLC Domestic Pipelines & Terminals 486 441 764 660 South Texas Gateway Terminal LLC (2) Global Marine Terminals (283 ) (176 ) (583 ) (176 ) Total earnings from equity investments $ 2,871 $ 8,265 $ 6,216 $ 15,754 (1) In January 2019, we completed the sale of our 50% equity interest in VTTI. See Note 3 - Acquisitions, Investments and Dispositions for further discussion. (2) In April 2018, we formed the STG Terminal joint venture. See Note 3 - Acquisitions, Investments and Disposition for further discussion. Summarized combined income statement data for our equity method investments is as follows for the periods indicated (amounts represent 100% of investee income statement data in thousands): Three Months Ended Six Months Ended 2019 2018 2019 2018 INCOME STATEMENT DATA: Revenue $ 24,467 $ 145,622 $ 47,756 $ 290,690 Operating income 13,361 40,027 26,473 89,809 Net income 10,313 26,382 20,443 51,132 Net income attributable to investee 10,313 25,170 20,443 48,129

LEASES

LEASES	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
LEASES	9. LEASES Lessee We have entered into certain agreements to use property, plant and equipment, including office space, equipment and land, which qualify as leases. ROU lease assets and liabilities associated with leases with an initial term of twelve months or less are not recorded on the balance sheet. Operating leases are included in Other non-current assets and Other non-current liabilities on our unaudited condensed consolidated balance sheet as of June 30, 2019 , with the current portion of such liabilities being included in Accrued and other current liabilities. Operating lease ROU assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the expected term of the lease at the commencement date including, as applicable, renewal periods when we have the option to extend and it is reasonably certain we will do so. As most of our leases do not provide an explicit interest rate, we use an applicable implicit incremental borrowing rate, based on the information available at the commencement date, in determining the present value of future payments. We give consideration to our borrowing rates based on our credit rating as well as secured and unsecured debt instruments with similar characteristics when calculating our incremental borrowing rates. We do not currently have any material financing leases. The operating lease ROU asset also includes lease payments made as of the commencement date and excludes lease incentives and initial direct costs. Our lease terms may include options to extend or terminate the lease when it is reasonably certain that we will exercise that option. At this time, our lease population does not have either variable lease payments or residual value guarantees that would materially impact the ROU asset and liability valuation. Additionally, we do not have any sublease arrangements or lease transactions with related parties. We have lessee agreements with lease and non-lease components, which are generally accounted for separately. For certain leases, we account for the lease and non-lease components as a single lease component based on the election of the practical expedient to not separate lease components from non-lease components related to the following classes of assets: (i) buildings and leasehold improvements; (ii) jetties, subsea pipeline and docks; (iii) pipelines and terminals; and (iv) vehicle, equipment and office furnishings. ASC 842 permits the lessee to account for its leases at a portfolio level provided that the resulting accounting would not differ materially from accounting at the individual lease level. We have applied the portfolio approach to certain equipment-type and vehicle leases in accounting for the operating lease ROU assets and liabilities. We also elected the package of practical expedients available upon adoption, including: (i) not to reassess whether any expired or existing contracts contain leases and lease classification for such leases, as well as initial direct costs for any existing leases; (ii) not to apply the provisions of ASU 2016-02 to land easements that existed or expired before adoption and that were not previously accounted for as leases under the previous lease standard in ASC Topic 840, Leases ; (iii) to use hindsight in determining the lease term and in assessing impairment of our ROU lease assets; and (iv) not to apply provisions of ASU 2016-02 to short-term leases. The operating lease costs for the three months ended June 30, 2019 and 2018 were $8.0 million and $8.1 million , respectively, including $1.2 million and $2.3 million of short-term operating lease costs for the respective periods. The operating lease costs for the six months ended June 30, 2019 and 2018 were $16.4 million and $16.2 million , respectively, including $3.5 million and $5.2 million of short-term operating lease costs for the respective periods. Supplemental balance sheet information related to leases is as follows (in thousands, except lease term and discount rate): Lease Activity Balance Sheet Location June 30, Operating lease right-of-use assets Other non-current assets $ 145,402 Current portion of operating lease liabilities Accrued and other current liabilities 30,440 Operating lease liabilities Other non-current liabilities 120,545 Total operating lease liabilities $ 150,985 Weighted average remaining lease term 16.2 years Weighted average discount rate 5.72 % The following table presents minimum lease payment obligations under noncancelable leases for our operating leases with terms in excess of one year as of June 30, 2019 (in thousands): Total Remainder of 2019 $ 18,500 2020 23,035 2021 19,314 2022 18,549 2023 18,541 Thereafter 140,426 Total 238,365 Less: Effect of discounting to net present value (87,380 ) Total operating lease liabilities $ 150,985 Disclosures Related to Periods Prior to Adoption of ASC 842 The following table presents minimum lease payment obligations under our operating leases with terms in excess of one year for the years ending December 31st (in thousands): Total 2019 $ 29,050 2020 26,255 2021 22,215 2022 21,378 2023 21,126 Thereafter 138,466 Total $ 258,490

OTHER NON-CURRENT ASSETS

OTHER NON-CURRENT ASSETS	6 Months Ended
	Jun. 30, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
OTHER NON-CURRENT ASSETS	10. OTHER NON-CURRENT ASSETS Other non-current assets consist of the following at the dates indicated (in thousands): June 30, December 31, Right of use lease assets (see Note 9) $ 145,402 $ — Debt issuance costs 1,813 2,216 Insurance receivables related to environmental remediation reserves 1,632 2,057 Derivative assets 129 1,003 Other 22,975 35,862 Total other non-current assets $ 171,951 $ 41,138

LONG-TERM DEBT

LONG-TERM DEBT	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
LONG-TERM DEBT	11. LONG-TERM DEBT Extinguishment of Debt In January 2018, we repaid in full the $300.0 million principal amount outstanding under our 6.050% notes. In January 2019, we repaid in full the $250.0 million variable-rate Term Loan due September 30, 2019 (the “Term Loan”), using proceeds from the VTTI sale transaction. In February 2019, we repaid in full the $275.0 million principal amount outstanding under our 5.500% notes, using proceeds from the VTTI sale transaction as well as borrowings under our Credit Facility. As a result of the 2019 retirements, we incurred a $4.0 million loss on early extinguishment of debt, consisting of a $3.6 million make-whole payment related to the 5.500% notes and unamortized financing costs of $0.4 million included in Other expense, net, on our unaudited condensed consolidated statements of operations. Notes Offerings In January 2018, we issued $400.0 million of junior subordinated notes (“Junior Notes”) maturing on January 22, 2078, which are redeemable at Buckeye’s option, in whole or in part, on or after January 22, 2023. The Junior Notes bear interest at a fixed rate of 6.375% per year up to, but not including, January 22, 2023. From January 22, 2023, the Junior Notes will bear interest at a floating rate based on the Three-Month London Interbank Offered Rate (“LIBOR”) plus 4.02% , reset quarterly. Total proceeds from this offering, after underwriting fees, expenses, and debt issuance costs, were $394.9 million . We used the net proceeds from this offering to reduce indebtedness outstanding under our $1.5 billion revolving Credit Facility with SunTrust Bank (the “Credit Facility”) and for general partnership purposes. Credit Facility At June 30, 2019 , we had a $170.3 million outstanding balance under the Credit Facility, $109.8 million of which is classified as current. The weighted average interest rate for borrowings under the Credit Facility was 4.0% during the six months ended June 30, 2019 .

DERIVATIVE INSTRUMENTS AND HEDG

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES	6 Months Ended
	Jun. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES	12. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES We are exposed to financial market risks, including changes in interest rates and commodity prices, in the course of our normal business operations. We use derivative instruments to manage such risks. Interest Rate Derivatives From time to time, we utilize forward-starting interest rate swaps to hedge the variability of the forecasted interest payments on anticipated debt issuances that may result from changes in the benchmark interest rate until the expected debt is issued. When entering into interest rate swap transactions, we become exposed to both credit risk and market risk. We are subject to credit risk when the change in fair value of the swap instrument is positive and the counterparty may fail to perform under the terms of the contract. We are subject to market risk with respect to changes in the underlying benchmark interest rate that impacts the fair value of the swaps. We manage our credit risk by entering into swap transactions only with major financial institutions with investment-grade credit ratings. We manage our market risk by aligning the swap instrument with the existing underlying debt obligation or a specified expected debt issuance, generally associated with the maturity of an existing debt obligation. We designate the swap agreements as cash flow hedges at inception and expect the changes in values to be highly correlated with the changes in value of the anticipated interest payments associated with the forecasted borrowings. Commodity Derivatives Our Merchant Services segment primarily uses exchange-traded refined petroleum product futures contracts to manage the risk of market price volatility on its refined petroleum product inventories and its physical derivative contracts, which we designated as fair value hedges, with changes in fair value of both the futures contracts and physical inventory reflected in earnings. Our Merchant Services segment also uses exchange-traded refined petroleum contracts to hedge expected future transactions related to certain gasoline inventory, which are designated as cash flow hedges, with the effective portion of the hedge reported in other comprehensive income (“OCI”) and reclassified into earnings when the expected future transaction affects earnings. Any gains or losses incurred on the derivative instruments that are not effective in offsetting changes in fair value or cash flows of the hedged item are recognized immediately in earnings. Additionally, our Merchant Services segment enters into exchange-traded refined petroleum product futures contracts on behalf of our Domestic Pipelines & Terminals segment to manage the risk of market price volatility on the gasoline-to-butane pricing spreads associated with our butane blending activities. These futures contracts are not designated in a hedge relationship for accounting purposes. Physical forward contracts and futures contracts that have not been designated in a hedge relationship are marked-to-market through earnings. The following table summarizes the notional volumes of the net long (short) positions of our commodity derivative instruments outstanding at June 30, 2019 (amounts in thousands of gallons): Volume Derivative Purpose Current Long-Term Derivatives NOT designated as hedging instruments: Physical fixed-price derivative contracts (29,577 ) (1,201 ) Physical index derivative contracts (2,476 ) — Futures contracts for refined petroleum products 25,114 1,638 Hedge Type Derivatives designated as hedging instruments: Cash flow hedge futures contracts (294 ) — Cash Flow Hedge Futures contracts for refined petroleum products (52,920 ) — Fair Value Hedge Our futures contracts designated as fair value hedges relate to our inventory portfolio and extend to the first quarter of 2020. Our futures contracts related to forecasted purchases and sales of refined petroleum products, not designated in a hedging relationship, extend to the first quarter of 2020 . In accordance with the Chicago Mercantile Exchange rulebook, variation margin transfers are considered settlement payments, thereby reducing the corresponding derivative asset and liability balances for our exchange-settled derivative contracts. These settlement payments result in realized gains and losses on derivatives. The following table sets forth the fair value of each classification of derivative instruments and the derivative instruments’ location on our unaudited condensed consolidated balance sheets at the dates indicated (in thousands): June 30, 2019 Derivative Carrying Value (1) Netting Balance Sheet Adjustment (2) Net Total Physical fixed-price derivative contracts $ 3,201 $ (585 ) $ 2,616 Physical index derivative contracts 140 — 140 Total current derivative assets 3,341 (585 ) 2,756 Physical fixed-price derivative contracts 129 — 129 Total non-current derivative assets 129 — 129 Physical fixed-price derivative contracts (1,369 ) 585 (784 ) Physical index derivative contracts (40 ) — (40 ) Total current derivative liabilities (1,409 ) 585 (824 ) Physical fixed-price derivative contracts (11 ) — (11 ) Total non-current derivative liabilities (11 ) — (11 ) Net derivative assets $ 2,050 $ — $ 2,050 (1) Other than our exchange-settled derivative contracts, as of June 30, 2019 , none of our derivative instruments were designated as hedging instruments. (2) Amounts represent the netting of physical fixed price and index contracts’ assets and liabilities when a legal right of offset exists. December 31, 2018 Derivative Carrying Value (1) Netting Balance Sheet Adjustment (2) Net Total Physical fixed-price derivative contracts $ 17,934 $ (84 ) $ 17,850 Physical index derivative contracts 286 (117 ) 169 Total current derivative assets 18,220 (201 ) 18,019 Physical fixed-price derivative contracts 1,003 — 1,003 Total non-current derivative assets 1,003 — 1,003 Physical fixed-price derivative contracts (1,386 ) 84 (1,302 ) Physical index derivative contracts (135 ) 117 (18 ) Total current derivative liabilities (1,521 ) 201 (1,320 ) Physical fixed-price derivative contracts (3 ) — (3 ) Total non-current derivative liabilities (3 ) — (3 ) Net derivative assets $ 17,699 $ — $ 17,699 (1) Other than our exchange-settled derivative contracts, as of December 31, 2018, none of our derivative instruments were designated as hedging instruments. (2) Amounts represent the netting of physical fixed price and index contracts’ assets and liabilities when a legal right of offset exists. At June 30, 2019 , open refined petroleum product derivative contracts (represented by the physical fixed-price contracts and physical index contracts noted above) were not classified as designated derivative instruments and varied in duration in the overall portfolio, but did not extend beyond January 2020 . In addition, at June 30, 2019 , we had refined petroleum product inventories that we intend to use to satisfy a portion of the physical derivative contracts. The gains and losses on our derivative instruments recognized in income were as follows for the periods indicated (in thousands): Three Months Ended Six Months Ended Location 2019 2018 2019 2018 Derivatives NOT designated as hedging instruments: Physical fixed price derivative contracts Product sales $ 2,892 $ (1,659 ) $ (7,875 ) $ (305 ) Physical index derivative contracts Product sales 65 (17 ) 108 160 Physical fixed price derivative contracts Cost of product sales (2,370 ) 552 (1,631 ) (53 ) Physical index derivative contracts Cost of product sales (161 ) 424 (216 ) 426 Futures contracts for refined products Cost of product sales (935 ) (2,265 ) 1,848 (4,563 ) Three Months Ended Six Months Ended Location 2019 2018 2019 2018 Derivatives designated as fair value hedging instruments: Futures contracts for refined products Cost of product sales $ 1,299 $ (10,013 ) $ (27,624 ) $ (4,306 ) Physical inventory - hedged items Cost of product sales (1,364 ) 9,530 28,565 3,540 Three Months Ended Six Months Ended Location 2019 2018 2019 2018 Ineffectiveness excluding the time value component on fair value hedging instruments: Fair value hedge ineffectiveness (excluding time value) Cost of product sales $ (1,345 ) (114 ) $ (2,709 ) $ (196 ) Time value excluded from hedge assessment Cost of product sales 1,280 (369 ) 3,650 (570 ) Net (loss) gain for ineffectiveness in income $ (65 ) $ (483 ) $ 941 $ (766 ) The change in value recognized in OCI and the losses reclassified from accumulated other comprehensive income (“AOCI”) to income, attributable to our derivative instruments designated as cash flow hedges, were as follows for the periods indicated (in thousands): Gain (Loss) Recognized in OCI on Derivatives for the Three Months Ended Six Months Ended 2019 2018 2019 2018 Derivatives designated as cash flow hedging instruments: Interest rate contracts $ — $ 5,656 $ — $ 20,417 Commodity derivatives (823 ) 3,280 (722 ) 2,657 Total $ (823 ) $ 8,936 $ (722 ) $ 23,074 Loss Reclassified from AOCI to Income (Effective Portion) for the Three Months Ended Six Months Ended Location 2019 2018 2019 2018 Derivatives designated as cash flow hedging instruments: Interest rate derivative contracts Interest and debt expense $ (2,296 ) $ (2,295 ) $ (4,592 ) $ (4,632 ) Total $ (2,296 ) $ (2,295 ) $ (4,592 ) $ (4,632 ) Over the next twelve months, we expect to reclassify $9.2 million of net losses attributable to interest rate derivatives from AOCI to earnings as an increase to interest and debt expense. These net losses consist of $11.2 million of amortization of hedge losses on settled forward-starting interest rate swaps, partially offset by $2.0 million of amortization of hedge gains on settled forward-starting interest rate swaps. Additionally, the unrealized gains and losses for refined petroleum products designated as cash flow hedges at June 30, 2019 , of $0.7 million , are estimated to be realized and reclassified from AOCI to product sales over the next twelve months. The ineffective portion of the change in fair value of cash flow hedges was not material for the three and six months ended June 30, 2019 and 2018 .

