Blueknight Energy Partners (BKEP) 10-Q 2 Aug 18 2018 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	6 Months Ended
	Jun. 30, 2018	Jul. 26, 2018	Dec. 31, 2017
Entity Information [Line Items]
Series A Preferred unitholders, units outstanding	35,125,202		35,125,202
Entity Registrant Name	Blueknight Energy Partners, L.P.
Entity Central Index Key	1,392,091
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q2
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2018
Entity Common Stock, Shares Outstanding		40,387,006
Subsequent Event [Member]
Entity Information [Line Items]
Series A Preferred unitholders, units outstanding		35,125,202

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 1,193	$ 2,469
Accounts receivable, net of allowance for doubtful accounts of $28 and $29 at December 31, 2017 and June 30, 2018, respectively	31,268	7,589
Receivables from related parties, net of allowance for doubtful accounts of $0 at both dates	1,219	3,070
Prepaid insurance	2,093	2,009
Other current assets	12,716	8,438
Total current assets	48,489	23,575
Assets, Noncurrent [Abstract]
Property, plant and equipment, net of accumulated depreciation of $316,591 and $269,978 at December 31, 2017 and June 30, 2018, respectively	295,711	296,069
Assets held for sale, net of accumulated depreciation of $55,583 at June 30, 2018	16,857	0
Goodwill	6,728	3,870
Debt issuance costs, net	3,802	4,442
Intangibles and other assets, net	18,919	12,913
Total assets	390,506	340,869
Current liabilities:
Accounts payable	5,244	4,439
Accounts payable to related parties	12,878	2,268
Accrued interest payable	644	694
Accrued property taxes payable	3,365	2,432
Unearned revenue	2,039	2,393
Unearned revenue with related parties	4,384	551
Accrued payroll	3,671	6,119
Other current liabilities	17,379	4,747
Total current liabilities	49,604	23,643
Long-term unearned revenue with related parties	960	1,052
Other long-term liabilities	3,715	3,673
Long-term interest rate swap liabilities	0	225
Long-term debt	349,592	307,592
Commitments and contingencies (Note 15)
Partners’ capital:
Common unitholders (40,158,342 and 40,326,571 units issued and outstanding at December 31, 2017 and June 30, 2018, respectively)	436,416	454,358
Preferred Units (35,125,202 units issued and outstanding at both dates)	253,923	253,923
General partner interest (1.6% interest with 1,225,409 general partner units outstanding at both dates)	(703,704)	(703,597)
Total partners’ capital	(13,365)	4,684
Total liabilities and partners’ capital	$ 390,506	$ 340,869

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Current assets:
Accounts receivable, allowance for doubtful accounts	$ 29	$ 28
Receivables from related parties, allowance for doubtful accounts	0	0
Assets, Noncurrent [Abstract]
Accumulated depreciation	269,978	316,591
Accumulated Depreciation, Assets held for sale	$ (55,583)	$ 0
Partners’ capital:
Common unitholders, units issued	40,326,571	40,158,342
Common unitholders, units outstanding	40,326,571	40,158,342
Series A Preferred unitholders, units issued	35,125,202	35,125,202
Series A Preferred unitholders, units outstanding	35,125,202	35,125,202
General partner interest, units outstanding	1,225,409	1,225,409
General partner percentage interest	1.60%	1.60%

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Service revenue:
Third-party revenue	$ 14,103	$ 28,145	$ 31,421	$ 56,808
Related-party revenue	6,063	13,505	12,384	27,147
Lease revenue:
Third-party revenue	10,237	0	20,041	0
Related-party revenue	7,475	0	15,178	0
Product sales revenue:
Third-party revenue	45,615	2,227	49,129	6,262
Total revenue	83,493	43,877	128,153	90,217
Costs and expenses:
Operating expense	28,988	30,610	60,123	62,516
Third-party cost of product sales	20,041	1,669	22,678	4,808
Related-party cost of product sales	23,747	0	23,747	0
General and administrative expense	4,486	4,322	8,707	8,907
Asset impairment expense	0	17	616	45
Total costs and expenses	77,262	36,618	115,871	76,276
Gain (loss) on sale of assets	599	(754)	363	(879)
Operating income	6,830	6,505	12,645	13,062
Other income (expenses):
Equity earnings in unconsolidated affiliate	0	0	0	61
Gain on sale of unconsolidated affiliate	0	4,172	2,225	4,172
Interest expense (net of capitalized interest of $3, $43, $5 and $72, respectively)	(5,024)	(4,265)	(8,593)	(7,295)
Income before income taxes	1,806	6,412	6,277	10,000
Provision for income taxes	21	41	50	87
Net income	1,785	6,371	6,227	9,913
Allocation of net income for calculation of earnings per unit:
General partner interest in net income	28	256	259	465
Preferred interest in net income	6,279	6,279	12,557	12,558
Net loss available to limited partners	$ (4,522)	$ (164)	$ (6,589)	$ (3,110)
Basic and diluted net loss per common unit	$ (0.11)	$ 0	$ (0.16)	$ (0.08)
Weighted average common units outstanding - basic and diluted	40,324	38,155	40,306	38,151

CONSOLIDATED STATEMENTS OF OPE5

CONSOLIDATED STATEMENTS OF OPERATIONS CONSOLIDATED STATEMENT OF OPERATIONS (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Income Statement [Abstract]
Capitalized interest	$ 43	$ 3	$ 72	$ 5

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL - 6 months ended Jun. 30, 2018 - USD ($) $ in Thousands	Total	Limited Partner [Member]	General Partner [Member]	Preferred Partner [Member]
Balance at Dec. 31, 2017	$ 4,684	$ 454,358	$ (703,597)	$ 253,923
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	6,227	(6,745)	415	12,557
Equity-based incentive compensation	687	669	18
Distributions	(25,238)	(11,958)	(723)	(12,557)
Capital contributions	183		183
Proceeds from sale of 21,246 common units pursuant to the Employee Unit Purchase Plan	92	92
Balance at Jun. 30, 2018	$ (13,365)	$ 436,416	$ (703,704)	$ 253,923

CONSOLIDATED STATEMENTS OF CHA7

CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL (Parenthetical)	6 Months Ended
	Jun. 30, 2018shares
Changes in Partners Capital [Abstract]
Units Issued, Unit Based Compensation	21,246

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Cash flows from operating activities:
Net income	$ 6,227	$ 9,913
Adjustments to reconcile net income to net cash provided by operating activities:
Provision for uncollectible receivables from third parties	1	(12)
Depreciation and amortization	14,779	15,905
Amortization and write-off of debt issuance costs	949	1,307
Unrealized gain related to interest rate swaps	(314)	(975)
Intangible asset impairment charge	189	0
Fixed asset impairment charge	427	45
Loss (gain) on sale of assets	(363)	879
Gain on sale of unconsolidated affiliate	(2,225)	(4,172)
Equity-based incentive compensation	687	524
Equity earnings in unconsolidated affiliate	0	(61)
Changes in assets and liabilities:
Increase in accounts receivable	(23,680)	(1,785)
Decrease in receivables from related parties	1,851	326
Decrease in prepaid insurance	1,494	1,194
Decrease (increase) in other current assets	(2,920)	148
Decrease in other non-current assets	90	111
Increase (decrease) in accounts payable	(502)	183
Increase in payables to related parties	10,504	156
Increase (decrease) in accrued interest payable	(50)	316
Increase in accrued property taxes	933	232
Increase (decrease) in unearned revenue	(346)	1,352
Increase in unearned revenue from related parties	3,679	3,953
Decrease in accrued payroll	(2,448)	(2,017)
Increase (decrease) in other accrued liabilities	12,113	(961)
Net cash provided by operating activities	21,075	26,561
Cash flows from investing activities:
Acquisitions	(21,959)	0
Capital expenditures	(22,125)	(10,331)
Proceeds from sale of assets	3,893	8,474
Proceeds from sale of unconsolidated affiliate	2,225	25,324
Net cash provided by (used in) investing activities	(37,966)	23,467
Cash flows from financing activities:
Payment on insurance premium financing agreement	(1,113)	(1,271)
Debt issuance costs	(309)	(4,017)
Borrowings under credit agreement	113,000	335,592
Payments under credit agreement	71,000	356,000
Proceeds from equity issuance	92	84
Capital contributions	183	104
Distributions	(25,238)	(24,550)
Net cash provided by (used in) financing activities	15,615	(50,058)
Net decrease in cash and cash equivalents	(1,276)	(30)
Cash and cash equivalents at beginning of period	2,469	3,304
Cash and cash equivalents at end of period	1,193	3,274
Supplemental disclosure of non-cash financing and investing cash flow information:
Non-cash changes in property, plant and equipment	294	1,545
Increase in accrued liabilities related to insurance premium financing agreement	$ 1,578	$ 2,281

ORGANIZATION AND NATURE OF BUSI

ORGANIZATION AND NATURE OF BUSINESS	6 Months Ended
	Jun. 30, 2018
ORGANIZATION AND NATURE OF BUSINESS [Abstract]
ORGANIZATION AND NATURE OF BUSINESS	ORGANIZATION AND NATURE OF BUSINESS Blueknight Energy Partners, L.P. and subsidiaries (collectively, the “Partnership”) is a publicly traded master limited partnership with operations in 27 states. The Partnership provides integrated terminalling, gathering, transportation and marketing services for companies engaged in the production, distribution and marketing of crude oil and asphalt products. The Partnership manages its operations through four operating segments: (i) asphalt terminalling services, (ii) crude oil terminalling services, (iii) crude oil pipeline services and (iv) crude oil trucking services. On April 24, 2018, the Partnership sold the producer field services business. As a result of the sale of the producer field services business, the Partnership changed the name of the crude oil trucking and producer field services operating segment to crude oil trucking services during the second quarter of 2018. See Note 6 for additional information. The Partnership’s common units and preferred units, which represent limited partnership interests in the Partnership, are listed on the NASDAQ Global Market under the symbols “BKEP” and “BKEPP,” respectively. The Partnership was formed in February 2007 as a Delaware master limited partnership initially to own, operate and develop a diversified portfolio of complementary midstream energy assets.

BASIS OF CONSOLIDATION AND PRES

BASIS OF CONSOLIDATION AND PRESENTATION	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
BASIS OF CONSOLIDATION AND PRESENTATION	BASIS OF CONSOLIDATION AND PRESENTATION The financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The condensed consolidated balance sheet as of June 30, 2018 , the condensed consolidated statements of operations for the three and six months ended June 30, 2017 and 2018 , the condensed consolidated statement of changes in partners’ capital (deficit) for the six months ended June 30, 2018 and the condensed consolidated statements of cash flows for the six months ended June 30, 2017 and 2018 , are unaudited. In the opinion of management, the unaudited condensed consolidated financial statements have been prepared on the same basis as the audited financial statements and include all adjustments necessary to state fairly the financial position and results of operations for the respective interim periods. All adjustments are of a recurring nature unless otherwise disclosed herein. The 2017 year-end condensed consolidated balance sheet data was derived from audited financial statements but does not include all disclosures required by GAAP. These unaudited condensed consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and notes thereto included in the Partnership’s annual report on Form 10-K for the year ended December 31, 2017 , filed with the Securities and Exchange Commission (the “SEC”) on March 8, 2018 (the “ 2017 Form 10-K”). Interim financial results are not necessarily indicative of the results to be expected for an annual period. The Partnership’s significant accounting policies are consistent with those disclosed in Note 3 of the Notes to Consolidated Financial Statements in its 2017 Form 10-K. The Partnership’s investment in Advantage Pipeline, L.L.C. (“Advantage Pipeline”), over which the Partnership had significant influence but not control, was accounted for by the equity method. The Partnership did not consolidate any part of the assets or liabilities of its equity investee. The Partnership’s share of net income or loss is reflected as one line item on the Partnership’s unaudited condensed consolidated statements of operations entitled “Equity earnings in unconsolidated affiliate” and increased or decreased, as applicable, the carrying value of the Partnership’s “Investment in unconsolidated affiliate” on the unaudited condensed consolidated balance sheets. Distributions to the Partnership reduced the carrying value of its investment and, to the extent received, were reflected in the Partnership’s unaudited condensed consolidated statements of cash flows in the line item “Distributions from unconsolidated affiliate.” Contributions increased the carrying value of the Partnership’s investment and were reflected in the Partnership’s unaudited condensed consolidated statements of cash flows in investing activities. On April 3, 2017, the Partnership sold its investment in Advantage Pipeline. See Note 5 for additional information.

