Blueknight Energy Partners (BKEP) 10-K 12 Mar 14 2013 Q4 Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Mar. 07, 2014	Jun. 30, 2013
Entity Information [Line Items]	'	'	'
Entity Registrant Name	'Blueknight Energy Partners, L.P.	'	'
Entity Central Index Key	'0001392091	'	'
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	'	'
Entity Public Float	'	'	$93
Entity Common Stock, Shares Outstanding	'	22,925,092	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'Q4	'	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$3,182	$3,177
Accounts receivable, net of allowance for doubtful accounts of $469 and $69 at December 31, 2012 and 2013, respectively	12,244	9,948
Receivables from related parties, net of allowance for doubtful accounts of $0 for both dates	3,149	3,522
Prepaid insurance	1,694	1,237
Assets held for sale, net of accumulated depreciation and impairments of $450 and $166 at December 31, 2012 and 2013, respectively	338	281
Other current assets	4,321	1,822
Total current assets	24,928	19,987
Property, plant and equipment, net of accumulated depreciation of $153,216 and $171,056 at December 31, 2012 and 2013, respectively	297,400	267,741
Investment in unconsolidated affiliate	19,498	0
Goodwill	7,216	7,216
Debt issuance costs, net	3,580	3,225
Intangibles and other assets, net	2,126	1,656
Total assets	354,748	299,825
Current liabilities:	'	'
Accounts payable	6,537	10,052
Accrued interest payable	482	164
Accrued interest payable to related parties	0	304
Accrued property taxes payable	1,810	1,938
Unearned revenue	2,326	4,068
Unearned revenue with related parties	90	316
Accrued payroll	7,379	6,409
Other current liabilities	4,959	4,032
Current portion of long-term payable to related parties	0	1,881
Total current liabilities	23,583	29,164
Long-term payable to related parties	153	800
Other long-term liabilities	2,554	206
Long-term debt (including $15.0 million with related parties at December 31, 2012)	273,000	211,000
Commitments and contingencies (Note 16)	'	'
Partners’ capital:	'	'
Series A Preferred Units (30,158,619 units issued and outstanding for both dates)	204,599	204,599
Common unitholders (22,675,135 and 22,786,101 units issued and outstanding at December 31, 2012 and December 31, 2013, respectively)	461,149	464,433
General partner interest (2.1% with 1,127,755 general partner units outstanding for both dates)	-610,290	-610,377
Total Partners’ capital	55,458	58,655
Total liabilities and Partners’ capital	$354,748	$299,825

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Current assets:	'	'
Accounts receivable, allowance for doubtful accounts	$69,000	$469,000
Receivables from related parties, allowance for doubtful accounts	0	0
Accumulated Depreciation and Impairments, Assets held for sale	166,000	450,000
Accumulated Depreciation and Impairments, property plant and equipment	171,056,000	153,216,000
LIABILITIES AND PARTNERS’ CAPITAL	'	'
Long-term debt with related parties	$0	$15,000,000
Partners’ capital:	'	'
Series A Preferred unitholders, units issued	30,158,619	30,159,958
Series A Preferred unitholders, units outstanding	30,158,619	30,159,958
Common unitholders, units issued	22,781,746	22,675,135
Common unitholders, units outstanding	22,781,746	22,675,135
General partner interest, units outstanding	1,127,755	1,127,755
General partner percentage interest	2.10%	2.10%