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	6 Months Ended
	Jun. 30, 2019
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	13. FAIR VALUE MEASUREMENTS We categorize our financial assets and liabilities using the three-tier fair value hierarchy as follows: Recurring The following table sets forth financial assets and liabilities measured at fair value on a recurring basis, as of the measurement dates indicated, and the basis for that measurement, by level within the fair value hierarchy (in thousands): June 30, 2019 December 31, 2018 Level 1 Level 2 Level 1 Level 2 Financial assets: Physical fixed-price derivative contracts $ — $ 3,330 $ — $ 18,937 Physical index derivative contracts — 140 — 286 Financial liabilities: Physical fixed-price derivative contracts — (1,380 ) — (1,389 ) Physical index derivative contracts — (40 ) — (135 ) Fair value $ — $ 2,050 $ — $ 17,699 The values of the Level 1 derivative assets and liabilities were based on quoted market prices obtained from the New York Mercantile Exchange. The values for exchange-settled commodity derivatives are settled daily via variation margin payments and as a result are with no net fair value at the balance sheet date for financial reporting purposes; however, the derivatives remain outstanding and subject to future commodity price fluctuations until they are settled in accordance with their contractual terms. The values of the Level 2 commodity derivative contracts were calculated using market approaches based on observable market data inputs, including published commodity pricing data, which is verified against other available market data, and market interest rate and volatility data. Level 2 physical fixed-price derivative assets are net of credit value adjustments (“CVAs”) determined using an expected cash flow model, which incorporates assumptions about the credit risk of the derivative contracts based on the historical and expected payment history of each customer, the amount of product contracted for under the agreement and the customer’s historical and expected purchase performance under each contract. The CVAs were nominal as of June 30, 2019 and December 31, 2018 . As of June 30, 2019 and December 31, 2018 , the Merchant Services segment did not hold any net liability derivative positions containing credit contingent features. Financial instruments included in current assets and current liabilities are reported in the unaudited condensed consolidated balance sheets at amounts which approximate fair value due to the relatively short period to maturity of these financial instruments. The fair values of our fixed-rate debt were estimated by observing market trading prices and by comparing the historic market prices of our publicly issued debt with the market prices of the publicly issued debt of other MLPs with similar credit ratings and terms. The fair value of our variable-rate debt approximates the carrying amount since the associated interest rates are market-based. The carrying value and fair value of our debt, using Level 2 input values, were as follows at the dates indicated (in thousands): June 30, 2019 December 31, 2018 Carrying Amount Fair Value Carrying Amount Fair Value Fixed-rate debt $ 3,273,334 $ 3,046,533 $ 3,546,396 $ 3,364,549 Variable-rate debt 566,647 570,275 1,168,046 1,172,328 Total debt $ 3,839,981 $ 3,616,808 $ 4,714,442 $ 4,536,877 In addition, our pension plan assets are measured at fair value on a recurring basis, based on Level 1 and Level 3 inputs. We recognize transfers between levels within the fair value hierarchy as of the beginning of the reporting period. We did not have any transfers between Level 1 and Level 2 during the six months ended June 30, 2019 and 2018. Non-Recurring Certain nonfinancial assets and liabilities are measured at fair value on a nonrecurring basis and are subject to fair value adjustments in certain circumstances, such as when there is evidence of impairment. For the three and six months ended June 30, 2019

UNIT-BASED COMPENSATION PLANS

UNIT-BASED COMPENSATION PLANS	6 Months Ended
	Jun. 30, 2019
Share-based Payment Arrangement [Abstract]
UNIT-BASED COMPENSATION PLANS	14. UNIT-BASED COMPENSATION PLANS We award unit-based compensation to employees and directors primarily under the 2013 Long Term Incentive Plan of Buckeye Partners, L.P. (the “LTIP”), which was approved by our unitholders in June 2013 and subsequently amended and restated in June 2017. The LTIP replaced the 2009 Long-Term Incentive Plan (the “2009 Plan”), which was merged with and into the LTIP, and no further grants have since been made under the 2009 Plan. We recognized compensation expense related to awards under the LTIP of $5.8 million and $8.0 million for the three months ended June 30, 2019 and 2018 , respectively. For the six months ended June 30, 2019 and 2018, we recognized compensation expense of $15.7 million and $16.8 million , respectively. LTIP As of June 30, 2019 , there were 1,536,149 LP Units available for issuance under the LTIP. Deferral Plan under the LTIP We also maintain the Buckeye Partners, L.P. Unit Deferral and Incentive Plan, as amended and restated effective December 13, 2016 (the “Deferral Plan”), pursuant to which we issue phantom and matching units under the LTIP to certain employees in lieu of cash compensation at the election of the employee. During the six months ended June 30, 2019 , 158,970 phantom units (including matching units) were granted under this plan. These grants are included as granted in the LTIP activity table below. Awards under the LTIP During the six months ended June 30, 2019 , the Compensation Committee of the Board granted 528,750 phantom units to employees (including the 158,970 phantom units granted pursuant to the Deferral Plan, as discussed above), 32,247 phantom units to independent directors of Buckeye GP and 345,574 performance units to employees. The following table sets forth the LTIP activity for the periods indicated (in thousands, except per unit amounts): Number of LP Units Weighted Average Grant Date Fair Value per LP Unit (1) Unvested at January 1, 2019 1,645 $ 55.52 Granted (2) 907 30.97 Vested (241 ) 52.23 Forfeited (253 ) 50.46 Unvested at June 30, 2019 2,058 $ 45.71 (1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued. The weighted-average grant date fair value per LP Unit for forfeited and vested awards is determined before an allowance for forfeitures. (2) Includes both phantom and performance awards. Performance awards are granted at a target amount but, depending on our performance during the vesting period with respect to certain pre-established goals, the number of LP Units issued upon vesting of such performance awards can be greater or less than the target amount. At June 30, 2019 , we expect to recognize $38.1 million of compensation expense related to the unvested LTIP over a weighted average remaining period of 1.8 years.

PARTNERS' CAPITAL AND DISTRIBUT

PARTNERS' CAPITAL AND DISTRIBUTIONS	6 Months Ended
	Jun. 30, 2019
Equity [Abstract]
PARTNERS' CAPITAL AND DISTRIBUTIONS	15. PARTNERS’ CAPITAL AND DISTRIBUTIONS Our LP Units represent limited partner interests, which give the holders thereof the right to participate in distributions and to exercise the other rights and privileges available to them under our partnership agreement. The partnership agreement provides that, without prior approval of our limited partners holding an aggregate of at least two-thirds of the outstanding LP Units, we cannot issue any limited partnership interests of a class or series having preferences or other special or senior rights over the LP Units. Equity Offering In March 2018, we issued approximately 6.2 million Class C Units in a private placement for aggregate gross proceeds of $265.0 million . The net proceeds were $262.0 million , after deducting issuance costs of approximately $3.0 million . We used the net proceeds from this offering to reduce the indebtedness outstanding under our Credit Facility, to partially fund growth capital expenditures and for general partnership purposes. Class C Units represented a separate class of our limited partnership interests. The Class C Units were substantially similar in all respects to our existing LP units, except that Buckeye had the option to pay distributions on the Class C Units in cash or by issuing additional Class C Units. In November 2018, all 6,714,963 Class C Units converted into LP Units on a one -for-one basis. Summary of Changes in Outstanding Units The following is a summary of changes in Buckeye ’ s outstanding units for the period indicated (in thousands): LP Units Units outstanding at January 1, 2019 153,755 LP units issued pursuant to the LTIP (1) 166 Units outstanding at June 30, 2019 153,921 (1) The number of LP Units issued represents issuance net of tax withholding. Distributions Cash distributions are paid for LP Units and for distribution equivalent rights with respect to certain unit-based compensation awards outstanding as of each respective period. Actual cash distributions on our LP Units totaled $232.5 million ( $1.50 per LP Unit) and $373.5 million ( $2.5250 per LP Unit) during the six months ended June 30, 2019 and 2018 , respectively. On August 1, 2019 , we announced a quarterly distribution of $0.75 per LP Unit that will be paid on August 19, 2019 to unitholders of record on August 12, 2019 . Based on the LP Units and distribution equivalent rights with respect to certain unit-based compensation awards outstanding as of June 30, 2019 , cash expected to be distributed to LP unitholders on August 19, 2019 is estimated to be approximately $116.3 million .

EARNINGS PER UNIT

EARNINGS PER UNIT	6 Months Ended
	Jun. 30, 2019
Earnings Per Share [Abstract]
EARNINGS PER UNIT	16. EARNINGS PER UNIT The following tables set forth the calculation of basic and diluted earnings per unit, attributable to Buckeye’s unitholders, taking into consideration net income allocable to participating securities, as well as the reconciliation of basic weighted average units outstanding to diluted weighted average units outstanding (in thousands, except per unit amounts). Three Months Ended Six Months Ended 2019 2018 2019 2018 Net income attributable to unitholders $ 89,152 $ 90,665 $ 169,044 $ 201,789 Basic: Weighted average units outstanding - basic 153,918 153,258 153,882 151,093 Earnings per unit - basic $ 0.58 $ 0.59 $ 1.10 $ 1.34 Diluted: Weighted average units outstanding - basic 153,918 153,258 153,882 151,093 Effect of dilutive securities 824 731 757 677 Weighted average units outstanding - diluted 154,742 153,989 154,639 151,770 Earnings per unit - diluted $ 0.58 $ 0.59 $ 1.09 $ 1.33