REVENUE REVENUE

REVENUE REVENUE	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers [Text Block]	REVENUE Revenue from Contracts with Customers On January 1, 2018, the Partnership adopted the new accounting standard ASC 606 - Revenue from Contracts with Customers and all related amendments (“new revenue standard”) using the modified retrospective method, and as a result applied the new guidance only to contracts that are not completed at the adoption date. Results for reporting periods beginning on January 1, 2018, are presented under the new revenue standard, while prior period amounts are not adjusted and continue to be reported in accordance with the Partnership’s historic accounting under ASC 605 - Revenue Recognition . The majority of the Partnership’s service revenue continues to be recognized as services are performed. Under the new revenue standard, the timing of revenue recognition on variable throughput fees will change, within a single reporting year, compared to the previous recognition. The effect will be straight-line recognition of unconstrained estimated annual throughput volumes over each contract year. See further discussion on variable throughput fees below. In addition, as a result of the adoption of the new revenue standard, revenue from leases is required to be presented separately from revenue from customers. As the Partnership applied the modified retrospective method, prior periods have not been reclassified. Upon adoption of the new revenue standard, there was no cumulative adjustment to the balance sheet at January 1, 2018. Adoption of the new revenue standard resulted in recognition of an additional $0.2 million and $0.3 million of “Service revenue - Third-party revenue” in the unaudited condensed consolidated statements of operations for the three and six months ended June 30, 2018 , respectively, and additional “Accounts receivable” of $0.3 million on the unaudited condensed consolidated balance sheet as of June 30, 2018 , over what would have been recorded under ASC 605. While some revenue under storage, throughput and handling contracts in the asphalt terminalling segment will shift between quarters within a fiscal year, the impact of adoption of the new revenue standard is not expected to be material to net income on an ongoing basis because the analysis of contracts under the new revenue standard supports the recognition of revenue as services are performed, which is consistent with the previous revenue recognition model. There are two types of contracts in the asphalt terminalling segment: (i) operating lease contracts, under which customers operate the facilities, and (ii) storage, throughput and handling contracts, under which the Partnership operates the facilities. The operating lease contracts are accounted for in accordance with ASC 840 - Leases . The storage, throughput and handling contracts contain both lease revenue and non-lease service revenue. In accordance with ASC 840 and 606, fixed consideration is allocated to the lease and service components based on their relative stand-alone selling price. The stand-alone selling price of the lease component is calculated using the average internal rate of return under the operating lease agreements. The stand-alone selling price of the service component is calculated by applying an appropriate margin to the expected costs to operate the facility. The service component contains a single performance obligation that consists of a stand-ready obligation to perform activities as directed by the customer. Revenue is recognized on a straight-line basis over time as the customer receives and consumes benefits. Fixed consideration, consisting of the monthly storage and handling fees, is billed a month prior to the performance of services and is due by the first day of the month of service. Payments received in advance of the month of service are recorded as unearned revenue (contract liability) until the service is performed. Asphalt storage, throughput and handling contracts also contain variable consideration in the form of reimbursements of utility, fuel and power expenses and throughput fees. Utility, fuel and power reimbursements are allocated entirely to the service component of the contracts. Utility, fuel and power reimbursements relate directly to the distinct monthly service that makes up the overall performance obligation and revenue is recognized in the period in which the service takes place. Variable consideration related to reimbursements of utility, fuel and power expenses is billed in the month subsequent to the period of service, and payment is due within 30 days of billing. Throughput fees are allocated to both the lease and service component of the contracts using the allocation percentages from contract inception. Total throughput fees are estimated at contract inception and updated at the beginning of each reporting period based on historical trends, current year throughput activities at the facilities, and analysis with customers regarding expectations for the current year. This consideration can be constrained when there is a lack of historical data or other uncertainties exist regarding expected throughput volumes. The service component of throughput fees is recognized on a straight-line basis over time as the customer receives and consumes benefits. In accordance with ASC 840, the lease component of variable throughput fees is recognized in the period when the changes in facts and circumstances on which the variable payment is based occur. Fees related to actual throughput are billed in the month subsequent to the period of movement, which can result in the recognition of un-billed accounts receivable (contract assets) when there is a variance in the straight-line revenue recognition and actual throughput fees billed. Payment on variable throughput consideration is due within 30 days of billing. Changes in estimated throughput fees affect the total transaction price and will be recorded as an adjustment to revenue in the period in which the change is identified. The Partnership recorded a $0.1 million adjustment related to changes in estimated throughput fees for both the three and six months ended June 30, 2018 . Certain asphalt storage, throughput and handling contracts contain provisions for reimbursement of specified major maintenance costs above a specified threshold over the life of the contract. Reimbursements of specified major maintenance costs are allocated to both the lease and service component of the contracts using the allocation percentages from contract inception. Reimbursements of specified major maintenance costs are reviewed and paid quarterly, which may result in overpayments that must be paid back to the customer in future years. As such, the service component of this consideration is constrained and recorded in unearned revenue (contract liability) until facts and circumstances indicate it is probable that the minimum threshold will be met. In the event the minimum threshold is not met, the Partnership will return the reimbursement to the customer. As of June 30, 2018 , the Partnership has performance obligations satisfied over time under asphalt storage, throughput and handling contracts that are wholly or partially unsatisfied. The revenue related to these performance obligations will be recognized as follows (in thousands): Revenue Related to Future Performance Obligations Due by Period (1) Less than 1 year $ 35,257 1-3 years 64,767 4-5 years 46,024 More than 5 years 13,591 Total revenue related to future performance obligations $ 159,639 ____________________ (1) Excluded from the table is revenue that is either constrained or related to performance obligations that are wholly unsatisfied as of June 30, 2018 . Crude oil terminalling services contracts can be either short- or long-term written contracts. The contracts contain a single performance obligation that consists of a series of distinct services provided over time. Customers are billed a month prior to the performance of terminalling services and payment is due by the first day of the month of service. Payments received in advance of the month of service are recorded as unearned revenue (contract liability) until the service is performed. These contracts also contain provisions under which customers are invoiced for product throughput in the month following the month in which the service is provided. Payment on product throughput is due within 30 days . The Partnership has elected to use the right-to-invoice expedient on crude oil terminalling services contracts as the right to consideration corresponds directly with the value to the customer of performance completed to date. There are primarily two types of contracts in the crude oil pipeline segment: (i) monthly transportation contracts and (ii) product sales contracts. Under crude oil pipeline services monthly transportation contracts, customers submit nominations for transportation monthly and a contract is created upon the Partnership’s acceptance of the nomination under its published tariffs. Crude oil pipeline services contracts have a single performance obligation to perform the transportation service. The transportation service is provided to the customer in the same month in which the customer makes the related nomination. Revenue is recorded in the month of service and invoiced in the following month. Payment is due within 30 days . The Partnership has elected to use the right-to-invoice expedient on crude oil pipeline services contracts as the right to consideration corresponds directly with the value to the customer of performance completed to date. The Partnership also purchases crude oil and resells to third parties under written product sales contracts. Product sales contracts have a single performance obligation, and revenue is recognized at the point in time that control is transferred to the customer. Control is considered transferred to the customer on the day of the sale. Revenue is recorded in the month of service and invoiced in the following month. Payment is due within 30 days . The Partnership has elected to use the right-to-invoice expedient on product sales contracts as the right to consideration corresponds directly with the value to the customer of performance completed to date. Services in the crude oil trucking segment are provided under master service agreements with customers that include rate sheets. Contracts are initiated when a customer requests service and both parties are committed upon the Partnership’s acceptance of the customer’s request. Crude oil trucking contracts have a single performance obligation to perform the service, which is completed in a day. Revenue is recorded in the month of service and invoiced in the following month. Payment is due within 30 days . The Partnership has elected to use the right-to-invoice expedient on crude oil trucking revenues as the right to consideration corresponds directly with the value to the customer of performance completed to date. Disaggregation of Revenue Disaggregation of revenue from contracts with customers for each operating segment by revenue type is presented as follows (in thousands): Three Months ended June 30, 2018 Asphalt Terminalling Services Crude Oil Terminalling Services Crude Oil Pipeline Services Crude Oil Trucking Services Total Third-party revenue: Fixed storage, throughput and other revenue $ 4,622 $ 2,767 $ — $ — $ 7,389 Variable throughput revenue 242 143 — — 385 Variable reimbursement revenue 1,775 — — — 1,775 Crude oil transportation revenue — — 1,045 3,509 4,554 Crude oil product sales revenue — — 45,612 3 45,615 Related-party revenue: Fixed storage, throughput and other revenue 4,632 — 48 — 4,680 Variable reimbursement revenue 1,349 — 34 — 1,383 Total revenue from contracts with customers $ 12,620 $ 2,910 $ 46,739 $ 3,512 $ 65,781 Six Months ended June 30, 2018 Asphalt Terminalling Services Crude Oil Terminalling Services Crude Oil Pipeline Services Crude Oil Trucking Services Total Third-party revenue: Fixed storage, throughput and other revenue $ 8,171 $ 6,849 $ — $ — $ 15,020 Variable throughput revenue 359 647 — — 1,006 Variable reimbursement revenue 3,241 — — — 3,241 Crude oil transportation revenue — — 3,105 9,049 12,154 Crude oil product sales revenue — — 49,120 9 49,129 Related-party revenue: Fixed storage, throughput and other revenue 9,263 — 48 — 9,311 Variable reimbursement revenue 3,039 — 34 — 3,073 Total revenue from contracts with customers $ 24,073 $ 7,496 $ 52,307 $ 9,058 $ 92,934 Contract Balances The timing of revenue recognition, billings and cash collections result in billed accounts receivable, un-billed accounts receivable (contract assets) and unearned revenue (contract liabilities) on the unaudited condensed consolidated balance sheet as noted in the contract discussions above. Accounts receivable and un-billed accounts receivable are both reflected in the line items “Accounts receivable” and “Receivables from related parties” on the unaudited condensed consolidated balance sheet. Unearned revenue is included in the line items “Unearned revenue,” “Unearned revenue with related parties,” “Long-term unearned revenue with related parties” and “Other long-term liabilities” on the unaudited condensed consolidated balance sheet. Billed accounts receivable from contracts with customers were $8.5 million and $27.9 million at December 31, 2017 , and June 30, 2018 , respectively. Un-billed accounts receivable from contracts with customers were $0.3 million at June 30, 2018 . There were no un-billed accounts receivable at December 31, 2017 . The Partnership records unearned revenues when cash payments are received in advance of performance. Unearned revenue related to contracts with customers was $3.7 million and $4.6 million at December 31, 2017 , and June 30, 2018 , respectively. The change in the unearned revenue balance for the six months ended June 30, 2018 , is driven by $2.5 million in cash payments received in advance of satisfying performance obligations, partially offset by $1.6 million of revenues recognized that were included in the unearned revenue balance at the beginning of the period. Practical Expedients and Exemptions The Partnership does not disclose the value of unsatisfied performance obligations for (i) contracts with an original expected length of one year or less and (ii) contracts for which revenue is recognized at the amount to which the Partnership has the right to invoice for services performed. The Partnership is using the right-to-invoice practical expedient on all contracts with customers in its crude oil terminalling services, crude oil pipeline services and crude oil trucking services segments.

RESTRUCTURING CHARGES RESTRUCTU

RESTRUCTURING CHARGES RESTRUCTURING CHARGES	6 Months Ended
	Jun. 30, 2018
Restructuring and Related Activities [Abstract]
Restructuring and Related Activities Disclosure [Text Block]	RESTRUCTURING CHARGES During the fourth quarter of 2015, the Partnership recognized certain restructuring charges in its crude oil trucking services segment pursuant to an approved plan to exit the trucking market in West Texas. The restructuring charges included an accrual related to leased vehicles that were idled as part of the restructuring plan. This accrual was being amortized over the remaining lease term of the vehicles. In June 2018, the Partnership purchased the vehicles off lease and resold them to a third party, paying off the remaining liability. Changes in the accrued amounts pertaining to the restructuring charges are summarized as follows (in thousands): Three Months ended Six Months ended 2017 2018 2017 2018 Beginning balance $ 428 $ 237 $ 474 $ 286 Cash payments 46 237 92 286 Ending balance $ 382 $ — $ 382 $ —

EQUITY METHOD INVESTMENT EQUITY

EQUITY METHOD INVESTMENT EQUITY METHOD INVESTMENT	6 Months Ended
	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments and Joint Ventures Disclosure [Text Block]	EQUITY METHOD INVESTMENT On April 3, 2017, Advantage Pipeline was acquired by a joint venture formed by affiliates of Plains All American Pipeline, L.P. and Noble Midstream Partners LP. The Partnership received cash proceeds at closing from the sale of its approximate 30% equity ownership interest in Advantage Pipeline of approximately $25.3 million and recorded a gain on the sale of the investment of $4.2 million . Approximately 10% of the gross sale proceeds were held in escrow, subject to certain post-closing settlement terms and conditions. The Partnership received approximately $1.1 million of the funds held in escrow in August 2017, and approximately $2.2 million for its pro rata portion of the remaining net escrow proceeds in January 2018. The Partnership’s proceeds were used to prepay revolving debt (without a commitment reduction). The operating and administrative services agreement to which the Partnership and Advantage Pipeline were parties and under which the Partnership operated the 70-mile, 16-inch Advantage crude oil pipeline, located in the southern Delaware Basin in Texas, was terminated at closing. The Partnership and the Plains/Noble joint venture entered into a short-term transition services agreement under which the Partnership provided certain services through August 1, 2017. Summarized financial information for Advantage Pipeline is set forth in the tables below for the period indicated in which the Partnership held the investment in Advantage Pipeline (in thousands): Period ended April 3, 2017 Income Statement Operating revenues $ 3,150 Operating expenses $ 465 Net income $ 187

PROPERTY, PLANT AND EQUIPMENT

PROPERTY, PLANT AND EQUIPMENT	6 Months Ended
	Jun. 30, 2018
Property, Plant and Equipment [Abstract]
PROPERTY, PLANT AND EQUIPMENT	PROPERTY, PLANT AND EQUIPMENT Estimated Useful Lives (Years) December 31, 2017 June 30, (dollars in thousands) Land N/A $ 24,776 $ 25,067 Land improvements 10-20 6,787 5,815 Pipelines and facilities 5-30 166,004 167,624 Storage and terminal facilities 10-35 370,056 319,344 Transportation equipment 3-10 3,293 1,056 Office property and equipment and other 3-20 32,011 26,958 Pipeline linefill and tank bottoms N/A 3,233 11,694 Construction-in-progress N/A 6,500 8,131 Property, plant and equipment, gross 612,660 565,689 Accumulated depreciation (316,591 ) (269,978 ) Property, plant and equipment, net $ 296,069 $ 295,711 Depreciation expense for the three months ended June 30, 2017 and 2018 , was $7.5 million and $6.7 million , respectively. Depreciation expense for the six months ended June 30, 2017 and 2018 , was $15.3 million and $13.7 million , respectively. In April 2018, the Partnership sold its producer field services business. The Partnership received cash proceeds at closing of approximately $3.0 million and recorded a gain of $0.4 million . The sale of the producer field services business does not qualify as discontinued operations as it does not represent a strategic shift that will have a major effect on the Partnership’s operations or financial results. In March 2018, the Partnership acquired an asphalt terminalling facility in Oklahoma from a third party for approximately $22.0 million , consisting of property, plant and equipment of $11.5 million , intangible assets of $7.6 million and goodwill of $2.9 million . On December 1, 2017, the Partnership issued 1.9 million common units to Ergon in a private placement valued at $10.2 million in exchange for an asphalt terminalling facility in Bainbridge, Georgia. In April 2017, the Partnership sold its East Texas pipeline system. The Partnership received cash proceeds at closing of approximately $4.8 million and recorded a gain of less than $0.1 million . The Partnership used the proceeds received at closing to prepay revolving debt (without a commitment reduction).