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Service revenue:	'	'	'
Third party revenue	$142,916	$130,696	$129,104
Related party revenue	51,755	48,153	44,089
Total revenue	194,671	178,849	173,193
Expenses:	'	'	'
Operating	133,610	122,746	114,731
General and administrative	17,482	19,795	17,311
Total expenses	151,092	142,541	132,042
Gain on sale of assets	1,073	7,271	3,008
Asset impairment expense	-524	-1,942	-867
Operating income	44,128	41,637	43,292
Other income (expense):	'	'	'
Equity loss in unconsolidated affiliate	-502	0	0
Interest expense (net of capitalized interest of $21, $150 and $1,048, respectively)	-11,615	-11,705	-32,898
Change in fair value of embedded derivative within convertible debt	0	0	20,224
Change In Fair Value Of Rights Offering Liability	0	0	1,883
Income from continuing operations before income taxes	32,011	29,932	32,501
Provision for income taxes	593	318	287
Income from continuing operations	31,418	29,614	32,214
Income (loss) from discontinued operations (including asset impairment expense of $6,353 for the year ended December 31, 2013) (See Note 5)	-3,383	1,951	1,261
Net Income	28,035	31,565	33,475
Allocation of net income for calculation of earnings per unit:	'	'	'
General partner interest in net income	647	774	912
Preferred interest in net income	21,564	21,564	16,446
Accretion of discount on increasing rate preferred units	0	0	-2,243
Beneficial conversion feature attributable to preferred units	0	1,853	43,259
Beneficial Conversion Feature Attributable To Repurchased Preferred Units	0	0	6,892
Gain on extinguishment attributable to redemption of convertible debt, recorded as a capital transaction	0	0	2,375
Income (loss) available to limited partners	$5,824	$7,374	($20,118)
Basic and diluted income (loss) from continuing operations per common unit	$0.39	$0.24	($0.65)
Basic and diluted income (loss) from discontinued operations per common unit	($0.14)	$0.08	$0.04
Basic net income (loss) per common unit	$0.25	$0.32	($0.61)
Basic and diluted net loss from continuing operations per subordinated unit	$0	$0	($0.55)
Basic and diluted income (loss) from discontinued operations per subordinated unit	$0	$0	$0.03
Basic and diluted net loss per subordinated unit	$0	$0	($0.52)
Weighted average common units outstanding - basic	22,706,000	22,666,000	22,059,000
Weighted Average Subordinated Partnership Units Outstanding Basic And Diluted	0	0	8,817,000

CONSOLIDATED_STATEMENTS_OF_OPE1

CONSOLIDATED STATEMENTS OF OPERATIONS (Parenthetical) (USD $)	12 Months Ended
Share data in Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement [Abstract]	'	'	'
Interest Costs Capitalized	$1,047,749.36	$150,412.62	$20,600.30
Gain (Loss) on Disposition of Real Estate, Discontinued Operations	$6,353,246.14	$0	$0
Income (Loss) from Continuing Operations, Per Diluted Share	$0.39	$0.24	($0.65)
Basic and diluted income (loss) from discontinued operations per common unit (usd per unit)	($0.14)	$0.08	$0.04
Diluted net income per common unit	$0.25	$0.32	($0.61)
Weighted average common units outstanding - diluted	22,706	22,666	22,059

CONSOLIDATED_STATEMENTS_OF_CHA

CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL (USD $)	Total	Common Unitholders [Member]	Subordinated Unitholders [Member]	Preferred Stock [Member]	General Partner Interest [Member]
In Thousands, unless otherwise specified
Balance at Dec. 31, 2010	($37,743)	$478,575	($286,264)	$91,376	($321,430)
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'
Net income	33,475	15,721	5,674	11,375	705
Partners' Capital Account, Unit-based Compensation	544	409	124	'	11
Amortization Of Beneficial Conversion Feature Of Preferred Units	'	-31,895	-11,364	43,259	'
Accretion Of Discount On Preferred Units	'	-2,243	'	2,243	'
Distributions	-11,615	'	'	-11,375	-240
Debt conversion option classified as equity	7,326	7,326	'	'	'
Contribution and cancellation of subordinated units	'	'	291,830	'	-291,830
Settlement of Class Action Litigation	5,200	5,200	'	'	'
Clawback Of LTIP Awards	-825	-804	'	'	-21
Repurchase of preferred units	-20,966	-1,270	'	-19,696	'
Proceeds from Rights Offering	77,005	'	'	77,005	'
Settlement of rights offering liability	8,559	'	'	8,559	'
Gain On Extinguishment Attributable To Redemption Of Convertible Debt	2,375	'	'	'	2,375
Fair Value Of Debt Conversion Option On Reacquisition Date	-5,536	-5,536	'	'	'
Balance at Dec. 31, 2011	57,799	465,483	0	202,746	-610,430
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'
Net income	31,565	9,662	'	21,244	659
Partners' Capital Account, Unit-based Compensation	1,897	1,856	'	'	41
Settlement of equity-based compensation agreement	-453	-443	'	'	-10
Amortization Of Beneficial Conversion Feature Of Preferred Units	'	-1,853	'	1,853	'
Profits interest contribution	36	'	'	'	36
Distributions	-32,189	-10,272	'	-21,244	-673
Balance at Dec. 31, 2012	58,655	464,433	0	204,599	-610,377
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'
Net income	28,035	5,885	'	21,564	586
Partners' Capital Account, Unit-based Compensation	1,912	1,864	'	'	48
Profits interest contribution	150	'	'	'	150
Distributions	-33,294	-11,033	'	-21,564	-697
Balance at Dec. 31, 2013	$55,458	$461,149	$0	$204,599	($610,290)