BUSINESS SEGMENTS

BUSINESS SEGMENTS	6 Months Ended
	Jun. 30, 2019
Segment Reporting [Abstract]
BUSINESS SEGMENTS	17. BUSINESS SEGMENTS We operate and report in three business segments: (i) Domestic Pipelines & Terminals; (ii) Global Marine Terminals; and (iii) Merchant Services. All inter-segment transactions have been eliminated in consolidation. Domestic Pipelines & Terminals The Domestic Pipelines & Terminals segment receives liquid petroleum products from refineries, connecting pipelines, vessels, trains, and bulk and marine terminals, transports those products to other locations for a fee, and provides bulk liquid storage and terminal throughput services. The segment also has butane blending capabilities and provides crude oil services, including train loading/unloading, storage and throughput. This segment owns and operates pipeline systems and liquid petroleum products terminals in the continental United States, including three terminals owned by the Merchant Services segment but operated by the Domestic Pipelines & Terminals segment, and two underground propane storage caverns. Additionally, this segment provides turn-key operations and maintenance of third-party pipelines and performs pipeline construction management services typically for cost plus a fixed or variable fee. Global Marine Terminals The Global Marine Terminals segment provides marine accessible bulk storage and blending services, rail and truck rack loading/unloading along with petroleum processing services across our network of marine terminals located primarily in the East Coast and Gulf Coast regions of the United States, as well as in the Caribbean. Our operating locations facilitate global flows of crude and refined petroleum products, offer connectivity between supply areas and market centers, and provide premier storage, marine terminalling, blending, and processing services to a diverse customer base. Merchant Services The Merchant Services segment is a wholesale distributor of refined petroleum products in the continental United States and in the Caribbean. The segment’s products include gasoline, natural gas liquids, ethanol, biodiesel and petroleum distillates such as heating oil, diesel fuel, kerosene and fuel oil. The segment owns three terminals, which are operated by the Domestic Pipelines & Terminals segment. The segment’s customers consist principally of product wholesalers, as well as major commercial users of these refined petroleum products. Financial Information by Segment For the three and six months ended June 30, 2019 and 2018 , no customer contributed 10% or more of consolidated revenue. The following tables provide information about our revenue types by reportable segment for the periods indicated (in thousands). Three Months Ended June 30, 2019 Domestic Pipelines & Terminals Global Marine Terminals Merchant Services Intersegment Eliminations Total Revenue from contracts with customers Pipeline transportation $ 119,798 $ — $ — $ (2,504 ) $ 117,294 Terminalling and storage services 102,360 87,406 — (6,411 ) 183,355 Product sales — 5 344,502 (2,930 ) 341,577 Other services 12,627 435 576 (17 ) 13,621 Total revenue from contracts with customers 234,785 87,846 345,078 (11,862 ) 655,847 Revenue from leases 10,490 46,511 — (142 ) 56,859 Commodity derivative contracts, net (1,694 ) — 80,690 — 78,996 Total revenue $ 243,581 $ 134,357 $ 425,768 $ (12,004 ) $ 791,702 Three Months Ended June 30, 2018 Domestic Pipelines & Terminals Global Marine Terminals Merchant Services Intersegment Eliminations Total Revenue from contracts with customers Pipeline transportation $ 127,959 $ — $ — $ (2,163 ) $ 125,796 Terminalling and storage services 100,981 99,927 — (9,730 ) 191,178 Product sales — 7 455,185 (1,889 ) 453,303 Other services 10,694 320 1,920 (15 ) 12,919 Total revenue from contracts with customers 239,634 100,254 457,105 (13,797 ) 783,196 Revenue from leases 11,065 42,889 — — 53,954 Commodity derivative contracts, net (819 ) — 104,508 — 103,689 Total revenue $ 249,880 $ 143,143 $ 561,613 $ (13,797 ) $ 940,839 Six Months Ended June 30, 2019 Domestic Pipelines & Terminals Global Marine Terminals Merchant Services Intersegment Eliminations Total Revenue from contracts with customers Pipeline transportation $ 242,013 $ — $ — $ (5,175 ) $ 236,838 Terminalling and storage services 208,139 175,768 — (16,907 ) 367,000 Product sales — 262 863,566 (5,682 ) 858,146 Other services 20,188 870 1,056 (32 ) 22,082 Total revenue from contracts with customers 470,340 176,900 864,622 (27,796 ) 1,484,066 Revenue from leases 20,015 91,464 — (294 ) 111,185 Commodity derivative contracts, net (5,238 ) — 230,661 — 225,423 Total revenue $ 485,117 $ 268,364 $ 1,095,283 $ (28,090 ) $ 1,820,674 Six Months Ended June 30, 2018 Domestic Pipelines & Terminals Global Marine Terminals Merchant Services Intersegment Eliminations Total Revenue from contracts with customers Pipeline transportation $ 249,430 $ — $ — $ (5,803 ) $ 243,627 Terminalling and storage services 216,956 201,145 — (18,323 ) 399,778 Product sales — 20 1,098,693 (5,242 ) 1,093,471 Other services 22,783 341 4,820 (1,362 ) 26,582 Total revenue from contracts with customers 489,169 201,506 1,103,513 (30,730 ) 1,763,458 Revenue from leases 19,055 85,722 — — 104,777 Commodity derivative contracts, net (2,909 ) — 256,528 2,090 255,709 Total revenue $ 505,315 $ 287,228 $ 1,360,041 $ (28,640 ) $ 2,123,944 The following table summarizes revenue by major geographic area for the periods indicated (in thousands): Three Months Ended Six Months Ended 2019 2018 2019 2018 Revenue: United States $ 740,538 $ 878,607 $ 1,718,318 $ 2,000,827 International 51,164 62,232 102,356 123,117 Total revenue $ 791,702 $ 940,839 $ 1,820,674 $ 2,123,944 Adjusted EBITDA Adjusted EBITDA is a measure not defined by GAAP. We define Adjusted EBITDA as earnings (losses) before interest expense, income taxes, depreciation and amortization, further adjusted to exclude certain non-cash items, such as non-cash compensation expense; transaction, transition, and integration costs associated with acquisitions and dispositions; certain gains and losses on foreign currency transactions and foreign currency derivative financial instruments, as applicable; and certain other operating expense or income items, reflected in net income, that we do not believe are indicative of our core operating performance results and business outlook, such as hurricane-related costs, gains and losses on property damage recoveries, non-cash impairment charges, and gains and losses on asset sales. The definition of Adjusted EBITDA is also applied to our proportionate share in the Adjusted EBITDA of significant equity method investments, which from January 1, 2017 through September 30, 2018, included VTTI, and is not applied to our less significant equity method investments. The calculation of our proportionate share of the reconciling items used to derive Adjusted EBITDA was based upon our 50% equity interest in VTTI, prior to adjustments related to noncontrolling interests in several of its subsidiaries and partnerships, which were immaterial. Adjusted EBITDA is a non-GAAP financial measure that is used by our senior management, including our Chief Executive Officer, to assess the operating performance of our business and optimize resource allocation. We use Adjusted EBITDA as a primary measure to: (i) evaluate our consolidated operating performance and the operating performance of our business segments; (ii) allocate resources and capital to business segments; (iii) evaluate the viability of proposed projects; and (iv) determine overall rates of return on alternative investment opportunities. We believe that investors benefit from having access to the same financial measures that we use and that these measures are useful to investors because they aid in comparing our operating performance with that of other companies with similar operations. The Adjusted EBITDA data presented by us may not be comparable to similarly titled measures at other companies because these items may be defined differently by other companies. The following table presents a reconciliation of consolidated net income, which is the most comparable financial measure under GAAP, to Adjusted EBITDA, as well as Adjusted EBITDA by segment for the periods indicated (in thousands): Three Months Ended Six Months Ended 2019 2018 2019 2018 Reconciliation of Net (loss) income to Adjusted EBITDA: Net income $ 90,515 $ 93,317 $ 171,775 $ 210,409 Less: Net income attributable to noncontrolling interests (496 ) (1,413 ) (994 ) (6,132 ) Net income attributable to Buckeye Partners, L.P. 90,019 91,904 170,781 204,277 Add: Interest and debt expense 49,574 59,566 101,742 118,671 Income tax expense 297 782 595 1,272 Depreciation and amortization (1) 65,859 66,569 129,743 130,707 Non-cash unit-based compensation expense 5,781 7,976 15,698 16,666 Acquisition, dispositions, and transition expense (2) 5,783 141 9,866 423 Non-cash impairment on disposals of long-lived assets 911 — 3,106 — Proportionate share of Adjusted EBITDA for equity method investment in VTTI (3) — 34,640 — 69,180 Loss on early extinguishment of debt (4) — — 4,020 — Less: Gains on property damage recoveries (5) — (450 ) — (14,535 ) Hurricane-related costs, net of recoveries (6) (3,881 ) (1,393 ) (4,810 ) (812 ) Earnings from the equity method investment in VTTI (3) — (4,882 ) — (9,272 ) Adjusted EBITDA $ 214,343 $ 254,853 $ 430,741 $ 516,577 Adjusted EBITDA: Domestic Pipelines & Terminals $ 133,082 $ 135,321 $ 268,975 $ 275,972 Global Marine Terminals 76,156 120,728 151,663 238,146 Merchant Services 5,105 (1,196 ) 10,103 2,459 Adjusted EBITDA $ 214,343 $ 254,853 $ 430,741 $ 516,577 (1) Includes 100% of the depreciation and amortization expense of $18.2 million and $36.0 million for Buckeye Texas for the three and six months ended June 30, 2018 , respectively. (2) Represents transaction, internal and third-party costs related to the Merger, asset acquisitions, dispositions, and integration. (3) Due to the significance of our equity method investment in VTTI, effective January 1, 2017 through September 30, 2018, we applied the definition of Adjusted EBITDA, covered in our description of Adjusted EBITDA, with respect to our proportionate share of VTTI’s Adjusted EBITDA. The calculation of our proportionate share of the reconciling items used to derive Adjusted EBITDA was based upon our 50% equity interest in VTTI, prior to adjustments related to noncontrolling interests in several of its subsidiaries and partnerships, which were immaterial. (4) Represents the loss on early extinguishment of the $275.0 million principal amount outstanding under our 5.500% notes and $250.0 million variable-rate Term Loan. (5) Represents gains on recoveries of property damages caused by third parties, which primarily related to a settlement in connection with a 2012 vessel allision with a jetty at our BBH facility in the Bahamas. (6) Represents costs incurred at our BBH facility in the Bahamas, Yabucoa Terminal in Puerto Rico, Corpus Christi facilities in Texas, and certain terminals in Florida, as a result of hurricanes, which occurred in 2017 and 2016, including operating expenses and write-offs of damaged long-lived assets, net of insurance recoveries.

SUPPLEMENTAL CASH FLOW INFORMAT

SUPPLEMENTAL CASH FLOW INFORMATION	6 Months Ended
	Jun. 30, 2019
Supplemental Cash Flow Elements [Abstract]
SUPPLEMENTAL CASH FLOW INFORMATION	18. SUPPLEMENTAL CASH FLOW INFORMATION Supplemental cash flows and non-cash transactions were as follows for the periods indicated (in thousands): Six Months Ended 2019 2018 Supplemental disclosures of cash flow information: Cash paid for interest (net of capitalized interest) $ 100,740 $ 108,405 Cash paid for income taxes 2,454 951 Capitalized interest 3,721 3,805 Cash paid for lease liabilities 12,119 N/A Non-cash activities: Issuance of Class C Units in Lieu of quarterly cash distribution $ — $ 8,469 Distribution payable to noncontrolling interest — 1,432 Recognition of non-cash ROU assets and operating lease obligations (see Note 9) 150,985 N/A Capital expenditure accruals 57,707 65,067