DEBT

DEBT	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
DEBT	DEBT On May 11, 2017, the Partnership entered into an amended and restated credit agreement. On June 28, 2018, the credit agreement was amended to, among other things, reduce the revolving loan facility from $450.0 million to $400.0 million and amend the maximum permitted consolidated total leverage ratio as discussed below. As of July 26, 2018 , approximately $263.6 million of revolver borrowings and $3.4 million of letters of credit were outstanding under the credit agreement, leaving the Partnership with approximately $133.0 million available capacity for additional revolver borrowings and letters of credit under the credit agreement, although the Partnership’s ability to borrow such funds may be limited by the financial covenants in the credit agreement. The proceeds of loans made under the credit agreement may be used for working capital and other general corporate purposes of the Partnership. The credit agreement is guaranteed by all of the Partnership’s existing subsidiaries. Obligations under the credit agreement are secured by first priority liens on substantially all of the Partnership’s assets and those of the guarantors. The credit agreement includes procedures for additional financial institutions to become revolving lenders, or for any existing lender to increase its revolving commitment thereunder, subject to an aggregate maximum of $600.0 million for all revolving loan commitments under the credit agreement. The credit agreement will mature on May 11, 2022 , and all amounts outstanding under the credit agreement will become due and payable on such date. The credit agreement requires mandatory prepayments of amounts outstanding thereunder with the net proceeds of certain asset sales, property or casualty insurance claims and condemnation proceedings, unless the Partnership reinvests such proceeds in accordance with the credit agreement, but these mandatory prepayments will not require any reduction of the lenders’ commitments under the credit agreement. Borrowings under the credit agreement bear interest, at the Partnership’s option, at either the reserve-adjusted eurodollar rate (as defined in the credit agreement) plus an applicable margin that ranges from 2.0% to 3.0% or the alternate base rate (the highest of the agent bank’s prime rate, the federal funds effective rate plus 0.5% , and the 30-day eurodollar rate plus 1.0% ) plus an applicable margin that ranges from 1.0% to 2.0% . The Partnership pays a per annum fee on all letters of credit issued under the credit agreement, which fee equals the applicable margin for loans accruing interest based on the eurodollar rate, and the Partnership pays a commitment fee ranging from 0.375% to 0.5% on the unused commitments under the credit agreement. The applicable margins for the Partnership’s interest rate, the letter of credit fee and the commitment fee vary quarterly based on the Partnership’s consolidated total leverage ratio (as defined in the credit agreement, being generally computed as the ratio of consolidated total debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges). The credit agreement includes financial covenants that are tested on a quarterly basis, based on the rolling four-quarter period that ends on the last day of each fiscal quarter. Prior to the date on which the Partnership issues qualified senior notes in an aggregate principal amount (when combined with all other qualified senior notes previously or concurrently issued) that equals or exceeds $200.0 million , the maximum permitted consolidated total leverage ratio is 4.75 to 1.00; provided that: • the maximum permitted consolidated total leverage ratio will be 5.50 to 1.00 for the fiscal quarters ending June 30, 2018, through December 31, 2018; 5.25 to 1.00 for the fiscal quarters ending March 31, 2019, and June 30, 2019; 5.00 to 1.00 for the fiscal quarters ending September 30, 2019, and December 31, 2019; and 4.75 to 1.00 for the fiscal quarter ending March 31, 2020, and each fiscal quarter thereafter; and • based on the occurrence of a specified acquisition (as defined in the credit agreement, but generally being an acquisition for which the aggregate consideration is $15.0 million or more), the maximum permitted consolidated total leverage ratio may be increased to 5.25 to 1.00 for the fiscal quarter ending March 31, 2020, and for certain fiscal quarters thereafter. From and after the date on which the Partnership issues qualified senior notes in an aggregate principal amount (when combined with all other qualified senior notes previously or concurrently issued) that equals or exceeds $200.0 million , the maximum permitted consolidated total leverage ratio is 5.00 to 1.00; provided that from and after the fiscal quarter ending immediately preceding the fiscal quarter in which a specified acquisition occurs to and including the last day of the second full fiscal quarter following the fiscal quarter in which such acquisition occurred, the maximum permitted consolidated total leverage ratio will be 5.50 to 1.00. The maximum permitted consolidated senior secured leverage ratio (as defined in the credit agreement, but generally computed as the ratio of consolidated total secured debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges) is 3.50 to 1.00, but this covenant is only tested from and after the date on which the Partnership issues qualified senior notes in an aggregate principal amount (when combined with all other qualified senior notes previously or concurrently issued) that equals or exceeds $200.0 million . The minimum permitted consolidated interest coverage ratio (as defined in the credit agreement, but generally computed as the ratio of consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges to consolidated interest expense) is 2.50 to 1.00. In addition, the credit agreement contains various covenants that, among other restrictions, limit the Partnership’s ability to: • create, issue, incur or assume indebtedness; • create, incur or assume liens; • engage in mergers or acquisitions; • sell, transfer, assign or convey assets; • repurchase the Partnership’s equity, make distributions to unitholders and make certain other restricted payments; • make investments; • modify the terms of certain indebtedness, or prepay certain indebtedness; • engage in transactions with affiliates; • enter into certain hedging contracts; • enter into certain burdensome agreements; • change the nature of the Partnership’s business; and • make certain amendments to the Partnership’s partnership agreement. At June 30, 2018 , the Partnership’s consolidated total leverage ratio was 4.65 to 1.00 and the consolidated interest coverage ratio was 3.78 to 1.00. The Partnership was in compliance with all covenants of its credit agreement as of June 30, 2018 . The credit agreement permits the Partnership to make quarterly distributions of available cash (as defined in the Partnership’s partnership agreement) to unitholders so long as no default or event of default exists under the credit agreement on a pro forma basis after giving effect to such distribution, provided, however, commencing with the fiscal quarter ending September 30, 2018, in no event shall aggregate quarterly distributions in any individual fiscal quarter exceed $10.7 million through, and including, the fiscal quarter ending December 31, 2019. The Partnership is currently allowed to make distributions to its unitholders in accordance with this covenant; however, the Partnership will only make distributions to the extent it has sufficient cash from operations after establishment of cash reserves as determined by the Board of Directors (the “Board”) of Blueknight Energy Partners G.P., L.L.C (the “general partner”) in accordance with the Partnership’s cash distribution policy, including the establishment of any reserves for the proper conduct of the Partnership’s business. See Note 9 for additional information regarding distributions. In addition to other customary events of default, the credit agreement includes an event of default if: (i) the general partner ceases to own 100% of the Partnership’s general partner interest or ceases to control the Partnership; (ii) Ergon, Inc. (“Ergon”) ceases to own and control 50% or more of the membership interests of the general partner; or (iii) during any period of 12 consecutive months, a majority of the members of the Board of the general partner ceases to be composed of individuals: (A) who were members of the Board on the first day of such period; (B) whose election or nomination to the Board was approved by individuals referred to in clause (A) above constituting at the time of such election or nomination at least a majority of the Board; or (C) whose election or nomination to the Board was approved by individuals referred to in clauses (A) and (B) above constituting at the time of such election or nomination at least a majority of the Board, provided that any changes to the composition of individuals serving as members of the Board approved by Ergon will not cause an event of default. If an event of default relating to bankruptcy or other insolvency events occurs with respect to the general partner or the Partnership, all indebtedness under the credit agreement will immediately become due and payable. If any other event of default exists under the credit agreement, the lenders may accelerate the maturity of the obligations outstanding under the credit agreement and exercise other rights and remedies. In addition, if any event of default exists under the credit agreement, the lenders may commence foreclosure or other actions against the collateral. If any default occurs under the credit agreement, or if the Partnership is unable to make any of the representations and warranties in the credit agreement, the Partnership will be unable to borrow funds or to have letters of credit issued under the credit agreement. Upon the execution of the amended and restated credit agreement in May 2017, the Partnership expensed $0.7 million of debt issuance costs related to the prior revolving loan facility, leaving a remaining balance of $0.9 million ascribed to those lenders with commitments under both the prior and the amended and restated credit agreement. Additionally, due to the reduction in available borrowing capacity, the Partnership expensed $0.4 million of debt issuance costs upon the execution of the first amendment to its credit agreement in June 2018. The Partnership capitalized $4.0 million of debt issuance costs during each of the three and six months ended June 30, 2017 , and capitalized $0.3 million of debt issuance costs during each of the three and six months ended June 30, 2018 . Debt issuance costs are being amortized over the term of the credit agreement. Interest expense related to debt issuance cost amortization for each of the three months ended June 30, 2017 and 2018 , was $0.3 million . Interest expense related to debt issuance cost amortization for the six months ended June 30, 2017 and 2018 , was $0.6 million and $0.5 million , respectively. During the three months ended June 30, 2017 and 2018 , the weighted average interest rate under the Partnership’s credit agreement, excluding the $0.7 million and $0.4 million , respectively, of debt issuance costs that were expensed as described above, was 4.44% and 5.39% , respectively, resulting in interest expense of approximately $3.4 million and $4.7 million , respectively. During the six months ended June 30, 2017 and 2018 , the weighted average interest rate under the Partnership’s credit agreement, excluding the $0.7 million and $0.4 million , respectively, of debt issuance costs that were expensed as described above, was 4.27% and 5.18% , respectively, resulting in interest expense of approximately $6.7 million and $8.6 million , respectively. During each of the three months ended June 30, 2017 and 2018 , the Partnership capitalized interest of less than $0.1 million . During the six months ended June 30, 2017 and 2018 , the Partnership capitalized interest of less than $0.1 million and $0.1 million , respectively. The Partnership is exposed to market risk for changes in interest rates related to its credit agreement. Interest rate swap agreements are used to manage a portion of the exposure related to changing interest rates by converting floating-rate debt to fixed-rate debt. As of December 31, 2017 , and June 30, 2018 , the Partnership had interest rate swap agreements with notional amounts totaling $200.0 million and $100.0 million , respectively, to hedge the variability of its LIBOR-based interest payments. An interest rate swap agreement with a notional amount of $100.0 million expired on June 28, 2018. Interest rate swap agreements with notional amounts totaling $100.0 million will mature on January 28, 2019. During the three months ended June 30, 2017 and 2018 , the Partnership recorded swap interest expense of $0.4 million and $0.1 million , respectively. During the six months ended June 30, 2017 and 2018 , the Partnership recorded swap interest expense of $0.8 million and less than $0.1 million , respectively. The interest rate swaps do not receive hedge accounting treatment under ASC 815 - Derivatives and Hedging . The following provides information regarding the Partnership’s assets and liabilities related to its interest rate swap agreements as of the periods indicated (in thousands): Derivatives Not Designated as Hedging Instruments Balance Sheet Location Fair Value of Derivatives December 31, 2017 June 30, Interest rate swap assets - current Other current assets $ 68 $ 157 Interest rate swap liabilities - noncurrent Long-term interest rate swap liabilities $ 225 $ — Changes in the fair value of the interest rate swaps are reflected in the unaudited condensed consolidated statements of operations as follows (in thousands): Derivatives Not Designated as Hedging Instruments Location of Gain (Loss) Recognized in Net Income on Derivatives Amount of Gain (Loss) Recognized in Net Income on Derivatives Three Months ended Six Months ended 2017 2018 2017 2018 Interest rate swaps Interest expense, net of capitalized interest $ 223 $ (40 ) $ 975 $ 314

NET INCOME PER LIMITED PARTNER

NET INCOME PER LIMITED PARTNER UNIT	6 Months Ended
	Jun. 30, 2018
Earnings Per Share [Abstract]
NET INCOME PER LIMITED PARTNER UNIT	NET INCOME PER LIMITED PARTNER UNIT For purposes of calculating earnings per unit, the excess of distributions over earnings or excess of earnings over distributions for each period are allocated to the Partnership’s general partner based on the general partner’s ownership interest at the time. The following sets forth the computation of basic and diluted net income per common unit (in thousands, except per unit data): Three Months ended Six Months ended 2017 2018 2017 2018 Net income $ 6,371 $ 1,785 $ 9,913 $ 6,227 General partner interest in net income 256 28 465 259 Preferred interest in net income 6,279 6,279 12,558 12,557 Net loss available to limited partners $ (164 ) $ (4,522 ) $ (3,110 ) $ (6,589 ) Basic and diluted weighted average number of units: Common units 38,155 40,324 38,151 40,306 Restricted and phantom units 923 1,133 806 983 Total units 39,078 41,457 38,957 41,289 Basic and diluted net loss per common unit $ — $ (0.11 ) $ (0.08 ) $ (0.16 )

PARTNERS' CAPITAL AND DISTRIBUT

PARTNERS' CAPITAL AND DISTRIBUTIONS	6 Months Ended
	Jun. 30, 2018
Partners' Capital Account, Distributions [Abstract]
PARTNERS' CAPITAL AND DISTRIBUTIONS	PARTNERS’ CAPITAL AND DISTRIBUTIONS On December 1, 2017, the Partnership issued 1.9 million common units to Ergon in a private placement valued at $10.2 million in exchange for an asphalt terminalling facility in Bainbridge, Georgia. On July 19, 2018 , the Board approved a distribution of $0.17875 per outstanding Preferred Unit for the three months ended June 30, 2018 . The Partnership will pay this distribution on August 14, 2018 , to unitholders of record as of August 3, 2018 . The total distribution will be approximately $6.4 million , with approximately $6.3 million and $0.1 million paid to the Partnership’s preferred unitholders and general partner, respectively. In addition, on July 19, 2018 , the Board approved a cash distribution of $0.08 per outstanding common unit for the three months ended June 30, 2018 . The Partnership will pay this distribution on August 14, 2018 , to unitholders of record on August 3, 2018 . The total distribution will be approximately $3.4 million , with approximately $3.2 million and $0.1 million to be paid to the Partnership’s common unitholders and general partner, respectively, and $0.1 million to be paid to holders of phantom and restricted units pursuant to awards granted under the Partnership’s Long-Term Incentive Plan.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	6 Months Ended
	Jun. 30, 2018
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	RELATED-PARTY TRANSACTIONS Transactions with Ergon The Partnership leases asphalt facilities and provides asphalt terminalling services to Ergon. For both the three months ended June 30, 2017 and 2018 , the Partnership recognized related-party revenues of $13.5 million for services provided to Ergon. For the six months ended June 30, 2017 and 2018 , the Partnership recognized related-party revenues of $26.8 million and $27.5 million , respectively, for services provided to Ergon. As of December 31, 2017 , and June 30, 2018 , the Partnership had receivables from Ergon of $3.1 million and $1.2 million , respectively, net of allowance for doubtful accounts. As of December 31, 2017 , and June 30, 2018 , the Partnership had unearned revenues from Ergon of $1.6 million and $5.3 million , respectively. Effective April 1, 2018, the Partnership entered into an agreement with Ergon under which the Partnership purchases crude oil in connection with its crude oil marketing operations. For the three and six months ended June 30, 2018 , the Partnership made purchases of crude oil under this agreement totaling $30.5 million . As of June 30, 2018 , the Partnership has payables to Ergon related to this agreement of $9.8 million . The Partnership and Ergon have an agreement (the “Agreement”) that gives each party rights concerning the purchase or sale of Ergon’s interest in Cimarron Express Pipeline, LLC (“Cimarron Express”), subject to certain terms and conditions. The Agreement was filed as Exhibit 10.1 to the Partnership’s Current Report on Form 8-K, filed May 14, 2018. The Cimarron Express will be a new 16-inch diameter, 65-mile crude oil pipeline running from northeastern Kingfisher County, Oklahoma to the Partnership’s Cushing, Oklahoma crude oil terminal. Ergon has formed a Delaware limited liability company, Ergon - Oklahoma Pipeline, LLC (“DEVCO”), which will hold Ergon’s 50% membership interest in Cimarron Express. Under the Agreement, the Partnership has the right, at any time, to purchase 100% of the authorized and outstanding member interests in DEVCO from Ergon for the Purchase Price, which shall be computed by taking Ergon’s total investment in the Cimarron Express plus interest, by giving written notice to Ergon (the “Call”). Ergon has the right to require BKEP to purchase 100% of the authorized and outstanding member interests of DEVCO for the Purchase Price (the “Put”) at any time beginning the earlier of (i) 18 months from the formation of the joint venture company to build the pipeline or (ii) six months after completion of the pipeline. Upon exercise of the Call or the Put, Ergon and the Partnership will execute the Member Interest Purchase Agreement which is attached to the Agreement as Exhibit B. Upon receipt of the Purchase Price, Ergon shall be obligated to convey 100% of the authorized and outstanding member interests in DEVCO to BKEP or its designee. There is not a separate amount of consideration for the put or the call exchanged between the parties. Therefore, based on applicable GAAP, no value was assigned to the combined instrument on the Partnership's balance sheet upon the execution of the put/call instrument. Construction of the Cimarron Express pipeline is anticipated to be complete and the pipeline placed in-service during the third quarter of 2019. As of June 30, 2018, neither Ergon nor the Partnership has exercised their options under the Agreement. Transactions with Advantage Pipeline The Partnership provided operating and administrative services to Advantage Pipeline. On April 3, 2017, the Partnership sold its investment in Advantage Pipeline. See Note 5 for additional information. For the six months ended June 30, 2017 , the Partnership earned revenues of $0.3 million for services provided to Advantage Pipeline.