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash flows from operating activities:	'	'	'
Net income	$28,035	$31,565	$33,475
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Provision for uncollectible receivables from third parties	400	-6	-47
Depreciation and amortization	24,241	23,129	22,775
Impairment of Intangible Assets	0	96	0
Amortization and write-off of debt issuance costs	3,326	1,775	1,955
Amortization of subordinated debenture discount	0	0	15,142
Change in fair value of embedded derivative within convertible debt	0	0	-20,224
Change in fair value of rights offering liability	0	0	-1,883
Tangible Asset Impairment Charges	6,877	1,846	867
Gain on sale of assets	2,661	7,250	3,008
Equity-based incentive compensation	1,912	1,897	544
Clawback of LTIP Awards	0	0	-825
Settlement of Equity Based Compensation Agreement	0	-453	0
Equity loss in unconsolidated affiliate	502	0	0
Changes in assets and liabilities	'	'	'
Decrease (increase) in accounts receivable	-3,970	4,249	-5,320
Decrease (increase) in receivables from related parties	373	875	-2,485
Decrease in prepaid insurance	2,333	2,430	1,404
Decrease (increase) in other current assets	-2,499	16	-216
Decrease (increase) in other assets	50	-6	1,163
Decrease in accounts payable	-417	-1,281	-1,623
Increase (decrease) in accrued interest payable	318	-67	-126
Decrease in accrued interest payable to related parties	-304	-58	-852
Increase (decrease) in accrued property taxes	-128	125	-441
Increase (decrease) in unearned revenue	150	3,278	-2,716
Decrease in unearned revenue from related parties	-73	-833	-1,005
Increase in accrued payroll	970	1,183	1,096
Increase (decrease) in other accrued liabilities	1,116	-790	-488
Net cash provided by operating activities	60,551	61,720	37,162
Cash flows from investing activities:	'	'	'
Acquisitions	0	0	-133
Capital expenditures	-64,956	-27,717	-17,998
Proceeds from sale of assets	4,258	10,206	7,491
Investment in unconsolidated affiliate	-20,000	0	0
Net cash used in investing activities	-80,698	-17,511	-10,640
Cash flows from financing activities:	'	'	'
Payment on insurance premium financing agreement	-2,342	-1,482	-1,194
Debt issuance costs	-3,681	0	-280
Payments on long-term payable to related party	-2,681	-1,636	-1,183
Borrowings under credit facility	342,411	37,000	7,000
Payments under credit facility	-280,411	-44,000	-28,862
Redemption of convertible subordinated debentures	0	0	-50,028
Proceeds from equity issuances, net of offering costs	0	0	77,005
Payments for Repurchase of Preferred Stock and Preference Stock	0	0	-20,966
Capital contribution related to profits interest	150	36	0
Distributions	-33,294	-32,189	-11,615
Net cash provided by (used in) financing activities	20,152	-42,271	-30,123
Net increase (decrease) in cash and cash equivalents	5	1,938	-3,601
Cash and cash equivalents at beginning of period	3,177	1,239	4,840
Cash and cash equivalents at end of period	3,182	3,177	1,239
Supplemental disclosure of cash flow information:	'	'	'
Increase (decrease) in accounts payable related to purchase of property, plant and equipment	-3,098	-1,195	2,932
Increase in accrued liabilities related to insurance premium financing agreement	2,609	1,580	1,278
Non-cash issuance of common units in settlement of the Class Action Litigation	0	0	5,200
Settlement Of Rights Offering Liability	0	0	8,559
Reclassification Of Fair Value Of Debt Conversion Option At Reacquisition Date	0	0	-5,536
Capital Contribution Related To Redemption Of Convertible Debt	0	0	2,375
Decrease (Increase) in accounts receivable related to purchase of property, plant and equipment	1,274	0	0
Interest Paid, Net	9,644	10,441	16,817
Income Taxes Paid	$419	$289	$209