ORGANIZATION AND BASIS OF PRE_2

ORGANIZATION AND BASIS OF PRESENTATION (Policies)	6 Months Ended
	Jun. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization	Organization Buckeye Partners, L.P. is a publicly traded Delaware master limited partnership (“MLP”), and its limited partner units representing limited partnership interests (“LP Units”), are listed on the New York Stock Exchange under the ticker symbol “BPL.” Buckeye GP LLC (“Buckeye GP”) is our general partner. As used in these Notes to Unaudited Condensed Consolidated Financial Statements, “ we ,” “ us ,” “ our ” and “ Buckeye ” mean Buckeye Partners, L.P. and, where the context requires, include our subsidiaries. We own and operate a diversified global network of integrated assets providing midstream logistic solutions, primarily consisting of the transportation, storage, processing and marketing of liquid petroleum products. We are one of the largest independent liquid petroleum products pipeline operators in the United States in terms of volumes delivered, with approximately 6,000 miles of pipeline. We also use our service expertise to operate and/or maintain third-party pipelines and terminals and perform certain engineering and construction services for our customers. Our global terminal network comprises more than 115 liquid petroleum products terminals with aggregate tank capacity of over 118 million barrels across our portfolio of pipelines, inland terminals and marine terminals located primarily in key petroleum logistics hubs in the East Coast, Midwest and Gulf Coast regions of the United States as well as in the Caribbean. Our terminal assets facilitate global flows of crude oil and refined petroleum products, offering our customers connectivity between supply areas and market centers through some of the world’s most important bulk liquid storage and blending hubs. Our wholly-owned flagship marine terminal in The Bahamas, Buckeye Bahamas Hub Limited (“BBH”), is one of the largest marine crude oil and refined petroleum products storage facilities in the world and provides an array of logistics and blending services for the global flow of petroleum products. Our Gulf Coast regional hub, Buckeye Texas Partners LLC (“Buckeye Texas”), offers world-class marine terminalling, storage and processing capabilities. We are also a wholesale distributor of refined petroleum products in certain areas served by our pipelines and terminals.
Basis of Presentation and Principles of Consolidation	Basis of Presentation and Principles of Consolidation The unaudited condensed consolidated financial statements and the accompanying notes are prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and the rules of the SEC. Accordingly, our financial statements reflect all normal and recurring adjustments that are, in the opinion of management, necessary for a fair presentation of our results of operations for the interim periods. The unaudited condensed consolidated financial statements include the accounts of our subsidiaries controlled by us and variable interest entities of which we are the primary beneficiary. Intercompany transactions are eliminated in consolidation. The preparation of consolidated financial statements in conformity with GAAP requires our management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenue and expenses during the reporting period and disclosure of contingent assets and liabilities at the date of the consolidated financial statements. Estimates and assumptions about future events and their effects cannot be made with certainty. Estimates may change as new events occur, when additional information becomes available and if our operating environment changes. Actual results could differ from our estimates. We believe that the disclosures in these unaudited condensed consolidated financial statements are adequate to make the information presented not misleading. These interim financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto contained in our Annual Report on Form 10-K for the year ended December 31, 2018 .
Recently Adopted Accounting Standards/Recent Accounting Standards Not Yet Adopted	Recently Adopted Accounting Standards Derivatives and Hedging . Effective January 1, 2019, we adopted Accounting Standards Update (“ASU”) 2017-12, which amends and simplifies the existing standard in order to improve the financial reporting of hedging relationships to better align risk management activities in financial statements and make targeted improvements to simplify the application of the current standard related to the assessment of hedge effectiveness. In October 2018, the Financial Accounting Standards Board (“FASB”) issued ASU 2018-16, which includes the Overnight Index Swap Rate based on Secured Overnight Financing Rate as a U.S. benchmark interest rate for hedge accounting purposes under Accounting Standards Codification (“ASC”) Topic 815, Derivatives and Hedging. The adoption of this standard did not have a material impact on our unaudited condensed consolidated financial statements and disclosures. Leases . Effective January 1, 2019, we adopted ASC Topic 842, Leases (“ASC 842”), applying the modified retrospective transition method. We applied the transition provision for ASC 842 at our adoption date instead of at the earliest comparative period presented in our financial statements and, therefore, we recognized and measured leases existing at January 1, 2019, but without retrospective application. ASC 842 requires lessees to recognize a right-of-use (“ROU”) lease asset and a lease liability on the balance sheet for leases with lease terms greater than twelve months. ASC 842 also requires enhanced disclosures regarding the amount, timing and uncertainty of cash flows arising from leases. The most significant impact was the recognition of ROU lease assets and lease liabilities for operating leases on our unaudited condensed consolidated balance sheet along with certain incremental disclosures. No impact was recorded to the income statement or beginning retained earnings upon our adoption of ASC 842. See Note 9 - Leases for further discussion. Improvements to Nonemployee Share-Based Payment Accounting. Effective January 1, 2019, we adopted ASU 2018-07, which conformed the current nonemployee share-based accounting with employee share-based accounting. The adoption of this standard did not have a material impact on our unaudited condensed consolidated financial statements and disclosures. Recent Accounting Standards Not Yet Adopted Codification Improvements . In April 2019, the FASB issued ASU 2019-04, which clarifies certain aspects of accounting for credit losses, hedging activities, and financial instruments (addressed by ASUs 2016-13, 2017-12, and 2016-01, respectively). The amendments clarify the scope of the credit losses standard (ASU 2016-13) and address issues related to accrued interest receivable balances, recoveries, variable interest rates and prepayments. The amendments on recognizing and measuring financial instruments (ASU 2016-01), address the scope of the guidance, the requirement for remeasurement under ASC 820 when using the measurement alternative, certain disclosure requirements and which equity securities have to be remeasured at historical exchange rates. The amendments to the credit losses and hedging standards have the same effective dates as those standards, unless an entity has already adopted the standards. The amendments to the recognition and measurement guidance are effective for fiscal years beginning after December 15, 2019. Early adoption is permitted. We adopted the amendments related to hedging and financial instruments effective June 30, 2019, which did not have an impact on our unaudited condensed consolidated financial statements. We expect to adopt the amendments related to credit losses concurrently with the adoption of ASU 2016-13. Collaborative Arrangements. In November 2018, the FASB issued ASU 2018-18, which clarifies whether certain transactions between collaborative arrangement participants should be accounted for as revenue under ASC Topic 606, Revenue from Contracts with Customers (“ASC 606”). The new standard also provides more comparability in the presentation of revenue for certain transactions between collaborative arrangement participants. The standard is effective for fiscal years beginning after December 15, 2019 and interim periods within those fiscal years, with early adoption permitted. The standard should be applied retrospectively to the date of initial application of ASC 606. We expect to adopt this standard effective January 1, 2020 and are currently evaluating the impact that it will have on our consolidated financial statements and disclosures. Targeted Improvements to Related Party Guidance for Variable Interest Entities. In October 2018, the FASB issued ASU 2018-17 that changes the standard for determining whether a decision-making fee is a variable interest. The standard provides that indirect interests held through related parties under common control will be considered on a proportional basis when determining whether certain decision-making fees are variable interests. The standard is effective for fiscal years beginning after December 15, 2019 and interim periods within those fiscal years, with early adoption permitted. The standard should be applied retrospectively, with a cumulative effect adjustment to retained earnings. We expect to adopt this standard effective January 1, 2020 and are currently evaluating the impact that it will have on our consolidated financial statements and disclosures. Cloud Computing Arrangements. In August 2018, the FASB issued ASU 2018-15, which aligns a customer’s accounting for capitalizing implementation costs in a cloud computing service arrangement that is hosted by the vendor with the requirements for capitalizing implementation costs incurred to develop or obtain an internal-use software license. The standard is effective for fiscal years beginning after December 15, 2019 and interim periods within those fiscal years, with early adoption permitted. The standard can be applied prospectively or retrospectively. We expect to adopt this standard effective January 1, 2020 and are currently evaluating the impact that it will have on our consolidated financial statements and disclosures. Changes to the Disclosure Requirements for Defined Benefit Plans. In August 2018, the FASB issued ASU 2018-14, which amends the existing standard on disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The new standard is effective for fiscal years ending after December 15, 2020, with early adoption permitted. The new standard requires retrospective application. We expect to adopt this standard effective January 1, 2021 and are currently evaluating the impact that it will have on our disclosures. Changes to the Disclosure Requirements for Fair Value Measurement. In August 2018, the FASB issued ASU 2018-13, which amends the existing standard on disclosure requirements for fair value measurements. The new standard is effective for fiscal years beginning after December 15, 2019 and interim periods within those fiscal years, with early adoption permitted. The new standard requires prospective application on changes in unrealized gains and losses, the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements, and the narrative description of measurement uncertainty. The effects of other amendments must be applied retrospectively to all periods presented. We expect to adopt this standard effective January 1, 2020 and are currently evaluating the impact that it will have on our disclosures. Measurement of Credit Losses on Financial Instruments. In June 2016, the FASB issued ASU 2016-13, which replaces the current incurred loss impairment method with a method that reflects expected credit losses on financial instruments. In November 2018, the FASB issued update ASU 2018-19 that clarifies the scope of the standard in the amendments in ASU 2016-13. In May 2019, the FASB issued ASU 2019-05, which provides entities with an option to irrevocably elect the fair value option for certain financial instruments. The new standard is effective as of January 1, 2020, and early adoption is permitted as of January 1, 2019. We expect to adopt this standard effective January 1, 2020 and are currently evaluating the impact that the adoption of this standard will have on our consolidated financial statements and disclosures.

REVENUE (Tables)

REVENUE (Tables)	6 Months Ended
	Jun. 30, 2019
Revenue from Contract with Customer [Abstract]
Contract with Customer, Asset and Liability	The following table presents the activity in our contract assets and contract liabilities (in thousands): Six Months Ended 2019 2018 Contract Assets: Balance as of January 1 $ 16,989 $ 13,999 Additions 17,133 25,633 Transfers to accounts receivable (16,890 ) (13,751 ) Balance as of June 30 $ 17,232 $ 25,881 Contract Liabilities: Balance as of January 1 $ (26,999 ) $ (15,778 ) Additions (18,654 ) (18,184 ) Transfers to revenues (1) 12,403 6,586 Balance as of June 30 $ (33,250 ) $ (27,376 ) (1) For the three months ended June 30, 2019 and 2018, $0.8 million and $1.0 million , respectively, related to contract liabilities were transferred to revenue.
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	The following table includes estimated revenue associated with contractual commitments in place related to future performance obligations as of the end of the reporting period, which are expected to be recognized in revenue in the specified periods (in thousands): Revenue from Contracts with Customers Revenue from Leases Total Remainder of 2019 $ 197,741 $ 114,522 $ 312,263 2020 240,599 233,800 474,399 2021 152,116 206,213 358,329 2022 73,399 141,156 214,555 2023 67,108 27,153 94,261 Thereafter 304,739 24,283 329,022 Total $ 1,035,702 $ 747,127 $ 1,782,829

INVENTORIES (Tables)

INVENTORIES (Tables)	6 Months Ended
	Jun. 30, 2019
Inventory Disclosure [Abstract]
Schedule of inventory	Our inventory amounts were as follows at the dates indicated (in thousands): June 30, December 31, Liquid petroleum products (1) $ 105,724 $ 186,683 Materials and supplies 25,013 24,201 Total inventories $ 130,737 $ 210,884 (1) Ending inventory was 54.9 million and 114.7 million gallons of liquid petroleum products at June 30, 2019 and December 31, 2018 , respectively.

OTHER NON-CURRENT LIABILITIES (

OTHER NON-CURRENT LIABILITIES (Tables)	6 Months Ended
	Jun. 30, 2019
Other Liabilities, Noncurrent [Abstract]
Schedule of other non-current liabilities	Other non-current liabilities consist of the following at the dates indicated (in thousands): June 30, December 31, Long-term lease liabilities (see Note 9) $ 120,545 $ — Accrued employee benefit liabilities 27,682 28,246 Accrued environmental remediation liabilities 24,820 27,358 Deferred consideration 11,805 20,232 Asset retirement obligations 4,337 4,349 Other 8,407 4,715 Total other non-current liabilities $ 197,596 $ 84,900

PREPAID AND OTHER CURRENT ASS_2

PREPAID AND OTHER CURRENT ASSETS (Tables)	6 Months Ended
	Jun. 30, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of prepaid and other current assets	Prepaid and other current assets consist of the following at the dates indicated (in thousands): June 30, December 31, Prepaid insurance $ 17,863 $ 6,622 Margin deposits 5,093 8,684 Contract assets 17,232 16,989 Prepaid taxes 8,916 5,311 Other 16,061 21,288 Total prepaid and other current assets $ 65,165 $ 58,894

EQUITY INVESTMENTS (Tables)

EQUITY INVESTMENTS (Tables)	6 Months Ended
	Jun. 30, 2019
Equity Method Investments and Joint Ventures [Abstract]
Earnings (losses) from equity investments	The following table presents earnings (losses) from equity investments for the periods indicated (in thousands): Three Months Ended Six Months Ended Segment 2019 2018 2019 2018 VTTI B.V. (1) Global Marine Terminals $ — $ 4,882 $ — $ 9,272 West Shore Pipe Line Company Domestic Pipelines & Terminals 2,469 2,466 5,085 4,792 Muskegon Pipeline LLC Domestic Pipelines & Terminals (23 ) 431 461 756 Transport4, LLC Domestic Pipelines & Terminals 222 221 489 450 South Portland Terminal LLC Domestic Pipelines & Terminals 486 441 764 660 South Texas Gateway Terminal LLC (2) Global Marine Terminals (283 ) (176 ) (583 ) (176 ) Total earnings from equity investments $ 2,871 $ 8,265 $ 6,216 $ 15,754 (1) In January 2019, we completed the sale of our 50% equity interest in VTTI. See Note 3 - Acquisitions, Investments and Dispositions for further discussion. (2) In April 2018, we formed the STG Terminal joint venture. See Note 3 - Acquisitions, Investments and Disposition for further discussion.
Summary of combined income statement data for equity method investments	Summarized combined income statement data for our equity method investments is as follows for the periods indicated (amounts represent 100% of investee income statement data in thousands): Three Months Ended Six Months Ended 2019 2018 2019 2018 INCOME STATEMENT DATA: Revenue $ 24,467 $ 145,622 $ 47,756 $ 290,690 Operating income 13,361 40,027 26,473 89,809 Net income 10,313 26,382 20,443 51,132 Net income attributable to investee 10,313 25,170 20,443 48,129

LEASES (Tables)

LEASES (Tables)	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
Supplemental Balance Sheet Information	Supplemental balance sheet information related to leases is as follows (in thousands, except lease term and discount rate): Lease Activity Balance Sheet Location June 30, Operating lease right-of-use assets Other non-current assets $ 145,402 Current portion of operating lease liabilities Accrued and other current liabilities 30,440 Operating lease liabilities Other non-current liabilities 120,545 Total operating lease liabilities $ 150,985 Weighted average remaining lease term 16.2 years Weighted average discount rate 5.72 %
Minimum Lease Payments Maturity Schedule	The following table presents minimum lease payment obligations under noncancelable leases for our operating leases with terms in excess of one year as of June 30, 2019 (in thousands): Total Remainder of 2019 $ 18,500 2020 23,035 2021 19,314 2022 18,549 2023 18,541 Thereafter 140,426 Total 238,365 Less: Effect of discounting to net present value (87,380 ) Total operating lease liabilities $ 150,985
Prior to Adoption Minimum Lease Payments	The following table presents minimum lease payment obligations under our operating leases with terms in excess of one year for the years ending December 31st (in thousands): Total 2019 $ 29,050 2020 26,255 2021 22,215 2022 21,378 2023 21,126 Thereafter 138,466 Total $ 258,490

OTHER NON-CURRENT ASSETS (Table

OTHER NON-CURRENT ASSETS (Tables)	6 Months Ended
	Jun. 30, 2019
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of other non-current assets	Other non-current assets consist of the following at the dates indicated (in thousands): June 30, December 31, Right of use lease assets (see Note 9) $ 145,402 $ — Debt issuance costs 1,813 2,216 Insurance receivables related to environmental remediation reserves 1,632 2,057 Derivative assets 129 1,003 Other 22,975 35,862 Total other non-current assets $ 171,951 $ 41,138