LONG-TERM INCENTIVE PLAN

LONG-TERM INCENTIVE PLAN	6 Months Ended
	Jun. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
LONG-TERM INCENTIVE PLAN	LONG-TERM INCENTIVE PLAN In July 2007, the general partner adopted the Long-Term Incentive Plan (the “LTIP”), which is administered by the compensation committee of the Board. Effective April 29, 2014, the Partnership’s unitholders approved an amendment to the LTIP to increase the number of common units reserved for issuance under the incentive plan to 4,100,000 common units, subject to adjustments for certain events. Although other types of awards are contemplated under the LTIP, currently outstanding awards include “phantom” units, which convey the right to receive common units upon vesting, and “restricted” units, which are grants of common units restricted until the time of vesting. The phantom unit awards also include distribution equivalent rights (“DERs”). Subject to applicable earning criteria, a DER entitles the grantee to a cash payment equal to the cash distribution paid on an outstanding common unit prior to the vesting date of the underlying award. Recipients of restricted and phantom units are entitled to receive cash distributions paid on common units during the vesting period which are reflected initially as a reduction of partners’ capital. Distributions paid on units which ultimately do not vest are reclassified as compensation expense. Awards granted to date are equity awards and, accordingly, the fair value of the awards as of the grant date is expensed over the vesting period. In connection with each anniversary of joining the Board, restricted common units are granted to the independent directors. The units vest in one-third increments over three years. The following table includes information on outstanding grants made to the directors under the LTIP: Grant Date Number of Units Weighted Average Grant Date Fair Value (1) Grant Date Total Fair Value (in thousands) December 2016 10,950 $ 6.85 $ 75 December 2017 15,306 $ 4.85 $ 74 _________________ (1) Fair value is the closing market price on the grant date of the awards. In addition, the independent directors received common unit grants that have no vesting requirement as part of their compensation. The following table includes information on grants made to the directors under the LTIP that have no vesting requirement: Grant Date Number of Units Weighted Average Grant Date Fair Value (1) Grant Date Total Fair Value (in thousands) December 2016 10,220 $ 6.85 $ 70 December 2017 14,286 $ 4.85 $ 69 _________________ (1) Fair value is the closing market price on the grant date of the awards. The Partnership also grants phantom units to employees. These grants are equity awards under ASC 718 – Stock Compensation and, accordingly, the fair value of the awards as of the grant date is expensed over the vesting period. The following table includes information on the outstanding grants: Grant Date Number of Units Weighted Average Grant Date Fair Value (1) Grant Date Total Fair Value (in thousands) March 2016 416,131 $ 4.77 $ 1,985 October 2016 9,960 $ 5.85 $ 58 March 2017 323,339 $ 7.15 $ 2,312 March 2018 457,984 $ 4.77 $ 2,185 _________________ (1) Fair value is the closing market price on the grant date of the awards. The unrecognized estimated compensation cost of outstanding phantom and restricted units at June 30, 2018 , was $3.1 million , which will be expensed over the remaining vesting period. The Partnership’s equity-based incentive compensation expense for each of the three months ended June 30, 2017 and 2018 , was $0.6 million . The Partnership’s equity-based incentive compensation expense for each of the six months ended June 30, 2017 and 2018 was $1.1 million . Activity pertaining to phantom and restricted common unit awards granted under the LTIP is as follows: Number of Units Weighted Average Grant Date Fair Value Nonvested at December 31, 2017 923,551 $ 6.29 Granted 457,984 4.77 Vested 241,629 7.46 Forfeited 10,865 5.39 Nonvested at June 30, 2018 1,129,041 $ 5.88

EMPLOYEE BENEFIT PLAN

EMPLOYEE BENEFIT PLAN	6 Months Ended
	Jun. 30, 2018
Retirement Benefits [Abstract]
EMPLOYEE BENEFIT PLAN	EMPLOYEE BENEFIT PLANS Under the Partnership’s 401(k) Plan, which was instituted in 2009 , employees who meet specified service requirements may contribute a percentage of their total compensation, up to a specified maximum, to the 401(k) Plan. The Partnership may match each employee’s contribution, up to a specified maximum, in full or on a partial basis. The Partnership recognized expense of $0.3 million for each of the three months ended June 30, 2017 and 2018 , for discretionary contributions under the 401(k) Plan. The Partnership recognized expense of $0.6 million for each of the six months ended June 30, 2017 and 2018 , for discretionary contributions under the 401(k) Plan. The Partnership may also make annual lump-sum contributions to the 401(k) Plan irrespective of the employee’s contribution match. The Partnership may make a discretionary annual contribution in the form of profit sharing calculated as a percentage of an employee’s eligible compensation. This contribution is retirement income under the qualified 401(k) Plan. Annual profit sharing contributions to the 401(k) Plan are submitted to and approved by the Board. The Partnership recognized expense of $0.2 million and less than $0.1 million for the three months ended June 30, 2017 and 2018 , respectively, for discretionary profit sharing contributions under the 401(k) Plan. The Partnership recognized expense of $0.4 million and $0.1 million for the six months ended June 30, 2017 and 2018 , respectively, for discretionary profit sharing contributions under the 401(k) Plan. Under the Partnership’s Employee Unit Purchase Plan (the “Unit Purchase Plan”), which was instituted in January 2015, employees have the opportunity to acquire or increase their ownership of common units representing limited partner interests in the Partnership. Eligible employees who enroll in the Unit Purchase Plan may elect to have a designated whole percentage, up to a specified maximum, of their eligible compensation for each pay period withheld for the purchase of common units at a discount to the then current market value. A maximum of 1,000,000 common units may be delivered under the Unit Purchase Plan, subject to adjustment for a recapitalization, split, reorganization, or similar event pursuant to the terms of the Unit Purchase Plan. The Partnership recognized compensation expense of less than $0.1 million during each of the three and six months ended June 30, 2017 and 2018 , in connection with the Unit Purchase Plan.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	6 Months Ended
	Jun. 30, 2018
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	FAIR VALUE MEASUREMENTS The Partnership uses valuation techniques, such as the market approach (comparable market prices), the income approach (present value of future income or cash flow), and the cost approach (cost to replace the service capacity of an asset or replacement cost) to value assets and liabilities required to be measured at fair value, as appropriate. The Partnership uses an exit price when determining the fair value. The exit price represents amounts that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. The Partnership utilizes a three-tier fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels: Level 1 Observable inputs such as quoted prices (unadjusted) in active markets for identical assets or liabilities. Level 2 Inputs other than quoted prices that are observable for these assets or liabilities, either directly or indirectly. These include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active. Level 3 Unobservable inputs in which there is little market data, which requires the reporting entity to develop its own assumptions. This hierarchy requires the use of observable market data, when available, to minimize the use of unobservable inputs when determining fair value. In periods in which they occur, the Partnership recognizes transfers into and out of Level 3 as of the end of the reporting period. There were no transfers during the six months ended June 30, 2018 . Transfers out of Level 3 represent existing assets and liabilities that were classified previously as Level 3 for which the observable inputs became a more significant portion of the fair value estimates. Determining the appropriate classification of the Partnership’s fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data. The Partnership’s recurring financial assets and liabilities subject to fair value measurements and the necessary disclosures are as follows (in thousands): Fair Value Measurements as of December 31, 2017 Description Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Assets: Interest rate swap assets $ 68 $ — $ 68 $ — Total swap assets $ 68 $ — $ 68 $ — Liabilities: Interest rate swap liabilities $ 225 $ — $ 225 $ — Total swap liabilities $ 225 $ — $ 225 $ — Fair Value Measurements as of June 30, 2018 Description Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Assets: Interest rate swap assets $ 157 $ — $ 157 $ — Total swap assets $ 157 $ — $ 157 $ — Fair Value of Other Financial Instruments The following disclosure of the estimated fair value of financial instruments is made in accordance with accounting guidance for financial instruments. The Partnership has determined the estimated fair values by using available market information and valuation methodologies. Considerable judgment is required in interpreting market data to develop the estimates of fair value. The use of different market assumptions or valuation methodologies may have a material effect on the estimated fair value amounts. At June 30, 2018 , the carrying values on the unaudited condensed consolidated balance sheets for cash and cash equivalents (classified as Level 1), accounts receivable, and accounts payable approximate their fair value because of their short-term nature. Based on the borrowing rates currently available to the Partnership for credit agreement debt with similar terms and maturities and consideration of the Partnership’s non-performance risk, long-term debt associated with the Partnership’s credit agreement at June 30, 2018 , approximates its fair value. The fair value of the Partnership’s long-term debt was calculated using observable inputs (LIBOR for the risk-free component) and unobservable company-specific credit spread information. As such, the Partnership considers this debt to be Level 3.

OPERATING SEGMENTS

OPERATING SEGMENTS	6 Months Ended
	Jun. 30, 2018
Segment Reporting [Abstract]
OPERATING SEGMENTS	OPERATING SEGMENTS The Partnership’s operations consist of four operating segments: (i) asphalt terminalling services, (ii) crude oil terminalling services, (iii) crude oil pipeline services and (iv) crude oil trucking services. ASPHALT TERMINALLING SERVICES —The Partnership provides asphalt product and residual fuel terminalling, storage and blending services. As of July 26, 2018 , the Partnership has 53 terminalling and storage facilities located in 26 states. CRUDE OIL TERMINALLING SERVICES —The Partnership provides crude oil terminalling services at its terminalling facility located in Oklahoma. CRUDE OIL PIPELINE SERVICES —The Partnership owns and operates pipeline systems that gather crude oil purchased by its customers and transports it to refiners, to common carrier pipelines for ultimate delivery to refiners or to terminalling facilities owned by the Partnership and others. The Partnership refers to its pipeline system located in Oklahoma and the Texas Panhandle as the Mid-Continent pipeline system. The Partnership previously owned and operated the East Texas pipeline system, which was located in Texas. On April 17, 2017, the Partnership sold the East Texas pipeline system. See Note 6 for additional information. Crude oil product sales revenues consist of sales proceeds recognized for the sale of crude oil to third-party customers. CRUDE OIL TRUCKING SERVICES — The Partnership uses its owned and leased tanker trucks to gather crude oil for its customers at remote wellhead locations generally not covered by pipeline and gathering systems and to transport the crude oil to aggregation points and storage facilities located along pipeline gathering and transportation systems. On April 24, 2018, the Partnership sold the producer field services business. As a result of the sale of the producer field services business, the Partnership changed the name of this operating segment to crude oil trucking services during the second quarter of 2018. See Note 6 for additional information. The Partnership’s management evaluates performance based upon operating margin, excluding amortization and depreciation, which includes revenues from related parties and external customers and operating expense, excluding depreciation and amortization. The non-GAAP measure of operating margin, excluding depreciation and amortization (in the aggregate and by segment) is presented in the following table. The Partnership computes the components of operating margin, excluding depreciation and amortization by using amounts that are determined in accordance with GAAP. The Partnership accounts for intersegment product sales as if the sales were to third parties, that is, at current market prices. A reconciliation of operating margin, excluding depreciation and amortization to income before income taxes, which is its nearest comparable GAAP financial measure, is included in the following table. The Partnership believes that investors benefit from having access to the same financial measures being utilized by management. Operating margin, excluding depreciation and amortization is an important measure of the economic performance of the Partnership’s core operations. This measure forms the basis of the Partnership’s internal financial reporting and is used by its management in deciding how to allocate capital resources among segments. Income before income taxes, alternatively, includes expense items, such as depreciation and amortization, general and administrative expenses and interest expense, which management does not consider when evaluating the core profitability of the Partnership’s operations. The following table reflects certain financial data for each segment for the periods indicated (in thousands): Three Months ended Six Months ended 2017 2018 2017 2018 Asphalt Terminalling Services Service revenue: Third-party revenue $ 13,259 $ 6,639 $ 26,482 $ 11,771 Related-party revenue 13,505 5,981 26,837 12,302 Lease revenue: Third-party revenue — 10,016 — 19,473 Related-party revenue — 7,475 — 15,178 Total revenue for reportable segment 26,764 30,111 53,319 58,724 Operating expense, excluding depreciation and amortization 11,935 13,393 24,255 26,728 Operating margin, excluding depreciation and amortization $ 14,829 $ 16,718 $ 29,064 $ 31,996 Total assets (end of period) $ 147,832 $ 167,849 $ 147,832 $ 167,849 Crude Oil Terminalling Services Service revenue: Third-party revenue $ 5,726 $ 2,910 $ 11,851 $ 7,496 Intersegment revenue — 170 — 170 Lease revenue: Third-party revenue — 12 — 27 Total revenue for reportable segment 5,726 3,092 11,851 7,693 Operating expense, excluding depreciation and amortization 992 913 2,003 2,188 Operating margin, excluding depreciation and amortization $ 4,734 $ 2,179 $ 9,848 $ 5,505 Total assets (end of period) $ 69,834 $ 67,150 $ 69,834 $ 67,150 Crude Oil Pipeline Services Service revenue: Third-party revenue $ 2,720 $ 1,045 $ 5,324 $ 3,105 Related-party revenue — 82 310 82 Lease revenue: Third-party revenue — 177 — 412 Product sales revenue: Third-party revenue 2,227 45,612 5,877 49,120 Total revenue for reportable segment 4,947 46,916 11,511 52,719 Operating expense, excluding depreciation and amortization 3,142 2,542 6,383 5,327 Operating expense (intersegment) 74 1,156 244 1,599 Third-party cost of product sales 1,669 20,041 4,808 22,678 Related-party cost of product sales — 23,747 — 23,747 Operating margin, excluding depreciation and amortization $ 62 $ (570 ) $ 76 $ (632 ) Total assets (end of period) $ 117,222 $ 152,105 $ 117,222 $ 152,105 Three Months ended Six Months ended 2017 2018 2017 2018 Crude Oil Trucking Services Service revenue: Third-party revenue $ 6,440 $ 3,509 $ 13,151 $ 9,049 Intersegment revenue 74 986 244 1,429 Lease revenue: Third-party revenue — 32 — 129 Product sales revenue: Third-party revenue — 3 385 9 Total revenue for reportable segment 6,514 4,530 13,780 10,616 Operating expense, excluding depreciation and amortization 6,702 4,727 13,970 11,101 Operating margin, excluding depreciation and amortization $ (188 ) $ (197 ) $ (190 ) $ (485 ) Total assets (end of period) $ 11,208 $ 3,402 $ 11,208 $ 3,402 Total operating margin, excluding depreciation and amortization (1) $ 19,437 $ 18,130 $ 38,798 $ 36,384 Total segment revenues $ 43,951 $ 84,649 $ 90,461 $ 129,752 Elimination of intersegment revenues (74 ) (1,156 ) (244 ) (1,599 ) Consolidated revenues $ 43,877 $ 83,493 $ 90,217 $ 128,153 ____________________ (1) The following table reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes (in thousands): Three Months ended Six Months ended 2017 2018 2017 2018 Operating margin, excluding depreciation and amortization $ 19,437 $ 18,130 $ 38,798 $ 36,384 Depreciation and amortization (7,839 ) (7,413 ) (15,905 ) (14,779 ) General and administrative expense (4,322 ) (4,486 ) (8,907 ) (8,707 ) Asset impairment expense (17 ) — (45 ) (616 ) Gain (loss) on sale of assets (754 ) 599 (879 ) 363 Interest expense (4,265 ) (5,024 ) (7,295 ) (8,593 ) Gain on sale of unconsolidated affiliate 4,172 — 4,172 2,225 Equity earnings in unconsolidated affiliate — — 61 — Income before income taxes $ 6,412 $ 1,806 $ 10,000 $ 6,277