ORGANIZATION_AND_NATURE_OF_BUS

ORGANIZATION AND NATURE OF BUSINESS	12 Months Ended
	Dec. 31, 2013
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 twenty-two states. The Partnership provides integrated terminalling, storage, processing, gathering and transportation 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) crude oil terminalling and storage services, (ii) crude oil pipeline services, (iii) crude oil trucking and producer field services and (iv) asphalt services. 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_PRE

BASIS OF CONSOLIDATION AND PRESENTATION	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
BASIS OF CONSOLIDATION AND PRESENTATION	'
	BASIS OF CONSOLIDATION AND PRESENTATION
	The accompanying financial statements have been prepared assuming that the Partnership will continue as a going concern.  The financial statements have been prepared in accordance with accounting principles and practices generally accepted in the United States of America (“GAAP”).  All significant intercompany accounts and transactions have been eliminated in the preparation of the accompanying financial statements. Certain reclassifications have been made in the consolidated financial statements for the years ended December 31, 2011 and 2012 to conform to the 2013 financial statement presentation.  This was a reclassification of asset impairment expense from operating expenses to a separate component of operating income, and a recasting of amounts related to discontinued operations (see Note 5).  The reclassification has no impact on net income.

RECENT_EVENTS

RECENT EVENTS	12 Months Ended
	Dec. 31, 2013
RECENT EVENTS [Abstract]	'
RECENT EVENTS	'
	RECENT EVENTS
	On February 4, 2013, the Partnership announced that it entered into an agreement with Advantage Pipeline to acquire approximately 30% ownership in a 70 mile crude oil pipeline project running from Pecos, Texas to Crane, Texas (the “Pecos River Pipeline”). The Pecos River Pipeline is a new 16" diameter pipeline that will enable west Texas producers to deliver crude oil to Gulf Coast markets through a pipeline connection at Crane, Texas. On September 17, 2013, commercial service started on Phase I of the system consisting of the Highway 18 Station near Grandfalls, Texas and 36 miles of pipeline connecting to the Longhorn Pipeline in Crane, Texas. The Partnership operates the pipeline under a long term agreement with Advantage Pipeline (see Note 12).
	On June 28, 2013, the Partnership entered into an amended and restated credit agreement which consists of a $400.0 million revolving loan facility (see Note 8).