DERIVATIVE INSTRUMENTS AND HE_2

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (Tables)	6 Months Ended
	Jun. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Summary of commodity derivative instruments outstanding	The following table summarizes the notional volumes of the net long (short) positions of our commodity derivative instruments outstanding at June 30, 2019 (amounts in thousands of gallons): Volume Derivative Purpose Current Long-Term Derivatives NOT designated as hedging instruments: Physical fixed-price derivative contracts (29,577 ) (1,201 ) Physical index derivative contracts (2,476 ) — Futures contracts for refined petroleum products 25,114 1,638 Hedge Type Derivatives designated as hedging instruments: Cash flow hedge futures contracts (294 ) — Cash Flow Hedge Futures contracts for refined petroleum products (52,920 ) — Fair Value Hedge
Fair value of each classification of derivative instrument and their location in the unaudited consolidated balance sheet	The following table sets forth the fair value of each classification of derivative instruments and the derivative instruments’ location on our unaudited condensed consolidated balance sheets at the dates indicated (in thousands): June 30, 2019 Derivative Carrying Value (1) Netting Balance Sheet Adjustment (2) Net Total Physical fixed-price derivative contracts $ 3,201 $ (585 ) $ 2,616 Physical index derivative contracts 140 — 140 Total current derivative assets 3,341 (585 ) 2,756 Physical fixed-price derivative contracts 129 — 129 Total non-current derivative assets 129 — 129 Physical fixed-price derivative contracts (1,369 ) 585 (784 ) Physical index derivative contracts (40 ) — (40 ) Total current derivative liabilities (1,409 ) 585 (824 ) Physical fixed-price derivative contracts (11 ) — (11 ) Total non-current derivative liabilities (11 ) — (11 ) Net derivative assets $ 2,050 $ — $ 2,050 (1) Other than our exchange-settled derivative contracts, as of June 30, 2019 , none of our derivative instruments were designated as hedging instruments. (2) Amounts represent the netting of physical fixed price and index contracts’ assets and liabilities when a legal right of offset exists. December 31, 2018 Derivative Carrying Value (1) Netting Balance Sheet Adjustment (2) Net Total Physical fixed-price derivative contracts $ 17,934 $ (84 ) $ 17,850 Physical index derivative contracts 286 (117 ) 169 Total current derivative assets 18,220 (201 ) 18,019 Physical fixed-price derivative contracts 1,003 — 1,003 Total non-current derivative assets 1,003 — 1,003 Physical fixed-price derivative contracts (1,386 ) 84 (1,302 ) Physical index derivative contracts (135 ) 117 (18 ) Total current derivative liabilities (1,521 ) 201 (1,320 ) Physical fixed-price derivative contracts (3 ) — (3 ) Total non-current derivative liabilities (3 ) — (3 ) Net derivative assets $ 17,699 $ — $ 17,699 (1) Other than our exchange-settled derivative contracts, as of December 31, 2018, none of our derivative instruments were designated as hedging instruments. (2) Amounts represent the netting of physical fixed price and index contracts’ assets and liabilities when a legal right of offset exists.
Gains and losses on derivative instruments recognized in income	The gains and losses on our derivative instruments recognized in income were as follows for the periods indicated (in thousands): Three Months Ended Six Months Ended Location 2019 2018 2019 2018 Derivatives NOT designated as hedging instruments: Physical fixed price derivative contracts Product sales $ 2,892 $ (1,659 ) $ (7,875 ) $ (305 ) Physical index derivative contracts Product sales 65 (17 ) 108 160 Physical fixed price derivative contracts Cost of product sales (2,370 ) 552 (1,631 ) (53 ) Physical index derivative contracts Cost of product sales (161 ) 424 (216 ) 426 Futures contracts for refined products Cost of product sales (935 ) (2,265 ) 1,848 (4,563 ) Three Months Ended Six Months Ended Location 2019 2018 2019 2018 Derivatives designated as fair value hedging instruments: Futures contracts for refined products Cost of product sales $ 1,299 $ (10,013 ) $ (27,624 ) $ (4,306 ) Physical inventory - hedged items Cost of product sales (1,364 ) 9,530 28,565 3,540 Three Months Ended Six Months Ended Location 2019 2018 2019 2018 Ineffectiveness excluding the time value component on fair value hedging instruments: Fair value hedge ineffectiveness (excluding time value) Cost of product sales $ (1,345 ) (114 ) $ (2,709 ) $ (196 ) Time value excluded from hedge assessment Cost of product sales 1,280 (369 ) 3,650 (570 ) Net (loss) gain for ineffectiveness in income $ (65 ) $ (483 ) $ 941 $ (766 )
(Loss) gain recognized in OCI and gains (losses) reclassified from AOCI to income	The change in value recognized in OCI and the losses reclassified from accumulated other comprehensive income (“AOCI”) to income, attributable to our derivative instruments designated as cash flow hedges, were as follows for the periods indicated (in thousands): Gain (Loss) Recognized in OCI on Derivatives for the Three Months Ended Six Months Ended 2019 2018 2019 2018 Derivatives designated as cash flow hedging instruments: Interest rate contracts $ — $ 5,656 $ — $ 20,417 Commodity derivatives (823 ) 3,280 (722 ) 2,657 Total $ (823 ) $ 8,936 $ (722 ) $ 23,074 Loss Reclassified from AOCI to Income (Effective Portion) for the Three Months Ended Six Months Ended Location 2019 2018 2019 2018 Derivatives designated as cash flow hedging instruments: Interest rate derivative contracts Interest and debt expense $ (2,296 ) $ (2,295 ) $ (4,592 ) $ (4,632 ) Total $ (2,296 ) $ (2,295 ) $ (4,592 ) $ (4,632 )

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	6 Months Ended
	Jun. 30, 2019
Fair Value Disclosures [Abstract]
Financial assets and liabilities measured at fair value on a recurring basis	The following table sets forth financial assets and liabilities measured at fair value on a recurring basis, as of the measurement dates indicated, and the basis for that measurement, by level within the fair value hierarchy (in thousands): June 30, 2019 December 31, 2018 Level 1 Level 2 Level 1 Level 2 Financial assets: Physical fixed-price derivative contracts $ — $ 3,330 $ — $ 18,937 Physical index derivative contracts — 140 — 286 Financial liabilities: Physical fixed-price derivative contracts — (1,380 ) — (1,389 ) Physical index derivative contracts — (40 ) — (135 ) Fair value $ — $ 2,050 $ — $ 17,699
Carrying value and fair value using level 2 inputs of debt	The carrying value and fair value of our debt, using Level 2 input values, were as follows at the dates indicated (in thousands): June 30, 2019 December 31, 2018 Carrying Amount Fair Value Carrying Amount Fair Value Fixed-rate debt $ 3,273,334 $ 3,046,533 $ 3,546,396 $ 3,364,549 Variable-rate debt 566,647 570,275 1,168,046 1,172,328 Total debt $ 3,839,981 $ 3,616,808 $ 4,714,442 $ 4,536,877

UNIT-BASED COMPENSATION PLANS (

UNIT-BASED COMPENSATION PLANS (Tables)	6 Months Ended
	Jun. 30, 2019
Share-based Payment Arrangement [Abstract]
Awards activity under the LTIP	The following table sets forth the LTIP activity for the periods indicated (in thousands, except per unit amounts): Number of LP Units Weighted Average Grant Date Fair Value per LP Unit (1) Unvested at January 1, 2019 1,645 $ 55.52 Granted (2) 907 30.97 Vested (241 ) 52.23 Forfeited (253 ) 50.46 Unvested at June 30, 2019 2,058 $ 45.71 (1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued. The weighted-average grant date fair value per LP Unit for forfeited and vested awards is determined before an allowance for forfeitures. (2) Includes both phantom and performance awards. Performance awards are granted at a target amount but, depending on our performance during the vesting period with respect to certain pre-established goals, the number of LP Units issued upon vesting of such performance awards can be greater or less than the target amount.

PARTNERS' CAPITAL AND DISTRIB_2

PARTNERS' CAPITAL AND DISTRIBUTIONS (Tables)	6 Months Ended
	Jun. 30, 2019
Equity [Abstract]
Summary of changes in LP units outstanding	The following is a summary of changes in Buckeye ’ s outstanding units for the period indicated (in thousands): LP Units Units outstanding at January 1, 2019 153,755 LP units issued pursuant to the LTIP (1) 166 Units outstanding at June 30, 2019 153,921 (1) The number of LP Units issued represents issuance net of tax withholding.

EARNINGS PER UNIT (Tables)

EARNINGS PER UNIT (Tables)	6 Months Ended
	Jun. 30, 2019
Earnings Per Share [Abstract]
Reconciliation of weighted average units outstanding used in computing basic and diluted earnings per unit	The following tables set forth the calculation of basic and diluted earnings per unit, attributable to Buckeye’s unitholders, taking into consideration net income allocable to participating securities, as well as the reconciliation of basic weighted average units outstanding to diluted weighted average units outstanding (in thousands, except per unit amounts). Three Months Ended Six Months Ended 2019 2018 2019 2018 Net income attributable to unitholders $ 89,152 $ 90,665 $ 169,044 $ 201,789 Basic: Weighted average units outstanding - basic 153,918 153,258 153,882 151,093 Earnings per unit - basic $ 0.58 $ 0.59 $ 1.10 $ 1.34 Diluted: Weighted average units outstanding - basic 153,918 153,258 153,882 151,093 Effect of dilutive securities 824 731 757 677 Weighted average units outstanding - diluted 154,742 153,989 154,639 151,770 Earnings per unit - diluted $ 0.58 $ 0.59 $ 1.09 $ 1.33

BUSINESS SEGMENTS (Tables)

BUSINESS SEGMENTS (Tables)	6 Months Ended
	Jun. 30, 2019
Segment Reporting [Abstract]
Disaggregation of revenue	The following tables provide information about our revenue types by reportable segment for the periods indicated (in thousands). Three Months Ended June 30, 2019 Domestic Pipelines & Terminals Global Marine Terminals Merchant Services Intersegment Eliminations Total Revenue from contracts with customers Pipeline transportation $ 119,798 $ — $ — $ (2,504 ) $ 117,294 Terminalling and storage services 102,360 87,406 — (6,411 ) 183,355 Product sales — 5 344,502 (2,930 ) 341,577 Other services 12,627 435 576 (17 ) 13,621 Total revenue from contracts with customers 234,785 87,846 345,078 (11,862 ) 655,847 Revenue from leases 10,490 46,511 — (142 ) 56,859 Commodity derivative contracts, net (1,694 ) — 80,690 — 78,996 Total revenue $ 243,581 $ 134,357 $ 425,768 $ (12,004 ) $ 791,702 Three Months Ended June 30, 2018 Domestic Pipelines & Terminals Global Marine Terminals Merchant Services Intersegment Eliminations Total Revenue from contracts with customers Pipeline transportation $ 127,959 $ — $ — $ (2,163 ) $ 125,796 Terminalling and storage services 100,981 99,927 — (9,730 ) 191,178 Product sales — 7 455,185 (1,889 ) 453,303 Other services 10,694 320 1,920 (15 ) 12,919 Total revenue from contracts with customers 239,634 100,254 457,105 (13,797 ) 783,196 Revenue from leases 11,065 42,889 — — 53,954 Commodity derivative contracts, net (819 ) — 104,508 — 103,689 Total revenue $ 249,880 $ 143,143 $ 561,613 $ (13,797 ) $ 940,839 Six Months Ended June 30, 2019 Domestic Pipelines & Terminals Global Marine Terminals Merchant Services Intersegment Eliminations Total Revenue from contracts with customers Pipeline transportation $ 242,013 $ — $ — $ (5,175 ) $ 236,838 Terminalling and storage services 208,139 175,768 — (16,907 ) 367,000 Product sales — 262 863,566 (5,682 ) 858,146 Other services 20,188 870 1,056 (32 ) 22,082 Total revenue from contracts with customers 470,340 176,900 864,622 (27,796 ) 1,484,066 Revenue from leases 20,015 91,464 — (294 ) 111,185 Commodity derivative contracts, net (5,238 ) — 230,661 — 225,423 Total revenue $ 485,117 $ 268,364 $ 1,095,283 $ (28,090 ) $ 1,820,674 Six Months Ended June 30, 2018 Domestic Pipelines & Terminals Global Marine Terminals Merchant Services Intersegment Eliminations Total Revenue from contracts with customers Pipeline transportation $ 249,430 $ — $ — $ (5,803 ) $ 243,627 Terminalling and storage services 216,956 201,145 — (18,323 ) 399,778 Product sales — 20 1,098,693 (5,242 ) 1,093,471 Other services 22,783 341 4,820 (1,362 ) 26,582 Total revenue from contracts with customers 489,169 201,506 1,103,513 (30,730 ) 1,763,458 Revenue from leases 19,055 85,722 — — 104,777 Commodity derivative contracts, net (2,909 ) — 256,528 2,090 255,709 Total revenue $ 505,315 $ 287,228 $ 1,360,041 $ (28,640 ) $ 2,123,944
Summary of revenue for continuing operations by major geographic area	The following table summarizes revenue by major geographic area for the periods indicated (in thousands): Three Months Ended Six Months Ended 2019 2018 2019 2018 Revenue: United States $ 740,538 $ 878,607 $ 1,718,318 $ 2,000,827 International 51,164 62,232 102,356 123,117 Total revenue $ 791,702 $ 940,839 $ 1,820,674 $ 2,123,944
Adjusted EBITDA by segment and Reconciliation of Net Income to Adjusted EBITDA	The following table presents a reconciliation of consolidated net income, which is the most comparable financial measure under GAAP, to Adjusted EBITDA, as well as Adjusted EBITDA by segment for the periods indicated (in thousands): Three Months Ended Six Months Ended 2019 2018 2019 2018 Reconciliation of Net (loss) income to Adjusted EBITDA: Net income $ 90,515 $ 93,317 $ 171,775 $ 210,409 Less: Net income attributable to noncontrolling interests (496 ) (1,413 ) (994 ) (6,132 ) Net income attributable to Buckeye Partners, L.P. 90,019 91,904 170,781 204,277 Add: Interest and debt expense 49,574 59,566 101,742 118,671 Income tax expense 297 782 595 1,272 Depreciation and amortization (1) 65,859 66,569 129,743 130,707 Non-cash unit-based compensation expense 5,781 7,976 15,698 16,666 Acquisition, dispositions, and transition expense (2) 5,783 141 9,866 423 Non-cash impairment on disposals of long-lived assets 911 — 3,106 — Proportionate share of Adjusted EBITDA for equity method investment in VTTI (3) — 34,640 — 69,180 Loss on early extinguishment of debt (4) — — 4,020 — Less: Gains on property damage recoveries (5) — (450 ) — (14,535 ) Hurricane-related costs, net of recoveries (6) (3,881 ) (1,393 ) (4,810 ) (812 ) Earnings from the equity method investment in VTTI (3) — (4,882 ) — (9,272 ) Adjusted EBITDA $ 214,343 $ 254,853 $ 430,741 $ 516,577 Adjusted EBITDA: Domestic Pipelines & Terminals $ 133,082 $ 135,321 $ 268,975 $ 275,972 Global Marine Terminals 76,156 120,728 151,663 238,146 Merchant Services 5,105 (1,196 ) 10,103 2,459 Adjusted EBITDA $ 214,343 $ 254,853 $ 430,741 $ 516,577 (1) Includes 100% of the depreciation and amortization expense of $18.2 million and $36.0 million for Buckeye Texas for the three and six months ended June 30, 2018 , respectively. (2) Represents transaction, internal and third-party costs related to the Merger, asset acquisitions, dispositions, and integration. (3) Due to the significance of our equity method investment in VTTI, effective January 1, 2017 through September 30, 2018, we applied the definition of Adjusted EBITDA, covered in our description of Adjusted EBITDA, with respect to our proportionate share of VTTI’s Adjusted EBITDA. The calculation of our proportionate share of the reconciling items used to derive Adjusted EBITDA was based upon our 50% equity interest in VTTI, prior to adjustments related to noncontrolling interests in several of its subsidiaries and partnerships, which were immaterial. (4) Represents the loss on early extinguishment of the $275.0 million principal amount outstanding under our 5.500% notes and $250.0 million variable-rate Term Loan. (5) Represents gains on recoveries of property damages caused by third parties, which primarily related to a settlement in connection with a 2012 vessel allision with a jetty at our BBH facility in the Bahamas. (6) Represents costs incurred at our BBH facility in the Bahamas, Yabucoa Terminal in Puerto Rico, Corpus Christi facilities in Texas, and certain terminals in Florida, as a result of hurricanes, which occurred in 2017 and 2016, including operating expenses and write-offs of damaged long-lived assets, net of insurance recoveries.