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	6 Months Ended
	Jun. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
COMMITMENT AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES The Partnership is from time to time subject to various legal actions and claims incidental to its business. Management believes that these legal proceedings will not have a material adverse effect on the financial position, results of operations or cash flows of the Partnership. Once management determines that information pertaining to a legal proceeding indicates that it is probable that a liability has been incurred and the amount of such liability can be reasonably estimated, an accrual is established equal to its estimate of the likely exposure. The Partnership has contractual obligations to perform dismantlement and removal activities in the event that some of its asphalt product and residual fuel oil terminalling and storage assets are abandoned. These obligations include varying levels of activity including completely removing the assets and returning the land to its original state. The Partnership has determined that the settlement dates related to the retirement obligations are indeterminate. The assets with indeterminate settlement dates have been in existence for many years and with regular maintenance will continue to be in service for many years to come. Also, it is not possible to predict when demands for the Partnership’s terminalling and storage services will cease, and the Partnership does not believe that such demand will cease for the foreseeable future. Accordingly, the Partnership believes the date when these assets will be abandoned is indeterminate. With no reasonably determinable abandonment date, the Partnership cannot reasonably estimate the fair value of the associated asset retirement obligations. Management believes that if the Partnership’s asset retirement obligations were settled in the foreseeable future the present value of potential cash flows that would be required to settle the obligations based on current costs are not material. The Partnership will record asset retirement obligations for these assets in the period in which sufficient information becomes available for it to reasonably determine the settlement dates.

INCOME TAXES

INCOME TAXES	6 Months Ended
	Jun. 30, 2018
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES In relation to the Partnership’s taxable subsidiary, the tax effects of temporary differences between the tax basis of assets and liabilities and their financial reporting amounts at June 30, 2018 , are presented below (dollars in thousands): Deferred Tax Asset Difference in bases of property, plant and equipment $ 444 Net operating loss carryforwards 11 Deferred tax asset 455 Less: valuation allowance 444 Net deferred tax asset $ 11 The Partnership has considered the taxable income projections in future years, whether the carryforward period is so brief that it would limit realization of tax benefits, whether future revenue and operating cost projections will produce enough taxable income to realize the deferred tax asset based on existing service rates and cost structures, and the Partnership’s earnings history exclusive of the loss that created the future deductible amount for the Partnership’s subsidiary that is taxed as a corporation for purposes of determining the likelihood of realizing the benefits of the deferred tax assets. As a result of the Partnership’s consideration of these factors, the Partnership has provided a valuation allowance against its deferred tax asset related to the difference in bases of property, plant and equipment as of June 30, 2018 .

RECENTLY ISSUED ACCOUNTING STAN

RECENTLY ISSUED ACCOUNTING STANDARDS	6 Months Ended
	Jun. 30, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
RECENTLY ISSUED ACCOUNTING STANDARDS	RECENTLY ISSUED ACCOUNTING STANDARDS Except as discussed below and in the 2017 Form 10-K, there have been no new accounting pronouncements that have become effective or have been issued during the six months ended June 30, 2018 , that are of significance or potential significance to the Partnership. In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers.” The amendments in this update create Topic 606, Revenue from Contracts with Customers, and supersede the revenue recognition requirements in Topic 605, Revenue Recognition, including most industry-specific revenue recognition guidance throughout the Industry Topics of the Codification. In addition, the amendments supersede the cost guidance in Subtopic 605-35, Revenue Recognition-Construction-Type and Production-Type Contracts, and create new Subtopic 340-40, Other Assets and Deferred Costs-Contracts with Customers. In summary, the core principle of Topic 606 is that an entity recognizes revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. Throughout 2015 and 2016, the FASB has issued a series of subsequent updates to the revenue recognition guidance in Topic 606, including ASU No. 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date,” ASU No. 2016-08, “Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” ASU No. 2016-10, “Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing,” ASU No. 2016-12, “Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients” and ASU No. 2016-20, “Technical Corrections and Improvements to Topic 606, Revenue from Contracts with Customers.” The amendments in ASU 2014-09, ASU 2016-08, ASU 2016-10, ASU 2016-12 and ASU 2016-20 are effective for public entities for annual reporting periods beginning after December 15, 2017, and for interim periods within that reporting period. The Partnership adopted these updates in the three-month period ending March 31, 2018. See Note 3 for disclosures related to the adoption of this standard and the impact on the Partnership’s financial position, results of operations and cash flows. In January 2016, the FASB issued ASU 2016-01, “Financial Instruments - Overall (Subtopic 825-10).” This update is intended to enhance the reporting model for financial instruments in order to provide users of financial statements with more decision-useful information. The amendments in the update address certain aspects of recognition, measurement, presentation and disclosure of financial instruments. This update is effective for financial statements issued for annual periods beginning after December 15, 2017, and interim periods within those fiscal years. The Partnership adopted this update in the three-month period ending March 31, 2018, and there was no impact on the Partnership’s financial position, results of operations or cash flows. In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842).” This update introduces a new lease model that requires the recognition of lease assets and lease liabilities on the balance sheet and the disclosure of key information about leasing arrangements. Throughout 2017 and 2018, the FASB issued a series of subsequent updates to the guidance in Topic 842. This update, as well as related updates, is effective for financial statements issued for annual periods beginning after December 15, 2018, and interim periods within those fiscal years. The Partnership is evaluating the impact of this guidance, which will be adopted beginning with the Partnership’s quarterly report for the three-month period ending March 31, 2019. In August 2016, the FASB issued ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments.” This update addresses the following eight specific cash flow issues: debt prepayment or debt extinguishment costs; settlement of zero-coupon debt instruments or other debt instruments with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance policies (including bank-owned life insurance policies); distributions received from equity method investees; beneficial interests in securitization transactions; and separately identifiable cash flows and application of the predominance principle. This update is effective for financial statements issued for annual periods beginning after December 15, 2017, and interim periods within those fiscal years. The Partnership adopted this update in the three-month period ending March 31, 2018, and there was no impact on the Partnership’s financial position, results of operations or cash flows. In October 2016, the FASB issued ASU 2016-16, “Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other than Inventory.” This update is intended to improve the accounting for the income tax consequences of intra-entity transfers of assets other than inventory. The amendments in the update eliminate the prohibition of recognizing current and deferred income taxes for an intra-entity asset transfer other than inventory until the asset has been sold to an outside party. This update is effective for financial statements issued for annual periods beginning after December 15, 2017, and interim periods within those fiscal years. The Partnership adopted this update in the three-month period ending March 31, 2018, and there was no impact on the Partnership’s financial position, results of operations or cash flows. In November 2016, the FASB issued ASU 2016-18, “Statement of Cash Flows (Topic 230): Restricted Cash (a Consensus of the FASB Emerging Issues Task Force).” This update requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents and amounts generally described as restricted cash or restricted cash equivalents. This update is effective for financial statements issued for annual periods beginning after December 15, 2017, and interim periods within those fiscal years. The Partnership adopted this update in the three-month period ending March 31, 2018, and there was no impact on the Partnership’s financial position, results of operations or cash flows. In January 2017, the FASB issued ASU 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business.” This update clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. This update is effective for financial statements issued for annual periods beginning after December 15, 2017, and interim periods within those fiscal years. The Partnership adopted this update in the three-month period ending March 31, 2018, and there was no impact on the Partnership’s financial position, results of operations or cash flows. In February 2017, the FASB issued ASU 2017-05, “Other Income - Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20).” This update clarifies the scope of Subtopic 610-20 and adds guidance for partial sales of nonfinancial assets. Subtopic 610-20, which was issued in May 2014 as a part of ASU 2014-09, “Revenue from Contracts with Customers (Topic 606),” provides guidance for recognizing gains and losses from the transfer of nonfinancial assets in contracts with noncustomers. The amendments in ASU 2017-05 are effective for public entities for annual reporting periods beginning after December 15, 2017, and for interim periods within that reporting period. Early application is permitted for annual reporting periods beginning after December 15, 2016. The Partnership adopted this update in the three-month period ending March 31, 2018, and there was no impact on the Partnership’s financial position, results of operations or cash flows. In May 2017, the FASB issued ASU 2017-09, “Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting.” This update provides clarity and reduces both diversity in practice and cost and complexity when applying the guidance of Topic 718, Compensation - Stock Compensation, to a change in the terms or conditions of a share-based payment award. This update is effective for financial statements issued for annual periods beginning after December 15, 2017, and interim periods within those fiscal years. The Partnership adopted this update in the three-month period ending March 31, 2018, and there was no impact on the Partnership’s financial position, results of operations or cash flows.

SUBSEQUENT EVENTS SUBSEQUENT EV

SUBSEQUENT EVENTS SUBSEQUENT EVENTS	6 Months Ended
	Jun. 30, 2018
Subsequent Events [Abstract]
Subsequent Events	SUBSEQUENT EVENTS Sale of Asphalt Facilities On June 29, 2018, the Partnership entered into a definitive agreement to sell certain asphalt terminals, storage tanks and related real property, contracts, permits, assets and other interests located in Lubbock and Saginaw, Texas and Memphis, Tennessee properties (the “Divestiture”) to Ergon Asphalt & Emulsion, Inc. (“Ergon A&E”) for a purchase price of $90.0 million , subject to customary adjustments. The Partnership closed the Divestiture on July 12, 2018, and filed a Current Report on Form 8-K on July 13, 2018. The Divestiture does not qualify as discontinued operations as it does not represent a strategic shift that will have a major effect on the Partnership’s operations or financial results. The Partnership used the proceeds received at closing to prepay revolving debt under its credit agreement.

REVENUE Revenue from Contracts

REVENUE Revenue from Contracts with Customers (Tables)	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]	As of June 30, 2018 , the Partnership has performance obligations satisfied over time under asphalt storage, throughput and handling contracts that are wholly or partially unsatisfied. The revenue related to these performance obligations will be recognized as follows (in thousands): Revenue Related to Future Performance Obligations Due by Period (1) Less than 1 year $ 35,257 1-3 years 64,767 4-5 years 46,024 More than 5 years 13,591 Total revenue related to future performance obligations $ 159,639 ____________________ (1) Excluded from the table is revenue that is either constrained or related to performance obligations that are wholly unsatisfied as of June 30, 2018 .
Disaggregation of Revenue [Table Text Block]	Disaggregation of revenue from contracts with customers for each operating segment by revenue type is presented as follows (in thousands): Three Months ended June 30, 2018 Asphalt Terminalling Services Crude Oil Terminalling Services Crude Oil Pipeline Services Crude Oil Trucking Services Total Third-party revenue: Fixed storage, throughput and other revenue $ 4,622 $ 2,767 $ — $ — $ 7,389 Variable throughput revenue 242 143 — — 385 Variable reimbursement revenue 1,775 — — — 1,775 Crude oil transportation revenue — — 1,045 3,509 4,554 Crude oil product sales revenue — — 45,612 3 45,615 Related-party revenue: Fixed storage, throughput and other revenue 4,632 — 48 — 4,680 Variable reimbursement revenue 1,349 — 34 — 1,383 Total revenue from contracts with customers $ 12,620 $ 2,910 $ 46,739 $ 3,512 $ 65,781 Six Months ended June 30, 2018 Asphalt Terminalling Services Crude Oil Terminalling Services Crude Oil Pipeline Services Crude Oil Trucking Services Total Third-party revenue: Fixed storage, throughput and other revenue $ 8,171 $ 6,849 $ — $ — $ 15,020 Variable throughput revenue 359 647 — — 1,006 Variable reimbursement revenue 3,241 — — — 3,241 Crude oil transportation revenue — — 3,105 9,049 12,154 Crude oil product sales revenue — — 49,120 9 49,129 Related-party revenue: Fixed storage, throughput and other revenue 9,263 — 48 — 9,311 Variable reimbursement revenue 3,039 — 34 — 3,073 Total revenue from contracts with customers $ 24,073 $ 7,496 $ 52,307 $ 9,058 $ 92,934

RESTRUCTURING CHARGES (Tables)

RESTRUCTURING CHARGES (Tables)	6 Months Ended
	Jun. 30, 2018
Crude Oil Trucking Services [Member] | West Texas Trucking Market Exit Plan [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring and Related Costs [Table Text Block]	Changes in the accrued amounts pertaining to the restructuring charges are summarized as follows (in thousands): Three Months ended Six Months ended 2017 2018 2017 2018 Beginning balance $ 428 $ 237 $ 474 $ 286 Cash payments 46 237 92 286 Ending balance $ 382 $ — $ 382 $ —