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Notes)	12 Months Ended
	Dec. 31, 2013
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES [Abstract]	'
Significant Accounting Policies [Text Block]	'
	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	USE OF ESTIMATES -The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts and disclosure of contingencies. Management makes significant estimates including: (1) allowance for doubtful accounts receivable; (2) estimated useful lives of assets, which impacts depreciation; (3) estimated cash flows and fair values inherent in impairment tests; (4) accruals related to revenues and expenses; (5) the estimated fair value of financial instruments; and (6) liability and contingency accruals. Although management believes these estimates are reasonable, actual results could differ from these estimates.
	CASH AND CASH EQUIVALENTS - The Partnership includes as cash and cash equivalents, cash and all investments with maturities at date of purchase of three months or less which are readily convertible into known amounts of cash.
	ACCOUNTS RECEIVABLE - The majority of the Partnership’s accounts receivable relates to its trucking and producer field services and asphalt services activities. Accounts receivable included in the balance sheets are reflected net of the allowance for doubtful accounts of $0.5 million and $0.1 million at December 31, 2012 and 2013, respectively.
	The Partnership reviews all outstanding accounts receivable balances on a monthly basis and records a reserve for amounts that the Partnership expects will not be fully recovered. Although the Partnership considers its allowance for doubtful trade accounts receivable to be adequate, there is no assurance that actual amounts will not vary significantly from estimated amounts.
	PROPERTY, PLANT AND EQUIPMENT - Property, plant and equipment are recorded at cost. Expenditures for maintenance and repairs that do not add capacity or extend the useful life of an asset are expensed as incurred. The carrying value of the assets is based on estimates, assumptions and judgments relative to useful lives and salvage values. As assets are disposed of, the cost and related accumulated depreciation are removed from the accounts, and any resulting gain or loss is included in operating income in the statements of operations.
	Depreciation is calculated using the straight-line method, based on estimated useful lives of the assets. These estimates are based on various factors including age (in the case of acquired assets), manufacturing specifications, technological advances and historical data concerning useful lives of similar assets. Uncertainties that impact these estimates include changes in laws and regulations relating to restoration and abandonment requirements, economic conditions and supply and demand in the area. When assets are put into service, management makes estimates with respect to useful lives and salvage values that it believes are reasonable. However, subsequent events could cause management to change its estimates, thus impacting the future calculation of depreciation.
	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 (see Note 16).  Such obligations are recognized in the period incurred if reasonably estimable.
	IMPAIRMENT OF LONG-LIVED ASSETS AND OTHER INTANGIBLE ASSETS - Long-lived assets with recorded values that are not expected to be recovered through future cash flows are written-down to estimated fair value. A long-lived asset is tested for impairment when events or circumstances indicate that its carrying value may not be recoverable. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the carrying value exceeds the sum of the undiscounted cash flows, an impairment loss equal to the amount by which the carrying value exceeds the fair value of the asset is recognized. Fair value is generally determined from estimated discounted future net cash flows.  The Partnership recognized impairment charges of $0.5 million and $0.3 million during the year ended December 31, 2011 related to an office building located in St. Louis, Missouri and an office building located in Abilene, Texas, respectively.  As of December 31, 2011, the office building in Abilene, Texas was classified as held for sale, and the Partnership subsequently sold this asset in January of 2012. The Partnership recognized total fixed asset impairment charges of $1.8 million during the year ended December 31, 2012 that included $1.0 million related to Oklahoma gathering pipeline assets and $0.7 million related to a Bay City, Michigan residual fuel oil facility. The Oklahoma gathering pipeline assets were sold during the summer of 2013 and demolition began on the Bay City facility in December 2013. The Partnership recognized total fixed asset impairment charges of $6.9 million during the year ended December 31, 2013 that included $5.7 million related to the Thompson pipeline system located in southern Texas. This system was sold in December 2013 (see Note 5).
	Acquired customer relationships and non-compete agreements are capitalized and amortized over useful lives ranging from 4 to 20 years using the straight-line method of amortization. An impairment loss is recognized for definite-lived intangibles if the carrying amount of an intangible asset is not recoverable and its carrying amount exceeds its fair value. No impairment charge was recognized in the twelve months ended December 31, 2011 and 2013 with respect to amortizable intangibles. In December 2012, the Partnership recognized an impairment loss of $0.1 million related to a non-compete agreement due to the death of the counterpart to the agreement.