SUPPLEMENTAL CASH FLOW INFORM_2

SUPPLEMENTAL CASH FLOW INFORMATION (Tables)	6 Months Ended
	Jun. 30, 2019
Supplemental Cash Flow Elements [Abstract]
Supplemental cash flows and non-cash transactions	Supplemental cash flows and non-cash transactions were as follows for the periods indicated (in thousands): Six Months Ended 2019 2018 Supplemental disclosures of cash flow information: Cash paid for interest (net of capitalized interest) $ 100,740 $ 108,405 Cash paid for income taxes 2,454 951 Capitalized interest 3,721 3,805 Cash paid for lease liabilities 12,119 N/A Non-cash activities: Issuance of Class C Units in Lieu of quarterly cash distribution $ — $ 8,469 Distribution payable to noncontrolling interest — 1,432 Recognition of non-cash ROU assets and operating lease obligations (see Note 9) 150,985 N/A Capital expenditure accruals 57,707 65,067

ORGANIZATION AND BASIS OF PRE_3

ORGANIZATION AND BASIS OF PRESENTATION - Additional Information (Details) mi in Thousands, bbl in Millions	6 Months Ended
	Jun. 30, 2019terminalmibbl	May 10, 2019$ / shares
Business Acquisition [Line Items]
Length of refined petroleum products pipelines (in miles) | mi	6
Number of terminals (more than) | terminal	115
Storage capacity of refined petroleum product terminals (in bbl) | bbl	118
Hercules Merger Sub LLC
Business Acquisition [Line Items]
Right to receive cash (in dollars per share) | $ / shares		$ 41.50

REVENUE - Contract Asset and Li

REVENUE - Contract Asset and Liability (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Receivables from contracts with customers	$ 204,200		$ 204,200		$ 199,300
Contract Assets:
Beginning balance			16,989	$ 13,999
Additions			17,133	25,633
Transfers to accounts receivable			(16,890)	(13,751)
Ending balance	17,232	$ 25,881	17,232	25,881
Contract Liabilities:
Beginning balance			(26,999)	(15,778)
Additions			(18,654)	(18,184)
Transfers to revenues	800	1,000	12,403	6,586
Ending balance	$ (33,250)	$ (27,376)	$ (33,250)	$ (27,376)

REVENUE - Performance Obligatio

REVENUE - Performance Obligations (Details) $ in Thousands	Jun. 30, 2019USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 312,263
Remaining performance obligation, period	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 474,399
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 358,329
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 214,555
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 94,261
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 329,022
Remaining performance obligation, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 1,782,829
Revenue from Contracts with Customers | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 197,741
Remaining performance obligation, period	6 months
Revenue from Contracts with Customers | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 240,599
Remaining performance obligation, period	1 year
Revenue from Contracts with Customers | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 152,116
Remaining performance obligation, period	1 year
Revenue from Contracts with Customers | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 73,399
Remaining performance obligation, period	1 year
Revenue from Contracts with Customers | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 67,108
Remaining performance obligation, period	1 year
Revenue from Contracts with Customers | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 304,739
Remaining performance obligation, period
Revenue from Contracts with Customers | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 1,035,702
Revenue from Leases | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 114,522
Remaining performance obligation, period	6 months
Revenue from Leases | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 233,800
Remaining performance obligation, period	1 year
Revenue from Leases | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 206,213
Remaining performance obligation, period	1 year
Revenue from Leases | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 141,156
Remaining performance obligation, period	1 year
Revenue from Leases | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 27,153
Remaining performance obligation, period	1 year
Revenue from Leases | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 24,283
Remaining performance obligation, period
Revenue from Leases | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 747,127

REVENUE - Narrative (Details)

REVENUE - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Property Subject to or Available for Operating Lease [Line Items]
Operating leases	$ 6,982,111		$ 6,982,111		$ 6,914,796
Accumulated depreciation	1,438,994		1,438,994		$ 1,343,898
Assets Leased to Others | Tolling, Storage and Pipeline Transportation Services
Property Subject to or Available for Operating Lease [Line Items]
Operating leases	241,200		241,200
Accumulated depreciation	31,700		31,700
Depreciation expense	$ 900	$ 900	$ 1,800	$ 1,800

ACQUISITIONS, INVESTMENTS AND_2

ACQUISITIONS, INVESTMENTS AND DISPOSITIONS - Narrative (Details) $ in Thousands, bbl in Millions	1 Months Ended			6 Months Ended
	Jun. 30, 2019USD ($)	Jan. 31, 2019USD ($)	Apr. 30, 2018USD ($)dockbbl	Jun. 30, 2019USD ($)	Jun. 30, 2018USD ($)	Dec. 31, 2018USD ($)
Business Acquisition [Line Items]
Proceeds from sale of VTTI and DPTS asset package				$ 985,000	$ 0
Equity investments	$ 169,400			169,400		$ 1,111,793
Acquisition of and contribution to equity investments				38,196	$ 28,361
Buckeye Texas Partners LLC
Business Acquisition [Line Items]
Percentage of interest acquired			20.00%
Consideration for business acquisition			$ 210,000
Joint Venture
Business Acquisition [Line Items]
Initial product storage capacity (in bbl) | bbl			3.4
Additional product storage capacity (in bbl) | bbl			7
Number Of Deep Water Vessel Docks | dock			2
Ownership percentage			50.00%
Equity investments	72,500			72,500
Acquisition of and contribution to equity investments				$ 31,800
Joint Venture | Phillips 66 Partners LP
Business Acquisition [Line Items]
Ownership percentage			25.00%
Joint Venture | Marathon
Business Acquisition [Line Items]
Ownership percentage			25.00%
Disposed of by sale
Business Acquisition [Line Items]
Proceeds from disposal	$ 10,000
Disposed of by sale | VTTI B.V.
Business Acquisition [Line Items]
Percentage of ownership sold		50.00%
Proceeds from sale of VTTI and DPTS asset package		$ 975,000
Transaction costs		$ 4,000

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - Environmental Contingencies (Details) - Environmental remediation unrelated to claims and legal proceedings - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Commitments and Contingencies Disclosure
Environmental remediation liabilities	$ 35.5	$ 39
Receivables related to environmental remediation expenditures covered by insurance or third party claims	$ 3.9	$ 4.2

INVENTORIES (Details)

INVENTORIES (Details) $ in Thousands, gal in Millions	Jun. 30, 2019USD ($)gal	Dec. 31, 2018USD ($)gal
Inventory Disclosure [Abstract]
Liquid petroleum products	$ 105,724	$ 186,683
Materials and supplies	25,013	24,201
Total inventories	$ 130,737	$ 210,884
Refined petroleum products (in gallons) | gal	54.9	114.7
Percentage of hedged refined petroleum products inventory	96.00%	94.00%

OTHER NON-CURRENT LIABILITIES_2

OTHER NON-CURRENT LIABILITIES (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Other Liabilities, Noncurrent [Abstract]
Long-term lease liabilities (see Note 9)	$ 120,545	$ 0
Accrued employee benefit liabilities	27,682	28,246
Accrued environmental remediation liabilities	24,820	27,358
Deferred consideration	11,805	20,232
Asset retirement obligations	4,337	4,349
Other	8,407	4,715
Total other non-current liabilities	$ 197,596	$ 84,900

PREPAID AND OTHER CURRENT ASS_3

PREPAID AND OTHER CURRENT ASSETS (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Prepaid insurance	$ 17,863	$ 6,622
Margin deposits	5,093	8,684
Contract assets	17,232	16,989
Prepaid taxes	8,916	5,311
Other	16,061	21,288
Total prepaid and other current assets	$ 65,165	$ 58,894

EQUITY INVESTMENTS - Equity Inv

EQUITY INVESTMENTS - Equity Investments (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Jan. 31, 2019	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Equity investments
Total earnings from equity investments		$ 2,871	$ 8,265	$ 6,216	$ 15,754
VTTI B.V.
Equity investments
Total earnings from equity investments			4,882		9,272
Global Marine Terminals | VTTI B.V.
Equity investments
Total earnings from equity investments		0	4,882	0	9,272
Global Marine Terminals | South Texas Gateway Terminal LLC
Equity investments
Total earnings from equity investments		(283)	(176)	(583)	(176)
Domestic Pipelines & Terminals | West Shore Pipe Line Company
Equity investments
Total earnings from equity investments		2,469	2,466	5,085	4,792
Domestic Pipelines & Terminals | Muskegon Pipeline LLC
Equity investments
Total earnings from equity investments		(23)	431	461	756
Domestic Pipelines & Terminals | Transport4, LLC
Equity investments
Total earnings from equity investments		222	221	489	450
Domestic Pipelines & Terminals | South Portland Terminal LLC
Equity investments
Total earnings from equity investments		$ 486	$ 441	$ 764	$ 660
Disposed of by sale | VTTI B.V.
Equity investments
Percentage of ownership sold	50.00%

EQUITY INVESTMENTS - Income Fro

EQUITY INVESTMENTS - Income From Equity Method Investments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Representation of investee financial information in the summarized equity method investments (as a percent)			100.00%
INCOME STATEMENT DATA:
Revenue	$ 24,467	$ 145,622	$ 47,756	$ 290,690
Operating income	13,361	40,027	26,473	89,809
Net income	10,313	26,382	20,443	51,132
Net income attributable to investee	$ 10,313	$ 25,170	$ 20,443	$ 48,129

LEASES - Narrative (Details)

LEASES - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Leases [Abstract]
Operating lease costs	$ 8	$ 8.1	$ 16.4	$ 16.2
Short-term operating lease costs	$ 1.2	$ 2.3	$ 3.5	$ 5.2

OTHER NON-CURRENT ASSETS (Detai

OTHER NON-CURRENT ASSETS (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Right of use lease assets (see Note 9)	$ 145,402	$ 0
Debt issuance costs	1,813	2,216
Insurance receivables related to environmental remediation reserves	1,632	2,057
Derivative assets	129	1,003
Other	22,975	35,862
Total other non-current assets	$ 171,951	$ 41,138

LEASES - Supplemental Balance S

LEASES - Supplemental Balance Sheet Information (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Dec. 31, 2018
Leases [Abstract]
Operating lease right-of-use assets	$ 145,402	$ 0
Current portion of operating lease liabilities	30,440
Operating lease liabilities	120,545	$ 0
Non-Cash, Recognition Of Right Of Use Assets And Operating Lease Liabilities	150,985
Total operating lease liabilities	$ 150,985
Weighted average remaining lease term	16 years 2 months 12 days
Weighted average discount rate	5.72%