EQUITY METHOD INVESTMENT (Table

EQUITY METHOD INVESTMENT (Tables)	6 Months Ended
	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments [Table Text Block]	Summarized financial information for Advantage Pipeline is set forth in the tables below for the period indicated in which the Partnership held the investment in Advantage Pipeline (in thousands): Period ended April 3, 2017 Income Statement Operating revenues $ 3,150 Operating expenses $ 465 Net income $ 187

PROPERTY, PLANT AND EQUIPMENT (

PROPERTY, PLANT AND EQUIPMENT (Tables)	6 Months Ended
	Jun. 30, 2018
Property, Plant and Equipment [Abstract]
Schedule of Property, Plant and Equipment	Estimated Useful Lives (Years) December 31, 2017 June 30, (dollars in thousands) Land N/A $ 24,776 $ 25,067 Land improvements 10-20 6,787 5,815 Pipelines and facilities 5-30 166,004 167,624 Storage and terminal facilities 10-35 370,056 319,344 Transportation equipment 3-10 3,293 1,056 Office property and equipment and other 3-20 32,011 26,958 Pipeline linefill and tank bottoms N/A 3,233 11,694 Construction-in-progress N/A 6,500 8,131 Property, plant and equipment, gross 612,660 565,689 Accumulated depreciation (316,591 ) (269,978 ) Property, plant and equipment, net $ 296,069 $ 295,711

DEBT Fair Values of Derivative

DEBT Fair Values of Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location [Table Text Block]	The following provides information regarding the Partnership’s assets and liabilities related to its interest rate swap agreements as of the periods indicated (in thousands): Derivatives Not Designated as Hedging Instruments Balance Sheet Location Fair Value of Derivatives December 31, 2017 June 30, Interest rate swap assets - current Other current assets $ 68 $ 157 Interest rate swap liabilities - noncurrent Long-term interest rate swap liabilities $ 225 $ — Changes in the fair value of the interest rate swaps are reflected in the unaudited condensed consolidated statements of operations as follows (in thousands): Derivatives Not Designated as Hedging Instruments Location of Gain (Loss) Recognized in Net Income on Derivatives Amount of Gain (Loss) Recognized in Net Income on Derivatives Three Months ended Six Months ended 2017 2018 2017 2018 Interest rate swaps Interest expense, net of capitalized interest $ 223 $ (40 ) $ 975 $ 314

NET INCOME PER LIMITED PARTNE32

NET INCOME PER LIMITED PARTNER UNIT (Tables)	6 Months Ended
	Jun. 30, 2018
Earnings Per Share [Abstract]
Schedule of Basic and Diluted Net Income (Loss) Per Common and Subordinated Units	The following sets forth the computation of basic and diluted net income per common unit (in thousands, except per unit data): Three Months ended Six Months ended 2017 2018 2017 2018 Net income $ 6,371 $ 1,785 $ 9,913 $ 6,227 General partner interest in net income 256 28 465 259 Preferred interest in net income 6,279 6,279 12,558 12,557 Net loss available to limited partners $ (164 ) $ (4,522 ) $ (3,110 ) $ (6,589 ) Basic and diluted weighted average number of units: Common units 38,155 40,324 38,151 40,306 Restricted and phantom units 923 1,133 806 983 Total units 39,078 41,457 38,957 41,289 Basic and diluted net loss per common unit $ — $ (0.11 ) $ (0.08 ) $ (0.16 )

LONG-TERM INCENTIVE PLAN (Table

LONG-TERM INCENTIVE PLAN (Tables)	6 Months Ended
	Jun. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-based Compensation Arrangements by Share-based Payment Award, Restricted Stock Units, Vested and Expected to Vest [Table Text Block]	In connection with each anniversary of joining the Board, restricted common units are granted to the independent directors. The units vest in one-third increments over three years. The following table includes information on outstanding grants made to the directors under the LTIP: Grant Date Number of Units Weighted Average Grant Date Fair Value (1) Grant Date Total Fair Value (in thousands) December 2016 10,950 $ 6.85 $ 75 December 2017 15,306 $ 4.85 $ 74 _________________ (1) Fair value is the closing market price on the grant date of the awards. In addition, the independent directors received common unit grants that have no vesting requirement as part of their compensation. The following table includes information on grants made to the directors under the LTIP that have no vesting requirement: Grant Date Number of Units Weighted Average Grant Date Fair Value (1) Grant Date Total Fair Value (in thousands) December 2016 10,220 $ 6.85 $ 70 December 2017 14,286 $ 4.85 $ 69 _________________ (1) Fair value is the closing market price on the grant date of the awards.
Disclosure of Share-based Compensation Arrangements by Share-based Payment Award [Table Text Block]	The Partnership also grants phantom units to employees. These grants are equity awards under ASC 718 – Stock Compensation and, accordingly, the fair value of the awards as of the grant date is expensed over the vesting period. The following table includes information on the outstanding grants: Grant Date Number of Units Weighted Average Grant Date Fair Value (1) Grant Date Total Fair Value (in thousands) March 2016 416,131 $ 4.77 $ 1,985 October 2016 9,960 $ 5.85 $ 58 March 2017 323,339 $ 7.15 $ 2,312 March 2018 457,984 $ 4.77 $ 2,185 _________________ (1) Fair value is the closing market price on the grant date of the awards.
Schedule Of Phantom Common Units And Restricted Common Units Activity	Activity pertaining to phantom and restricted common unit awards granted under the LTIP is as follows: Number of Units Weighted Average Grant Date Fair Value Nonvested at December 31, 2017 923,551 $ 6.29 Granted 457,984 4.77 Vested 241,629 7.46 Forfeited 10,865 5.39 Nonvested at June 30, 2018 1,129,041 $ 5.88

FAIR VALUE MEASUREMENTS Fair Va

FAIR VALUE MEASUREMENTS Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value, by Balance Sheet Grouping [Table Text Block]	The Partnership’s recurring financial assets and liabilities subject to fair value measurements and the necessary disclosures are as follows (in thousands): Fair Value Measurements as of December 31, 2017 Description Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Assets: Interest rate swap assets $ 68 $ — $ 68 $ — Total swap assets $ 68 $ — $ 68 $ — Liabilities: Interest rate swap liabilities $ 225 $ — $ 225 $ — Total swap liabilities $ 225 $ — $ 225 $ — Fair Value Measurements as of June 30, 2018 Description Total Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Assets: Interest rate swap assets $ 157 $ — $ 157 $ — Total swap assets $ 157 $ — $ 157 $ —

OPERATING SEGMENTS (Tables)

OPERATING SEGMENTS (Tables)	6 Months Ended
	Jun. 30, 2018
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	The following table reflects certain financial data for each segment for the periods indicated (in thousands): Three Months ended Six Months ended 2017 2018 2017 2018 Asphalt Terminalling Services Service revenue: Third-party revenue $ 13,259 $ 6,639 $ 26,482 $ 11,771 Related-party revenue 13,505 5,981 26,837 12,302 Lease revenue: Third-party revenue — 10,016 — 19,473 Related-party revenue — 7,475 — 15,178 Total revenue for reportable segment 26,764 30,111 53,319 58,724 Operating expense, excluding depreciation and amortization 11,935 13,393 24,255 26,728 Operating margin, excluding depreciation and amortization $ 14,829 $ 16,718 $ 29,064 $ 31,996 Total assets (end of period) $ 147,832 $ 167,849 $ 147,832 $ 167,849 Crude Oil Terminalling Services Service revenue: Third-party revenue $ 5,726 $ 2,910 $ 11,851 $ 7,496 Intersegment revenue — 170 — 170 Lease revenue: Third-party revenue — 12 — 27 Total revenue for reportable segment 5,726 3,092 11,851 7,693 Operating expense, excluding depreciation and amortization 992 913 2,003 2,188 Operating margin, excluding depreciation and amortization $ 4,734 $ 2,179 $ 9,848 $ 5,505 Total assets (end of period) $ 69,834 $ 67,150 $ 69,834 $ 67,150 Crude Oil Pipeline Services Service revenue: Third-party revenue $ 2,720 $ 1,045 $ 5,324 $ 3,105 Related-party revenue — 82 310 82 Lease revenue: Third-party revenue — 177 — 412 Product sales revenue: Third-party revenue 2,227 45,612 5,877 49,120 Total revenue for reportable segment 4,947 46,916 11,511 52,719 Operating expense, excluding depreciation and amortization 3,142 2,542 6,383 5,327 Operating expense (intersegment) 74 1,156 244 1,599 Third-party cost of product sales 1,669 20,041 4,808 22,678 Related-party cost of product sales — 23,747 — 23,747 Operating margin, excluding depreciation and amortization $ 62 $ (570 ) $ 76 $ (632 ) Total assets (end of period) $ 117,222 $ 152,105 $ 117,222 $ 152,105 Three Months ended Six Months ended 2017 2018 2017 2018 Crude Oil Trucking Services Service revenue: Third-party revenue $ 6,440 $ 3,509 $ 13,151 $ 9,049 Intersegment revenue 74 986 244 1,429 Lease revenue: Third-party revenue — 32 — 129 Product sales revenue: Third-party revenue — 3 385 9 Total revenue for reportable segment 6,514 4,530 13,780 10,616 Operating expense, excluding depreciation and amortization 6,702 4,727 13,970 11,101 Operating margin, excluding depreciation and amortization $ (188 ) $ (197 ) $ (190 ) $ (485 ) Total assets (end of period) $ 11,208 $ 3,402 $ 11,208 $ 3,402 Total operating margin, excluding depreciation and amortization (1) $ 19,437 $ 18,130 $ 38,798 $ 36,384 Total segment revenues $ 43,951 $ 84,649 $ 90,461 $ 129,752 Elimination of intersegment revenues (74 ) (1,156 ) (244 ) (1,599 ) Consolidated revenues $ 43,877 $ 83,493 $ 90,217 $ 128,153 ____________________ (1) The following table reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes (in thousands): Three Months ended Six Months ended 2017 2018 2017 2018 Operating margin, excluding depreciation and amortization $ 19,437 $ 18,130 $ 38,798 $ 36,384 Depreciation and amortization (7,839 ) (7,413 ) (15,905 ) (14,779 ) General and administrative expense (4,322 ) (4,486 ) (8,907 ) (8,707 ) Asset impairment expense (17 ) — (45 ) (616 ) Gain (loss) on sale of assets (754 ) 599 (879 ) 363 Interest expense (4,265 ) (5,024 ) (7,295 ) (8,593 ) Gain on sale of unconsolidated affiliate 4,172 — 4,172 2,225 Equity earnings in unconsolidated affiliate — — 61 — Income before income taxes $ 6,412 $ 1,806 $ 10,000 $ 6,277

INCOME TAXES (Tables)

INCOME TAXES (Tables)	6 Months Ended
	Jun. 30, 2018
Income Tax Disclosure [Abstract]
Schedule of Deferred Tax Assets	In relation to the Partnership’s taxable subsidiary, the tax effects of temporary differences between the tax basis of assets and liabilities and their financial reporting amounts at June 30, 2018 , are presented below (dollars in thousands): Deferred Tax Asset Difference in bases of property, plant and equipment $ 444 Net operating loss carryforwards 11 Deferred tax asset 455 Less: valuation allowance 444 Net deferred tax asset $ 11

ORGANIZATION AND NATURE OF BU37

ORGANIZATION AND NATURE OF BUSINESS (Narrative) (Details)	6 Months Ended
	Jun. 30, 2018Operating-segmentsStates
ORGANIZATION AND NATURE OF BUSINESS [Abstract]
Number of states in which entity operates (in states) | States	27
Number of operating segments (in operating segments) | Operating-segments	4

REVENUE Narrative (Details)

REVENUE Narrative (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Third-party revenue	$ 14,103,000	$ 28,145,000	$ 31,421,000	$ 56,808,000
Accounts Receivable, Net, Current	31,268,000		31,268,000		$ 7,589,000
Revenue related to future performance obligations	159,639,000		159,639,000
Contract with Customer, Performance Obligation Satisfied in Previous Period	114,039
Billed contract accounts receivable	27,900,000		27,900,000		8,500,000
Contract with Customer, Asset, Net, Current	300,000		300,000		0
Contract with Customer, Liability, Noncurrent	4,600,000		4,600,000		$ 3,700,000
Changes in deferred revenue [Roll Forward]
Deferred revenue, additions			2,500,000
Contract with customer, liability, revenue recognized			(1,600,000)
Fixed Storage and Throughput Revenue [Member]
Third-party revenue	7,389,000		15,020,000
Variable Throughput Revenue [Member]
Third-party revenue	385,000		1,006,000
Variable Reimbursement Revenue [Member]
Third-party revenue	1,775,000		3,241,000
Crude Oil Transportation Revenue [Member]
Third-party revenue	4,554,000		12,154,000
Asphalt Terminalling Services [Member]
Third-party revenue	6,639,000	13,259,000	11,771,000	26,482,000
Asphalt Terminalling Services [Member] | Fixed Storage and Throughput Revenue [Member]
Third-party revenue	4,622,000		8,171,000
Asphalt Terminalling Services [Member] | Variable Throughput Revenue [Member]
Third-party revenue	242,000		$ 359,000
Revenue, Performance Obligation, Description of Payment Terms			P30D
Asphalt Terminalling Services [Member] | Variable Reimbursement Revenue [Member]
Third-party revenue	1,775,000		$ 3,241,000
Revenue, Performance Obligation, Description of Payment Terms			P30D
Asphalt Terminalling Services [Member] | Crude Oil Transportation Revenue [Member]
Third-party revenue	0		$ 0
Crude Oil Terminalling Services [Member]
Third-party revenue	2,910,000	5,726,000	7,496,000	11,851,000
Crude Oil Terminalling Services [Member] | Fixed Storage and Throughput Revenue [Member]
Third-party revenue	2,767,000		6,849,000
Crude Oil Terminalling Services [Member] | Variable Throughput Revenue [Member]
Third-party revenue	143,000		$ 647,000
Revenue, Performance Obligation, Description of Payment Terms			P30D
Crude Oil Terminalling Services [Member] | Variable Reimbursement Revenue [Member]
Third-party revenue	0		$ 0
Crude Oil Terminalling Services [Member] | Crude Oil Transportation Revenue [Member]
Third-party revenue	0		0
Crude Oil Pipeline Services [Member]
Third-party revenue	1,045,000	2,720,000	3,105,000	5,324,000
Crude Oil Pipeline Services [Member] | Fixed Storage and Throughput Revenue [Member]
Third-party revenue	0		0
Crude Oil Pipeline Services [Member] | Variable Throughput Revenue [Member]
Third-party revenue	0		0
Crude Oil Pipeline Services [Member] | Variable Reimbursement Revenue [Member]
Third-party revenue	0		0
Crude Oil Pipeline Services [Member] | Crude Oil Transportation Revenue [Member]
Third-party revenue	1,045,000		$ 3,105,000
Revenue, Performance Obligation, Description of Payment Terms			P30D
Crude Oil Pipeline Services [Member] | Crude Oil Product Sales Revenue [Member]
Revenue, Performance Obligation, Description of Payment Terms			P30D
Crude Oil Trucking Services [Member]
Third-party revenue	3,509,000	$ 6,440,000	$ 9,049,000	$ 13,151,000
Crude Oil Trucking Services [Member] | Fixed Storage and Throughput Revenue [Member]
Third-party revenue	0		0
Crude Oil Trucking Services [Member] | Variable Throughput Revenue [Member]
Third-party revenue	0		0
Crude Oil Trucking Services [Member] | Variable Reimbursement Revenue [Member]
Third-party revenue	0		0
Crude Oil Trucking Services [Member] | Crude Oil Transportation Revenue [Member]
Third-party revenue	3,509,000		$ 9,049,000
Revenue, Performance Obligation, Description of Payment Terms			P30D
Accounting Standards Update 2014-09 [Member]
Third-party revenue	200,000		$ 300,000
Accounts Receivable, Net, Current	$ 300,000		$ 300,000