LEASES - Minimum Lease Payment

LEASES - Minimum Lease Payment Obligations (Details) $ in Thousands	Jun. 30, 2019USD ($)
Leases [Abstract]
Remainder of 2019	$ 18,500
2020	23,035
2021	19,314
2022	18,549
2023	18,541
Thereafter	140,426
Total	238,365
Less: Effect of discounting to net present value	(87,380)
Total operating lease liabilities	$ 150,985

LEASES - Minimum Lease Paymen_2

LEASES - Minimum Lease Payment Obligations Prior to Adoption (Details) $ in Thousands	Dec. 31, 2018USD ($)
Leases [Abstract]
2019	$ 29,050
2020	26,255
2021	22,215
2022	21,378
2023	21,126
Thereafter	138,466
Total	$ 258,490

LONG-TERM DEBT (Details)

LONG-TERM DEBT (Details) - USD ($)	1 Months Ended			3 Months Ended		6 Months Ended
	Feb. 28, 2019	Jan. 31, 2019	Jan. 31, 2018	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Debt instrument
Loss on early extinguishment of debt						$ 4,020,000	$ 0
Unamortized financing costs				$ 1,813,000		1,813,000		$ 2,216,000
Line of credit				$ 109,820,000		$ 109,820,000		$ 177,727,000
Junior Subordinated Debt
Debt instrument
Interest rate percentage			6.375%
Face amount			$ 400,000,000
Proceeds from issuance of debt			394,900,000
Revolving Credit Facility
Debt instrument
Weighted average interest rate				4.00%		4.00%
Revolving Credit Facility | Line of credit
Debt instrument
Maximum borrowing capacity				$ 1,500,000,000		$ 1,500,000,000
6.050% Notes Due January 2018
Debt instrument
Principal amount repaid			$ 300,000,000
Interest rate percentage			6.05%
Term Loan
Debt instrument
Principal amount repaid		$ 250,000,000
5.500% Notes Due August 2019
Debt instrument
Principal amount repaid	$ 275,000,000
Interest rate percentage	5.50%
Loss on early extinguishment of debt	$ 4,000,000			0	$ 0
Make-whole payment	3,600,000
Unamortized financing costs	$ 400,000
Credit Facility
Debt instrument
Outstanding balance				170,300,000		170,300,000
Line of credit				$ 109,800,000		$ 109,800,000
LIBOR | Junior Subordinated Debt
Debt instrument
Variable rate			4.02%

DERIVATIVE INSTRUMENTS AND HE_3

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Commodity Derivative Instruments (Details) gal in Thousands	6 Months Ended
	Jun. 30, 2019gal
Derivatives NOT Designated as Hedging Instruments | Physical fixed-price derivative contracts | Current
Derivative Instruments And Hedging Activities
Volume (in gallons)	29,577
Derivatives NOT Designated as Hedging Instruments | Physical fixed-price derivative contracts | Long-Term
Derivative Instruments And Hedging Activities
Volume (in gallons)	1,201
Derivatives NOT Designated as Hedging Instruments | Physical index derivative contracts | Current
Derivative Instruments And Hedging Activities
Volume (in gallons)	2,476
Derivatives NOT Designated as Hedging Instruments | Physical index derivative contracts | Long-Term
Derivative Instruments And Hedging Activities
Volume (in gallons)	0
Derivatives NOT Designated as Hedging Instruments | Futures contracts for refined petroleum products | Current
Derivative Instruments And Hedging Activities
Volume (in gallons)	25,114
Derivatives NOT Designated as Hedging Instruments | Futures contracts for refined petroleum products | Long-Term
Derivative Instruments And Hedging Activities
Volume (in gallons)	1,638
Derivatives Designated as Hedging Instruments | Cash Flow Hedge | Cash flow hedge futures contracts | Current
Derivative Instruments And Hedging Activities
Volume (in gallons)	294
Derivatives Designated as Hedging Instruments | Cash Flow Hedge | Cash flow hedge futures contracts | Long-Term
Derivative Instruments And Hedging Activities
Volume (in gallons)	0
Derivatives Designated as Hedging Instruments | Fair Value Hedge | Futures contracts for refined petroleum products | Current
Derivative Instruments And Hedging Activities
Volume (in gallons)	52,920
Derivatives Designated as Hedging Instruments | Fair Value Hedge | Futures contracts for refined petroleum products | Long-Term
Derivative Instruments And Hedging Activities
Volume (in gallons)	0

DERIVATIVE INSTRUMENTS AND HE_4

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Fair Value of Each Classification of Derivative Instrument (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Derivatives, Fair Value
Fair value	$ 2,050	$ 17,699
Netting balance sheet adjustment	0	0
Net Total
Derivatives, Fair Value
Fair value	2,050	17,699
Total current derivative assets
Derivatives, Fair Value
Fair value	3,341	18,220
Netting balance sheet adjustment	(585)	(201)
Total current derivative assets | Physical fixed-price derivative contracts
Derivatives, Fair Value
Fair value	3,201	17,934
Netting balance sheet adjustment	(585)	(84)
Total current derivative assets | Physical index derivative contracts
Derivatives, Fair Value
Fair value	140	286
Netting balance sheet adjustment	0	(117)
Total current derivative assets | Net Total
Derivatives, Fair Value
Fair value	2,756	18,019
Total current derivative assets | Net Total | Physical fixed-price derivative contracts
Derivatives, Fair Value
Fair value	2,616	17,850
Total current derivative assets | Net Total | Physical index derivative contracts
Derivatives, Fair Value
Fair value	140	169
Total non-current derivative assets
Derivatives, Fair Value
Fair value	129	1,003
Netting balance sheet adjustment	0	0
Total non-current derivative assets | Physical fixed-price derivative contracts
Derivatives, Fair Value
Fair value	129	1,003
Netting balance sheet adjustment	0	0
Total non-current derivative assets | Net Total
Derivatives, Fair Value
Fair value	129	1,003
Total non-current derivative assets | Net Total | Physical fixed-price derivative contracts
Derivatives, Fair Value
Fair value	129	1,003
Total current derivative liabilities
Derivatives, Fair Value
Fair value	(1,409)	(1,521)
Netting balance sheet adjustment	585	201
Total current derivative liabilities | Physical fixed-price derivative contracts
Derivatives, Fair Value
Fair value	(1,369)	(1,386)
Netting balance sheet adjustment	585	84
Total current derivative liabilities | Physical index derivative contracts
Derivatives, Fair Value
Fair value	(40)	(135)
Netting balance sheet adjustment	0	117
Total current derivative liabilities | Net Total
Derivatives, Fair Value
Fair value	(824)	(1,320)
Total current derivative liabilities | Net Total | Physical fixed-price derivative contracts
Derivatives, Fair Value
Fair value	(784)	(1,302)
Total current derivative liabilities | Net Total | Physical index derivative contracts
Derivatives, Fair Value
Fair value	(40)	(18)
Total non-current derivative liabilities
Derivatives, Fair Value
Fair value	(11)	(3)
Netting balance sheet adjustment	0	0
Total non-current derivative liabilities | Physical fixed-price derivative contracts
Derivatives, Fair Value
Fair value	(11)	(3)
Netting balance sheet adjustment	0	0
Total non-current derivative liabilities | Net Total
Derivatives, Fair Value
Fair value	(11)	(3)
Total non-current derivative liabilities | Net Total | Physical fixed-price derivative contracts
Derivatives, Fair Value
Fair value	$ (11)	$ (3)

DERIVATIVE INSTRUMENTS AND HE_5

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Gains and Losses on Derivative Instruments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Derivatives NOT Designated as Hedging Instruments | Product sales | Physical fixed-price derivative contracts
Derivatives NOT designated as hedging instruments:
Gain (loss) recognized in income	$ 2,892	$ (1,659)	$ (7,875)	$ (305)
Derivatives NOT Designated as Hedging Instruments | Product sales | Physical index derivative contracts
Derivatives NOT designated as hedging instruments:
Gain (loss) recognized in income	65	(17)	108	160
Derivatives NOT Designated as Hedging Instruments | Cost of product sales | Physical fixed-price derivative contracts
Derivatives NOT designated as hedging instruments:
Gain (loss) recognized in income	(2,370)	552	(1,631)	(53)
Derivatives NOT Designated as Hedging Instruments | Cost of product sales | Physical index derivative contracts
Derivatives NOT designated as hedging instruments:
Gain (loss) recognized in income	(161)	424	(216)	426
Derivatives NOT Designated as Hedging Instruments | Cost of product sales | Futures contracts for refined products
Derivatives NOT designated as hedging instruments:
Gain (loss) recognized in income	(935)	(2,265)	1,848	(4,563)
Derivatives Designated as Hedging Instruments | Cost of product sales | Hedge Ineffectiveness
Ineffectiveness excluding the time value component on fair value hedging instruments:
Fair value hedge ineffectiveness (excluding time value)	(1,345)	(114)	(2,709)	(196)
Time value excluded from hedge assessment	1,280	(369)	3,650	(570)
Net (loss) gain for ineffectiveness in income	(65)	(483)	941	(766)
Derivatives Designated as Hedging Instruments | Cost of product sales | Futures contracts for refined products
Derivatives designated as fair value hedging instruments:
Futures contracts for refined products	1,299	(10,013)	(27,624)	(4,306)
Derivatives Designated as Hedging Instruments | Cost of product sales | Physical inventory - hedged items
Derivatives designated as fair value hedging instruments:
Physical inventory - hedged items	$ (1,364)	$ 9,530	$ 28,565	$ 3,540

DERIVATIVE INSTRUMENTS AND HE_6

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Changes in Value Recognized in OCI (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Losses reclassified from AOCI to income
Gain (Loss) Recognized in OCI on Derivatives	$ (823)	$ 8,936	$ (722)	$ 23,074
Loss Reclassified from AOCI to Income (Effective Portion)	(2,296)	(2,295)	(4,592)	(4,632)
Cash Flow Hedge
Losses reclassified from AOCI to income
Gain (Loss) Recognized in OCI on Derivatives	(823)	8,936	(722)	23,074
Loss Reclassified from AOCI to Income (Effective Portion)	(2,296)	(2,295)	(4,592)	(4,632)
Cash Flow Hedge | Interest rate derivative contracts
Losses reclassified from AOCI to income
Gain (Loss) Recognized in OCI on Derivatives	0	5,656	0	20,417
Cash Flow Hedge | Commodity derivatives
Losses reclassified from AOCI to income
Gain (Loss) Recognized in OCI on Derivatives	(823)	3,280	(722)	2,657
Interest and debt expense | Cash Flow Hedge | Interest rate derivative contracts
Losses reclassified from AOCI to income
Loss Reclassified from AOCI to Income (Effective Portion)	$ (2,296)	$ (2,295)	$ (4,592)	$ (4,632)

DERIVATIVE INSTRUMENTS AND HE_7

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Additional Information (Details) $ in Millions	6 Months Ended
	Jun. 30, 2019USD ($)
Interest rate derivative contracts
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified within twelve months	$ (9.2)
Settled Forward-Starting Interest Rate Swaps
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified within twelve months	(11.2)
Forward-Starting Interest Rate Swaps
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified within twelve months	2
Cash Flow Hedge | Futures
Derivative [Line Items]
Futures contracts for refined products	$ (0.7)

FAIR VALUE MEASUREMENTS - Asset

FAIR VALUE MEASUREMENTS - Assets and Liabilities Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value	$ 2,050	$ 17,699
Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value	0	0
Fair Value, Measurements, Recurring | Level 1 | Physical fixed-price derivative contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Financial assets	0	0
Financial liabilities	0	0
Fair Value, Measurements, Recurring | Level 1 | Physical index derivative contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Financial assets	0	0
Financial liabilities	0	0
Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value	2,050	17,699
Fair Value, Measurements, Recurring | Level 2 | Physical fixed-price derivative contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Financial assets	3,330	18,937
Financial liabilities	(1,380)	(1,389)
Fair Value, Measurements, Recurring | Level 2 | Physical index derivative contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Financial assets	140	286
Financial liabilities	$ (40)	$ (135)

FAIR VALUE MEASUREMENTS - Carry

FAIR VALUE MEASUREMENTS - Carrying Value and Fair Value of Debt (Details) - Level 2 - USD ($) $ in Thousands	Jun. 30, 2019	Dec. 31, 2018
Carrying Amount
Fair Value And Carrying Value By Balance Sheet Grouping
Total debt	$ 3,839,981	$ 4,714,442
Carrying Amount | Fixed-rate debt
Fair Value And Carrying Value By Balance Sheet Grouping
Total debt	3,273,334	3,546,396
Carrying Amount | Variable-rate debt
Fair Value And Carrying Value By Balance Sheet Grouping
Total debt	566,647	1,168,046
Fair Value
Fair Value And Carrying Value By Balance Sheet Grouping
Total debt	3,616,808	4,536,877
Fair Value | Fixed-rate debt
Fair Value And Carrying Value By Balance Sheet Grouping
Total debt	3,046,533	3,364,549
Fair Value | Variable-rate debt
Fair Value And Carrying Value By Balance Sheet Grouping
Total debt	$ 570,275	$ 1,172,328