REVENUE Disaggregation of Reven

REVENUE Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Disaggregation of Revenue [Line Items]
Third-party revenue	$ 14,103	$ 28,145	$ 31,421	$ 56,808
Third-party revenue, product sales	45,615	2,227	49,129	6,262
Related-party revenue	6,063	13,505	12,384	27,147
Revenue from contracts with customers	65,781		92,934
Fixed Storage and Throughput Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	7,389		15,020
Related-party revenue	4,680		9,311
Variable Throughput Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	385		1,006
Variable Reimbursement Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	1,775		3,241
Related-party revenue	1,383		3,073
Crude Oil Transportation Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	4,554		12,154
Crude Oil Product Sales Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue, product sales	45,615		49,129
Asphalt Terminalling Services [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	6,639	13,259	11,771	26,482
Related-party revenue			12,302	26,837
Revenue from contracts with customers	12,620		24,073
Asphalt Terminalling Services [Member] | Fixed Storage and Throughput Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	4,622		8,171
Related-party revenue	4,632		9,263
Asphalt Terminalling Services [Member] | Variable Throughput Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	242		359
Asphalt Terminalling Services [Member] | Variable Reimbursement Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	1,775		3,241
Related-party revenue	1,349		3,039
Asphalt Terminalling Services [Member] | Crude Oil Transportation Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	0		0
Asphalt Terminalling Services [Member] | Crude Oil Product Sales Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue, product sales	0		0
Crude Oil Terminalling Services [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	2,910	5,726	7,496	11,851
Revenue from contracts with customers	2,910		7,496
Crude Oil Terminalling Services [Member] | Fixed Storage and Throughput Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	2,767		6,849
Related-party revenue	0		0
Crude Oil Terminalling Services [Member] | Variable Throughput Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	143		647
Crude Oil Terminalling Services [Member] | Variable Reimbursement Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	0		0
Related-party revenue	0		0
Crude Oil Terminalling Services [Member] | Crude Oil Transportation Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	0		0
Crude Oil Terminalling Services [Member] | Crude Oil Product Sales Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue, product sales	0		0
Crude Oil Pipeline Services [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	1,045	2,720	3,105	5,324
Third-party revenue, product sales	45,612	2,227	49,120	5,877
Related-party revenue			82	310
Revenue from contracts with customers	46,739		52,307
Crude Oil Pipeline Services [Member] | Fixed Storage and Throughput Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	0		0
Related-party revenue	48		48
Crude Oil Pipeline Services [Member] | Variable Throughput Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	0		0
Crude Oil Pipeline Services [Member] | Variable Reimbursement Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	0		0
Related-party revenue	34		34
Crude Oil Pipeline Services [Member] | Crude Oil Transportation Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	1,045		3,105
Crude Oil Pipeline Services [Member] | Crude Oil Product Sales Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue, product sales	45,612		49,120
Crude Oil Trucking Services [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	3,509	6,440	9,049	13,151
Third-party revenue, product sales	3	$ 0	9	$ 385
Revenue from contracts with customers	3,512		9,058
Crude Oil Trucking Services [Member] | Fixed Storage and Throughput Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	0		0
Related-party revenue	0		0
Crude Oil Trucking Services [Member] | Variable Throughput Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	0		0
Crude Oil Trucking Services [Member] | Variable Reimbursement Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	0		0
Related-party revenue	0		0
Crude Oil Trucking Services [Member] | Crude Oil Transportation Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue	3,509		9,049
Crude Oil Trucking Services [Member] | Crude Oil Product Sales Revenue [Member]
Disaggregation of Revenue [Line Items]
Third-party revenue, product sales	$ 3		$ 9

REVENUE Revenue Related to Futu

REVENUE Revenue Related to Future Performance Obligations Due by Period (Details) $ in Thousands	Jun. 30, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue related to future performance obligations	$ 159,639
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue related to future performance obligations	35,257
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue related to future performance obligations	64,767
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue related to future performance obligations	46,024
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue related to future performance obligations	$ 13,591

RESTRUCTURING CHARGES (Details)

RESTRUCTURING CHARGES (Details) - West Texas Trucking Market Exit Plan [Member] - Crude Oil Trucking Services [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Mar. 31, 2018	Dec. 31, 2017	Mar. 31, 2017	Dec. 31, 2016
Restructuring Cost and Reserve [Line Items]
Restructuring reserve	$ 0	$ 382	$ 0	$ 382	$ 237	$ 286	$ 428	$ 474
Cash payments	$ 237	$ 46	$ 286	$ 92

EQUITY METHOD INVESTMENT (Detai

EQUITY METHOD INVESTMENT (Details) - USD ($) $ in Thousands	Jan. 02, 2018	Apr. 03, 2017	Jun. 30, 2018	Sep. 30, 2017	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Schedule of Equity Method Investments [Line Items]
Proceeds from sale of unconsolidated affiliate						$ 2,225	$ 25,324
Gain on sale of unconsolidated affiliate			$ 0		$ 4,172	$ 2,225	4,172
Advantage Pipeline, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		30.00%
Proceeds from sale of unconsolidated affiliate	$ 2,200	$ 25,300		$ 1,100
Equity Method Investment, Summarized Financial Information, Revenue							3,150
Equity Method Investment, Summarized Financial Information, Cost of Sales							465
Equity Method Investment, Summarized Financial Information, Net income							$ 187
Gain on sale of unconsolidated affiliate		$ 4,200
Proceeds from Sale of Equity Method Investment, Percent Held In Escrow		10.00%

PROPERTY, PLANT AND EQUIPMENT43

PROPERTY, PLANT AND EQUIPMENT (Details) - USD ($) $ in Thousands	Apr. 24, 2018	Dec. 01, 2017	Apr. 18, 2017	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross				$ 565,689		$ 565,689		$ 612,660
Accumulated depreciation				269,978		269,978		316,591
Property, plant and equipment, net				295,711		295,711		296,069
Depreciation				6,700	$ 7,500	13,700	$ 15,300
Payments to Acquire Businesses, Gross						21,959	0
Land
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross				25,067		25,067		24,776
Land improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross				5,815		5,815		6,787
Pipelines and facilities
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross				167,624		167,624		166,004
Storage and terminal facilities
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross				319,344		319,344		370,056
Transportation equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross				1,056		1,056		3,293
Office property and equipment and other
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross				26,958		26,958		32,011
Pipeline linefill and tank bottoms
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross				11,694		11,694		3,233
Construction-in-progress
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross				8,131		$ 8,131		$ 6,500
Min | Land improvements
Property, Plant and Equipment [Line Items]
Estimated Useful Lives (Years)						10 years
Min | Pipelines and facilities
Property, Plant and Equipment [Line Items]
Estimated Useful Lives (Years)						5 years
Min | Storage and terminal facilities
Property, Plant and Equipment [Line Items]
Estimated Useful Lives (Years)						10 years
Min | Transportation equipment
Property, Plant and Equipment [Line Items]
Estimated Useful Lives (Years)						3 years
Min | Office property and equipment and other
Property, Plant and Equipment [Line Items]
Estimated Useful Lives (Years)						3 years
Max | Land improvements
Property, Plant and Equipment [Line Items]
Estimated Useful Lives (Years)						20 years
Max | Pipelines and facilities
Property, Plant and Equipment [Line Items]
Estimated Useful Lives (Years)						30 years
Max | Storage and terminal facilities
Property, Plant and Equipment [Line Items]
Estimated Useful Lives (Years)						35 years
Max | Transportation equipment
Property, Plant and Equipment [Line Items]
Estimated Useful Lives (Years)						10 years
Max | Office property and equipment and other
Property, Plant and Equipment [Line Items]
Estimated Useful Lives (Years)						20 years
Oklahoma [Member] | Asphalt Terminalling Services [Member]
Property, Plant and Equipment [Line Items]
Payments to Acquire Businesses, Gross							$ 22,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment				11,500		$ 11,500
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Finite-Lived Intangibles				7,600		7,600
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net				$ 2,900		$ 2,900
Texas [Member] | Crude Oil Trucking Services [Member]
Property, Plant and Equipment [Line Items]
Proceeds from Sale of Property Held-for-sale	$ 3,000
Gain (Loss) on Disposition of Assets	$ 400
Texas [Member] | Crude Oil Pipeline Services [Member]
Property, Plant and Equipment [Line Items]
Proceeds from Sale of Property Held-for-sale			$ 4,800
Gain (Loss) on Disposition of Assets			$ 100
Limited Partner [Member] | Ergon [Member]
Property, Plant and Equipment [Line Items]
Stock Issued During Period, Shares, Acquisitions		1,898,380
Stock Issued During Period, Value, Acquisitions		$ 10,200

DEBT (Credit Agreements) (Detai

DEBT (Credit Agreements) (Details)	Jun. 28, 2018USD ($)	May 11, 2017USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Jul. 26, 2018USD ($)	Dec. 31, 2017USD ($)
Debt Instrument [Line Items]
Maximum quarterly distribution					$ 10,700,000
Write-off of deferred debt issuance costs	$ 400,000	$ 700,000
Debt issuance costs, noncurrent, net			$ 3,802,000		3,802,000			$ 4,442,000
Payments for Debt issuance costs					309,000	$ 4,017,000
Amortization of debt issuance costs			256,000	$ 273,000	513,000	614,000
Interest expense for long-term debt			4,700,000	3,400,000	8,600,000	6,700,000
Capitalized interest			43,000	3,000	72,000	5,000
Long-term Debt, Excluding Current Maturities			349,592,000		349,592,000			307,592,000
Derivative, Notional Amount			100,000,000		100,000,000			$ 200,000,000
Interest Expense, Other			100,000	$ 400,000	$ 100,000	$ 800,000
Blueknight General Partners G. P., L.L.C. [Member]
Debt Instrument [Line Items]
Credit agreement change of control provision, General Partner ownership minimum					100.00%
Ergon [Member]
Debt Instrument [Line Items]
Credit agreement change of control provision, Ergon minimum control percentage					50.00%
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Revolving credit facility amount	450,000,000		400,000,000		$ 400,000,000
Maximum borrowing capacity including additional lenders			$ 600,000,000		$ 600,000,000
Debt instrument maximum covenant consolidated senior secured leverage ratio			3.50		3.50
Consolidated interest coverage (as a ratio), minimum permitted			2.50		2.50
Consolidated total leverage (as a ratio), actual			4.65		4.65
Consolidated interest coverage (as a ratio), actual			3.78		3.78
Write-off of deferred debt issuance costs	$ 400,000
Debt issuance costs, noncurrent, net		$ 900,000
Debt instrument, interest rate during period			5.39%	4.44%	5.18%	4.27%
Payments for Debt issuance costs			$ 309,000	$ 4,010,000	$ 300,000	$ 4,017,000
Revolving Credit Facility [Member] | Min
Debt Instrument [Line Items]
Unused capacity, commitment fee (as a percent)					0.375%
Debt instrument covenant, issued qualified senior notes			$ 200,000,000		$ 200,000,000
Revolving Credit Facility [Member] | Max
Debt Instrument [Line Items]
Unused capacity, commitment fee (as a percent)					0.50%
Revolving Credit Facility [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Revolver borrowings							$ 263,600,000
Unused borrowing capacity							133,000,000
Revolving Credit Facility [Member] | Federal funds rate [Member]
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)					0.50%
Revolving Credit Facility [Member] | Eurodollar rate [Member]
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)					1.00%
Revolving Credit Facility [Member] | Applicable margin based on ABR [Member] | Min
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)					1.00%
Revolving Credit Facility [Member] | Applicable margin based on ABR [Member] | Max
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)					2.00%
Revolving Credit Facility [Member] | Applicable margin based on Eurodollar rate [Member] | Min
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)					2.00%
Revolving Credit Facility [Member] | Applicable margin based on Eurodollar rate [Member] | Max
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)					3.00%
Letter of Credit [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Letters of credit outstanding							$ 3,400,000
Aggregate Principal Below Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), maximum permitted			4.75		4.75
Minimum acquisition costs					$ 15,000,000
Debt instrument covenant, issued qualified senior notes			$ 200,000,000		200,000,000
Aggregate Principal Above Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt instrument covenant, issued qualified senior notes			$ 200,000,000		$ 200,000,000
Provision One, Applicable Period One [Member] | Aggregate Principal Below Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), maximum permitted			5.50		5.50
Provision One, Applicable Period Two [Member] | Aggregate Principal Below Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), maximum permitted			5.25		5.25
Provision One, Applicable Period Three [Member] | Aggregate Principal Below Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), maximum permitted			5		5
Provision One, Applicable Period Four [Member] | Aggregate Principal Below Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), maximum permitted			4.75		4.75
Provision Two, Applicable Period One [Member] | Aggregate Principal Below Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), maximum permitted			5.25		5.25
Provision Three, Applicable Period One [Member] | Aggregate Principal Above Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), maximum permitted			5		5
Provision Three, Applicable Period Two [Member] | Aggregate Principal Above Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), maximum permitted			5.50		5.50

DEBT Derivative Instruments (De

DEBT Derivative Instruments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Interest Rate Swaps, Notional Amount	$ 100,000		$ 100,000		$ 200,000
Unrealized Gain (Loss) on Interest Rate Swaps	(40)	$ 223	314	$ 975
Other Current Assets [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Interest Rate Swap Assets - Current	157		157		68
Other Noncurrent Liabilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Interest Rate Swap Liabilities - Noncurrent	$ 0		$ 0		$ 225

NET INCOME PER LIMITED PARTNE46

NET INCOME PER LIMITED PARTNER UNIT (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Earnings Per Share [Abstract]
Net income	$ 1,785	$ 6,371	$ 6,227	$ 9,913
General partner interest in net income	28	256	259	465
Preferred interest in net income	6,279	6,279	12,557	12,558
Net loss available to limited partners	$ (4,522)	$ (164)	$ (6,589)	$ (3,110)
Basic and diluted weighted average number of units:
Common units	40,324	38,155	40,306	38,151
Weighted Average Restricted and Phantom Partnership Units Outstanding, Basic and Diluted	1,133	923	983	806
Total Weighted Average Limited Partnership Units Outstanding, Basic and Diluted	41,457	39,078	41,289	38,957
Basic and diluted net loss per common unit	$ (0.11)	$ 0	$ (0.16)	$ (0.08)

PARTNERS' CAPITAL AND DISTRIB47

PARTNERS' CAPITAL AND DISTRIBUTIONS Issuances Narrative (Details) - Ergon [Member] - Limited Partner [Member] $ in Millions	Dec. 01, 2017USD ($)shares
Capital Unit [Line Items]
Value of stock issued during the period for acquisitions | $	$ 10.2
Common units issued during the period for acquisitions | shares	1,898,380

PARTNERS' CAPITAL AND DISTRIB48

PARTNERS' CAPITAL AND DISTRIBUTIONS Cash Distributions Paid on Preferred Units (Details) - Preferred Units [Member] $ / shares in Units, $ in Millions	3 Months Ended
	Jun. 30, 2018USD ($)$ / shares
Preferred and General Partners [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Cash Distributions Declared	$ 6.4
Preferred Partner [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit | $ / shares	$ 0.17875
Distribution Made to Limited Partner, Cash Distributions Declared	$ 6.3
General Partner [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Cash Distributions Declared	$ 0.1

PARTNERS' CAPITAL AND DISTRIB49

PARTNERS' CAPITAL AND DISTRIBUTIONS Cash Distributions Paid on Common Units (Details) - Common Units [Member] $ / shares in Units, $ in Millions	3 Months Ended
	Jun. 30, 2018USD ($)$ / shares
Limited, General Partner, Phantom Share and Restricted Units [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Cash Distributions Declared	$ 3.4
Limited Partner [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit | $ / shares	$ 0.0800
Distribution Made to Limited Partner, Cash Distributions Declared	$ 3.2
General Partner [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Cash Distributions Declared	0.1
Phantom Share Units and Restricted Units [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Cash Distributions Declared	$ 0.1

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Related Party Transaction [Line Items]
Receivables from related parties	$ 1,219		$ 1,219		$ 3,070
Accounts payable to related parties	$ 12,878		$ 12,878		2,268
Noncontrolling Interest, Ownership Percentage by Parent	50.00%		50.00%
Ergon [Member]
Related Party Transaction [Line Items]
Related-party revenue	$ 13,500	$ 13,500	$ 27,500	$ 26,800
Receivables from related parties	1,219		1,219		3,100
Payables to Related Parties	$ 5,300		$ 5,300		$ 1,600
Joint Venture Purchase Option	100.00%		100.00%
Advantage Pipeline, L.L.C. [Member]
Related Party Transaction [Line Items]
Related-party revenue				$ 300
Crude Oil Purchase Agreement [Member] | Ergon [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Purchases from Related Party	$ 30,000		$ 30,000
Accounts payable to related parties	$ 9,800		$ 9,800

LONG-TERM INCENTIVE PLAN (Detai

LONG-TERM INCENTIVE PLAN (Details) - USD ($) $ / shares in Units, $ in Thousands

1 Months Ended

3 Months Ended

6 Months Ended

Mar. 31, 2018

Dec. 31, 2017

Mar. 31, 2017

Dec. 31, 2016

Oct. 31, 2016

Mar. 31, 2016

Jun. 30, 2018

Jun. 30, 2017

Jun. 30, 2018

Jun. 30, 2017

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Equity-based incentive compensation expense (in dollars)

$ 687

$ 524

Blueknight Energy Partners G.P., L.L.C. Long-Term Incentive Plan [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Number of units authorized

4,100,000

4,100,000

Number of Units [Roll Forward]

Nonvested at December 31, 2017

923,551

Granted

457,984

Vested

241,629

Forfeited

10,865

Nonvested at June 30, 2018

923,551

1,129,041

1,129,041

Weighted Average Grant Date Fair Value [Roll Forward]

Weighted Average Grant Date Fair Value, Nonvested, Beginning balance (in dollars per unit)

$ 6.29

Weighted Average Grant Date Fair Value, Granted (in dollars per unit)

4.77

Weighted Average Grant Date Fair Value, Vested (in dollars per unit)

7.46

Weighted Average Grant Date Fair Value, Forfeited (in dollars per unit)

5.39

Weighted Average Grant Date Fair Value, Nonvested, Ending balance (in dollars per unit)

$ 6.29

$ 5.88

$ 5.88

Blueknight Energy Partners G.P., L.L.C. Long-Term Incentive Plan [Member] | Common Stock [Member] | Independent Directors [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Value of award grants (in dollars)

$ 69

$ 70

Number of Units [Roll Forward]

Granted

14,286

10,220

Weighted Average Grant Date Fair Value [Roll Forward]

Weighted Average Grant Date Fair Value, Granted (in dollars per unit)

[1]

$ 4.85

$ 6.85

Blueknight Energy Partners G.P., L.L.C. Long-Term Incentive Plan [Member] | Phantom common units [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Unrecognized estimated compensation cost (in dollars)

$ 3,100

$ 3,100

Equity-based incentive compensation expense (in dollars)

$ 600

$ 600

$ 1,100

$ 1,100

Blueknight Energy Partners G.P., L.L.C. Long-Term Incentive Plan [Member] | Restricted common units [Member] | Independent Directors [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Vesting period

3 years

Value of award grants (in dollars)

$ 74

$ 75

Number of Units [Roll Forward]

Granted

15,306

10,950

Weighted Average Grant Date Fair Value [Roll Forward]

Weighted Average Grant Date Fair Value, Granted (in dollars per unit)

$ 4.85

[1]

$ 6.85

[2]

January 2019 Vesting [Member] | Blueknight Energy Partners G.P., L.L.C. Long-Term Incentive Plan [Member] | Phantom common units [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Value of award grants (in dollars)

$ 58

$ 1,985

Number of Units [Roll Forward]

Granted

9,960

416,131

Weighted Average Grant Date Fair Value [Roll Forward]

Weighted Average Grant Date Fair Value, Granted (in dollars per unit)

[3]

$ 5.85

$ 4.77

January 2020 Vesting [Member] | Blueknight Energy Partners G.P., L.L.C. Long-Term Incentive Plan [Member] | Phantom common units [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Value of award grants (in dollars)

$ 2,312

Number of Units [Roll Forward]

Granted

323,339

Weighted Average Grant Date Fair Value [Roll Forward]

Weighted Average Grant Date Fair Value, Granted (in dollars per unit)

[3]

$ 7.15

January 2021 Vesting [Member] | Blueknight Energy Partners G.P., L.L.C. Long-Term Incentive Plan [Member] | Phantom common units [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Value of award grants (in dollars)

$ 2,185

Number of Units [Roll Forward]

Granted

457,984

Weighted Average Grant Date Fair Value [Roll Forward]

Weighted Average Grant Date Fair Value, Granted (in dollars per unit)

[3]

$ 4.77

[1]

Fair value is the closing market price on the grant date of the awards.

[2]

Fair value is the closing market price on the grant date of the awards.

[3]

Fair value is the closing market price on the grant date of the awards.

EMPLOYEE BENEFIT PLAN (Details)

EMPLOYEE BENEFIT PLAN (Details) - Blueknight Energy Partners G.P., L.L.C. 401(K) Plan [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Pension Plan [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer discretionary contribution amount	$ 0.3	$ 0.3	$ 0.6	$ 0.6
Other Postretirement Benefits Plan [Member]
Defined Contribution Plan Disclosure [Line Items]
Employer discretionary contribution amount	$ 0.1	$ 0.2	$ 0.1	$ 0.4

EMPLOYEE BENEFIT PLAN EUPP (Det

EMPLOYEE BENEFIT PLAN EUPP (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
EUPP [Abstract]
Employee Stock Ownership Plan (ESOP), Shares in ESOP	1,000,000		1,000,000
Employee Stock Ownership Plan (ESOP), Compensation Expense	$ 0.1	$ 0.1	$ 0.1	$ 0.1

FAIR VALUE MEASUREMENTS Fair 54

FAIR VALUE MEASUREMENTS Fair Value Measurements (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest rate swap assets	$ 157	$ 68
Total Swap Assets	157	68
Interest rate swap liabilities	0	225
Total swap liabilities		225
Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest rate swap assets	0	0
Total Swap Assets	0	0
Interest rate swap liabilities		0
Total swap liabilities		0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest rate swap assets	157	68
Total Swap Assets	157	68
Interest rate swap liabilities		225
Total swap liabilities		225
Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest rate swap assets	0	0
Total Swap Assets	$ 0	0
Interest rate swap liabilities		0
Total swap liabilities		$ 0

OPERATING SEGMENTS (Details)

OPERATING SEGMENTS (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)Operating-segments	Jun. 30, 2017USD ($)	Jul. 26, 2018Terminalling_And_Storage_Facilities	Dec. 31, 2017USD ($)
Segment Reporting Information [Line Items]
Number of operating segments (in operating segments) | Operating-segments			4
Service revenue
Third-party revenue	$ 14,103	$ 28,145	$ 31,421	$ 56,808
Sales revenue from related parties, services, net	6,063	13,505	12,384	27,147
Lease revenue:
Third-party revenue	10,237	0	20,041	0
Related-party revenue	7,475	0	15,178	0
Product sales revenue:
Third-party revenue	45,615	2,227	49,129	6,262
Total revenue for reportable segments	83,493	43,877	128,153	90,217
Third-party cost of product sales	20,041	1,669	22,678	4,808
Related-party cost of product sales	23,747	0	23,747	0
Operating margin, excluding depreciation and amortization	18,130	19,437	36,384	38,798
Total assets (end of period)	390,506		390,506			$ 340,869
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes
Operating margin, excluding depreciation and amortization	18,130	19,437	36,384	38,798
Depreciation and amortization	(7,413)	(7,839)	(14,779)	(15,905)
General and administrative expense	(4,486)	(4,322)	(8,707)	(8,907)
Asset impairment expense	0	(17)	(616)	(45)
Gain (loss) on sale of assets	599	(754)	363	(879)
Interest expense	(5,024)	(4,265)	(8,593)	(7,295)
Gain on sale of unconsolidated affiliate	0	4,172	2,225	4,172
Equity earnings in unconsolidated affiliate	0	0	0	61
Income before income taxes	1,806	6,412	6,277	10,000
Asphalt Terminalling Services [Member]
Service revenue
Third-party revenue	6,639	13,259	11,771	26,482
Related-party revenue	5,981	13,505
Sales revenue from related parties, services, net			12,302	26,837
Lease revenue:
Third-party revenue	10,016	0	19,473	0
Related-party revenue	7,475	0	15,178	0
Product sales revenue:
Total revenue for reportable segments	30,111	26,764	58,724	53,319
Operating expenses (excluding depreciation and amortization)	13,393	11,935	26,728	24,255
Operating margin, excluding depreciation and amortization	16,718	14,829	31,996	29,064
Total assets (end of period)	167,849	147,832	167,849	147,832
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes
Operating margin, excluding depreciation and amortization	16,718	14,829	31,996	29,064
Crude Oil Terminalling Services [Member]
Service revenue
Third-party revenue	2,910	5,726	7,496	11,851
Intersegment Revenues	170	0	170	0
Lease revenue:
Third-party revenue	12	0	27	0
Product sales revenue:
Total revenue for reportable segments	3,092	5,726	7,693	11,851
Operating expenses (excluding depreciation and amortization)	913	992	2,188	2,003
Operating margin, excluding depreciation and amortization	2,179	4,734	5,505	9,848
Total assets (end of period)	67,150	69,834	67,150	69,834
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes
Operating margin, excluding depreciation and amortization	2,179	4,734	5,505	9,848
Crude Oil Pipeline Services [Member]
Service revenue
Third-party revenue	1,045	2,720	3,105	5,324
Related-party revenue	82	0
Sales revenue from related parties, services, net			82	310
Lease revenue:
Third-party revenue	177	0	412	0
Product sales revenue:
Third-party revenue	45,612	2,227	49,120	5,877
Total revenue for reportable segments	46,916	4,947	52,719	11,511
Operating expenses (excluding depreciation and amortization)	2,542	3,142	5,327	6,383
Intersegment operating expenses	1,156	74	1,599	244
Third-party cost of product sales	20,041	1,669	22,678	4,808
Related-party cost of product sales	23,747	0	23,747	0
Operating margin, excluding depreciation and amortization	(570)	62	(632)	76
Total assets (end of period)	152,105	117,222	152,105	117,222
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes
Operating margin, excluding depreciation and amortization	(570)	62	(632)	76
Crude Oil Trucking Services [Member]
Service revenue
Third-party revenue	3,509	6,440	9,049	13,151
Intersegment Revenues	986	74	1,429	244
Lease revenue:
Third-party revenue	32	0	129	0
Product sales revenue:
Third-party revenue	3	0	9	385
Total revenue for reportable segments	4,530	6,514	10,616	13,780
Operating expenses (excluding depreciation and amortization)	4,727	6,702	11,101	13,970
Operating margin, excluding depreciation and amortization	(197)	(188)	(485)	(190)
Total assets (end of period)	3,402	11,208	3,402	11,208
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes
Operating margin, excluding depreciation and amortization	(197)	(188)	(485)	(190)
Operating Segments [Member]
Service revenue
Intersegment Revenues	(1,156)	(74)	(1,599)	(244)
Product sales revenue:
Total revenue for reportable segments	$ 84,649	$ 43,951	$ 129,752	$ 90,461
Subsequent Event [Member] | Asphalt Terminalling Services [Member]
Segment Reporting Information [Line Items]
Number of terminalling and storage facilities providing asphalt product and residual fuel terminalling storage and blending services (in terminalling and storage facilities) | Terminalling_And_Storage_Facilities					53
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes
Number of states where Asphalt terminalling and storage facilities are located | Terminalling_And_Storage_Facilities					26

INCOME TAXES (Details)

INCOME TAXES (Details) $ in Thousands	Jun. 30, 2018USD ($)
Valuation Allowance [Line Items]
Difference in bases of property, plant and equipment	$ 444
Deferred tax asset, operating loss carryforwards	11
Deferred tax asset	455
Less: valuation allowance	444
Net deferred tax asset	$ 11

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) $ in Millions	Jul. 13, 2018USD ($)
Asphalt Terminalling Services [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Proceeds from Sale of Property Held-for-sale	$ 90