UNIT-BASED COMPENSATION PLANS -

UNIT-BASED COMPENSATION PLANS - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
LTIP and Option Plan
Share-based Compensation Arrangement by Share-based Payment Award
Compensation expense	$ 5.8	$ 8	$ 15.7	$ 16.8
Long Term Incentive Plan 2013
Share-based Compensation Arrangement by Share-based Payment Award
LP Units, available for issuance (in shares)	1,536,149		1,536,149
Awards granted (in shares)			907,000
Long Term Incentive Plan 2013 | Phantom Stock Units | Independent directors
Share-based Compensation Arrangement by Share-based Payment Award
Awards granted (in shares)			32,247
Long Term Incentive Plan 2013 | Performance Shares | Employee
Share-based Compensation Arrangement by Share-based Payment Award
Awards granted (in shares)			345,574
Long Term Incentive Plan 2009, Deferral Plan | Phantom Stock Units
Share-based Compensation Arrangement by Share-based Payment Award
Awards granted (in shares)			528,750
Long Term Incentive Plan 2009, Deferral Plan | Phantom Stock Units | Employee
Share-based Compensation Arrangement by Share-based Payment Award
Awards granted (in shares)			158,970

UNIT-BASED COMPENSATION PLANS_2

UNIT-BASED COMPENSATION PLANS - LTIP Activity for the Period (Details) - Long Term Incentive Plan 2013 $ / shares in Units, shares in Thousands, $ in Millions	6 Months Ended
	Jun. 30, 2019USD ($)$ / sharesshares
Number of LP Units
Beginning Balance (in shares) | shares	1,645
Granted (in shares) | shares	907
Vested (in shares) | shares	(241)
Forfeited (in shares) | shares	(253)
Ending Balance (in shares) | shares	2,058
Weighted Average Grant Date Fair Value per LP Unit
Beginning Balance (in dollars per share) | $ / shares	$ 55.52
Granted (in dollars per share) | $ / shares	30.97
Vested (in dollars per share) | $ / shares	52.23
Forfeited (in dollars per share) | $ / shares	50.46
Ending Balance (in dollars per share) | $ / shares	$ 45.71
Additional disclosures
Compensation expense expected to be recognized | $	$ 38.1
Unrecognized compensation cost, weighted average period of recognition	1 year 9 months 18 days

PARTNERS' CAPITAL AND DISTRIB_3

PARTNERS' CAPITAL AND DISTRIBUTIONS - Narrative (Details) $ in Thousands	1 Months Ended		6 Months Ended
	Nov. 30, 2018shares	Mar. 30, 2018USD ($)shares	Jun. 30, 2019USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)
Partner's capital and distributions
Ownership interest			66.67%
Net proceeds from issuance of Units and exercise of Unit options			$ 0	$ 262,042
Class C Units
Partner's capital and distributions
Units issued in private placements | shares		6,200,000
Aggregate proceeds of private placement		$ 265,000
Net proceeds from issuance of Units and exercise of Unit options		$ 262,000
Issuance costs					$ 3,000
Shares converted (in shares) | shares	6,714,963
Conversion basis	1

PARTNERS' CAPITAL AND DISTRIB_4

PARTNERS' CAPITAL AND DISTRIBUTIONS - Summary of Changes in Outstanding Units (Details) shares in Thousands	6 Months Ended
	Jun. 30, 2019shares
Summary of Changes in Outstanding Units for the Period
Beginning Balance (in shares)	153,755
Ending Balance (in shares)	153,921
Long Term Incentive Plan 2013
Summary of Changes in Outstanding Units for the Period
LP units issued pursuant to the LTIP (in shares)	166

PARTNERS' CAPITAL AND DISTRIB_5

PARTNERS' CAPITAL AND DISTRIBUTIONS - Distributions (Details) - USD ($) $ / shares in Units, $ in Thousands	Aug. 19, 2019	Aug. 01, 2019	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Distributions to unitholders
Issuance of Class C Units in Lieu of quarterly cash distribution					$ 231,778	$ 372,157
Distribution per LP unit (in dollars per share)			$ 0.75	$ 1.2625	$ 1.5	$ 2.5250
Limited Partner Units
Distributions to unitholders
Issuance of Class C Units in Lieu of quarterly cash distribution					$ 232,500	$ 373,500
Distribution per LP unit (in dollars per share)					$ 1.50	$ 2.5250
Forecast | Limited Partner Units
Distributions to unitholders
Issuance of Class C Units in Lieu of quarterly cash distribution	$ 116,300
Subsequent event
Distributions to unitholders
Cash distributions declared (in dollars per share)		$ 0.75

EARNINGS PER UNIT (Details)

EARNINGS PER UNIT (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Earnings Per Share [Abstract]
Net income attributable to unitholders	$ 89,152	$ 90,665	$ 169,044	$ 201,789
Basic:
Weighted average units outstanding - basic (in shares)	153,918	153,258	153,882	151,093
Earnings per unit - basic (in dollars per share)	$ 0.58	$ 0.59	$ 1.10	$ 1.34
Diluted:
Weighted average units outstanding - basic (in shares)	153,918	153,258	153,882	151,093
Effect of dilutive securities (in shares)	824	731	757	677
Weighted average units outstanding - diluted (in shares)	154,742	153,989	154,639	151,770
Earnings per unit - diluted (in dollars per share)	$ 0.58	$ 0.59	$ 1.09	$ 1.33

BUSINESS SEGMENTS - Narrative (

BUSINESS SEGMENTS - Narrative (Details) $ in Thousands	1 Months Ended		3 Months Ended		6 Months Ended
	Feb. 28, 2019USD ($)	Jan. 31, 2019USD ($)	Jun. 30, 2019USD ($)propane_storage	Jun. 30, 2018USD ($)	Jun. 30, 2019USD ($)terminalsegmentpropane_storage	Jun. 30, 2018USD ($)	Jan. 31, 2017
Segment information
Number of business segments | segment					3
Depreciation and amortization			$ 65,859	$ 66,569	$ 129,743	$ 130,707
5.500% Notes Due August 2019
Segment information
Principal amount repaid	$ 275,000
Interest rate percentage	5.50%
Term Loan
Segment information
Principal amount repaid		$ 250,000
Domestic Pipelines & Terminals
Segment information
Number of terminals operated | terminal					3
Merchant Services
Segment information
Number of terminals owned | terminal					3
Indiana and Illinois | Domestic Pipelines & Terminals
Segment information
Number of underground propane storage caverns | propane_storage			2		2
Buckeye Texas Partners LLC
Segment information
Ownership percentage			100.00%		100.00%
Depreciation and amortization				$ 18,200		$ 36,000
VTTI B.V.
Segment information
Ownership percentage							50.00%

BUSINESS SEGMENTS - Revenue by

BUSINESS SEGMENTS - Revenue by Segment (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Revenue:
Total revenue from contracts with customers	$ 655,847	$ 783,196	$ 1,484,066	$ 1,763,458
Revenue from leases	56,859	53,954	111,185	104,777
Commodity derivative contracts, net	78,996	103,689	225,423	255,709
Total revenue	791,702	940,839	1,820,674	2,123,944
United States
Revenue:
Total revenue	740,538	878,607	1,718,318	2,000,827
International
Revenue:
Total revenue	51,164	62,232	102,356	123,117
Domestic Pipelines & Terminals
Revenue:
Total revenue from contracts with customers	234,785	239,634	470,340	489,169
Revenue from leases	10,490	11,065	20,015	19,055
Commodity derivative contracts, net	(1,694)	(819)	(5,238)	(2,909)
Total revenue	243,581	249,880	485,117	505,315
Global Marine Terminals
Revenue:
Total revenue from contracts with customers	87,846	100,254	176,900	201,506
Revenue from leases	46,511	42,889	91,464	85,722
Commodity derivative contracts, net	0	0	0	0
Total revenue	134,357	143,143	268,364	287,228
Merchant Services
Revenue:
Total revenue from contracts with customers	345,078	457,105	864,622	1,103,513
Revenue from leases	0	0	0	0
Commodity derivative contracts, net	80,690	104,508	230,661	256,528
Total revenue	425,768	561,613	1,095,283	1,360,041
Intersegment
Revenue:
Total revenue from contracts with customers	(11,862)	(13,797)	(27,796)	(30,730)
Revenue from leases	(142)	0	(294)	0
Commodity derivative contracts, net	0	0	0	2,090
Total revenue	(12,004)	(13,797)	(28,090)	(28,640)
Pipeline transportation
Revenue:
Total revenue from contracts with customers	117,294	125,796	236,838	243,627
Pipeline transportation | Domestic Pipelines & Terminals
Revenue:
Total revenue from contracts with customers	119,798	127,959	242,013	249,430
Pipeline transportation | Global Marine Terminals
Revenue:
Total revenue from contracts with customers	0	0	0	0
Pipeline transportation | Merchant Services
Revenue:
Total revenue from contracts with customers	0	0	0	0
Pipeline transportation | Intersegment
Revenue:
Total revenue from contracts with customers	(2,504)	(2,163)	(5,175)	(5,803)
Terminalling and storage services
Revenue:
Total revenue from contracts with customers	183,355	191,178	367,000	399,778
Terminalling and storage services | Domestic Pipelines & Terminals
Revenue:
Total revenue from contracts with customers	102,360	100,981	208,139	216,956
Terminalling and storage services | Global Marine Terminals
Revenue:
Total revenue from contracts with customers	87,406	99,927	175,768	201,145
Terminalling and storage services | Merchant Services
Revenue:
Total revenue from contracts with customers	0	0	0	0
Terminalling and storage services | Intersegment
Revenue:
Total revenue from contracts with customers	(6,411)	(9,730)	(16,907)	(18,323)
Product sales
Revenue:
Total revenue from contracts with customers	341,577	453,303	858,146	1,093,471
Product sales | Domestic Pipelines & Terminals
Revenue:
Total revenue from contracts with customers	0	0	0	0
Product sales | Global Marine Terminals
Revenue:
Total revenue from contracts with customers	5	7	262	20
Product sales | Merchant Services
Revenue:
Total revenue from contracts with customers	344,502	455,185	863,566	1,098,693
Product sales | Intersegment
Revenue:
Total revenue from contracts with customers	(2,930)	(1,889)	(5,682)	(5,242)
Other services
Revenue:
Total revenue from contracts with customers	13,621	12,919	22,082	26,582
Other services | Domestic Pipelines & Terminals
Revenue:
Total revenue from contracts with customers	12,627	10,694	20,188	22,783
Other services | Global Marine Terminals
Revenue:
Total revenue from contracts with customers	435	320	870	341
Other services | Merchant Services
Revenue:
Total revenue from contracts with customers	576	1,920	1,056	4,820
Other services | Intersegment
Revenue:
Total revenue from contracts with customers	$ (17)	$ (15)	$ (32)	$ (1,362)

BUSINESS SEGMENTS - Adjusted EB

BUSINESS SEGMENTS - Adjusted EBITDA from Continuing Operations (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Feb. 28, 2019	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Reconciliation of Net (loss) income to Adjusted EBITDA:
Net income		$ 90,515	$ 93,317	$ 171,775	$ 210,409
Less: Net income attributable to noncontrolling interests		(496)	(1,413)	(994)	(6,132)
Net income attributable to Buckeye Partners, L.P.		90,019	91,904	170,781	204,277
Add: Interest and debt expense		49,574	59,566	101,742	118,671
Income tax expense		297	782	595	1,272
Depreciation and amortization		65,859	66,569	129,743	130,707
Non-cash impairment on disposals of long-lived assets		911	0	3,106	0
Loss on early extinguishment of debt				4,020	0
Earnings from the equity method investment in VTTI		(2,871)	(8,265)	(6,216)	(15,754)
Adjusted EBITDA		214,343	254,853	430,741	516,577
VTTI B.V.
Reconciliation of Net (loss) income to Adjusted EBITDA:
Earnings from the equity method investment in VTTI			(4,882)		(9,272)
Segment Reconciling Items
Reconciliation of Net (loss) income to Adjusted EBITDA:
Non-cash unit-based compensation expense		5,781	7,976	15,698	16,666
Acquisition, dispositions, and transition expense		5,783	141	9,866	423
Proportionate share of Adjusted EBITDA for the equity-method investment in VTTI		0	34,640	0	69,180
Less: Gains on property damage recoveries		0	(450)	0	(14,535)
Hurricane-related costs, net of recoveries		(3,881)	(1,393)	(4,810)	(812)
Domestic Pipelines & Terminals
Reconciliation of Net (loss) income to Adjusted EBITDA:
Adjusted EBITDA		133,082	135,321	268,975	275,972
Global Marine Terminals
Reconciliation of Net (loss) income to Adjusted EBITDA:
Adjusted EBITDA		76,156	120,728	151,663	238,146
Global Marine Terminals | VTTI B.V.
Reconciliation of Net (loss) income to Adjusted EBITDA:
Earnings from the equity method investment in VTTI		0	(4,882)	0	(9,272)
Merchant Services
Reconciliation of Net (loss) income to Adjusted EBITDA:
Adjusted EBITDA		5,105	(1,196)	$ 10,103	$ 2,459
5.500% Notes Due August 2019
Reconciliation of Net (loss) income to Adjusted EBITDA:
Loss on early extinguishment of debt	$ 4,000	$ 0	$ 0

SUPPLEMENTAL CASH FLOW INFORM_3

SUPPLEMENTAL CASH FLOW INFORMATION (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Supplemental disclosures of cash flow information:
Cash paid for interest (net of capitalized interest)	$ 100,740	$ 108,405
Cash paid for income taxes	2,454	951
Capitalized interest	3,721	3,805
Cash paid for lease liabilities	12,119
Non-cash activities:
Issuance of Class C Units in Lieu of quarterly cash distribution	0	8,469
Distribution payable to noncontrolling interest	0		$ 1,432
Recognition of non-cash ROU assets and operating lease obligations (see Note 9)	150,985
Capital expenditure accruals	$ 57,707	$ 65,067