	EQUITY METHOD INVESTMENTS - The Partnership’s investment in Advantage Pipeline, L.L.C. (“Advantage Pipeline”), over which the Partnership has significant influence but not control, is accounted for by the equity method. The Partnership does not consolidate any part of the assets or liabilities of its equity investee. As of December 31, 2013, the Partnership's investment represents a 30% ownership interest in Advantage Pipeline. The Partnership’s share of net income or loss is reflected as one line item on the Partnership’s Consolidated Statements of Operations entitled “Equity earnings in unconsolidated affiliate” and will increase or decrease, as applicable, the carrying value of the Partnership’s investment in the unconsolidated affiliate on the balance sheet. Distributions to the Partnership will reduce the carrying value of its investment and will be reflected in the Partnership’s Consolidated Statements of Cash Flows in the line item “Distributions from unconsolidated affiliate.” In turn, contributions will increase the carrying value of the Partnership’s investment and will be reflected in the Partnership’s Consolidated Statements of Cash Flows in investing activities. The Partnership evaluates its equity investment for impairment in accordance with FASB guidance with respect to the equity method of accounting for investments in common stock. An impairment of an equity investment results when factors indicate that the investment’s fair value is less than its carrying value and the reduction in value is other than temporary in nature.
	DEBT ISSUANCE COSTS - Costs incurred in connection with the issuance of long-term debt related to the Partnership’s credit facilities are capitalized and amortized using the straight-line method over the term of the related debt. Use of the straight-line method does not differ materially from the “effective interest” method of amortization.
	GOODWILL - Goodwill represents the excess of the cost of acquisitions over the amounts assigned to assets acquired and liabilities assumed. Goodwill is not amortized but is tested annually for impairment and when events and circumstances warrant an interim evaluation. Goodwill is tested for impairment at a level of reporting referred to as a reporting unit. The Partnership has four reporting units comprised of (i) its crude oil terminalling and storage services, (ii) its crude oil pipeline services, (iii) its crude oil trucking and producer field services, and (iv) its asphalt services.  The Partnership has recorded goodwill of $6.3 million related to its crude oil pipeline services reporting unit and $0.9 million related to its crude oil trucking and producer field services reporting unit. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is considered not impaired. The impairment test is generally based on the estimated discounted future net cash flows of the respective reporting unit, utilizing discount rates and other factors in determining the fair value of the reporting unit.  Inputs in our estimated discounted future net cash flows include existing and estimated future asset utilization, estimated growth rates in future cash flows, and estimated terminal values (these are all considered level 3 inputs). The Partnership did not recognize any impairment of goodwill, including in its most recent impairment test conducted in the fourth quarter of 2013.
	ENVIRONMENTAL MATTERS - Liabilities for loss contingencies, including environmental remediation costs, arising from claims, assessments, litigation, fines, penalties and other sources are charged to expense when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated. The Partnership recorded loss contingencies related to environmental matters of $0.2 million and $1.8 million as of December 31, 2012 and 2013, respectively.
	REVENUE RECOGNITION - The Partnership’s revenues consist of (i) terminalling and storage revenues, (ii) gathering, transportation and producer field services revenues and (iii) fuel surcharge revenues.
	Terminalling and storage revenues consist of (i) storage service fees from actual storage used on a month-to-month basis; (ii) storage service fees resulting from short-term and long-term contracts for committed space that may or may not be utilized by the customer in a given month; and (iii) terminal throughput service charges to pump crude oil to connecting carriers or to deliver asphalt product out of the Partnership’s terminals. Terminal throughput service charges are recognized as the crude oil exits the terminal and is delivered to the connecting crude oil carrier or third-party terminal and as the asphalt product is delivered out of the Partnership’s terminal. Storage service revenues are recognized as the services are provided and the amounts earned on a monthly basis.
	Gathering and transportation services revenues consist of service fees recognized for the gathering of crude oil for the Partnership’s customers and the transportation of the crude oil to refiners, to common carrier pipelines for ultimate delivery to refiners, or to terminalling and storage facilities owned by the Partnership and others. Revenue for the gathering and transportation of crude oil is recognized when the service is performed and is based upon regulated and non-regulated tariff rates and the related transport volumes.  Producer field services revenue consists of a number of services ranging from gathering condensates from natural gas producers to hauling produced water to disposal wells.  Revenue for producer field services is recognized when the service is performed.
	Fuel surcharge revenues are comprised of revenues recognized for the reimbursement of fuel and power consumed to operate the Partnership’s asphalt product storage tanks and terminals.  The Partnership recognizes fuel surcharge revenues in the period in which the related fuel and power expenses are incurred.
	INCOME AND OTHER TAXES - For federal and most state income tax purposes, the majority of income, gains, losses, expenses, deductions and tax credits generated by the Partnership flow through to the unitholders of the Partnership. In 2007, the state of Texas implemented a partnership-level tax based on a percentage of the revenue earned for services provided in the state of Texas. The Partnership has estimated its liability related to this tax to be $0.3 million and $0.4 million at December 31, 2012 and 2013, respectively, which is reported as a provision for income taxes on its consolidated statements of operations.  See Note 20 for a discussion of certain risks related to the Partnership’s ability to be treated as a partnership for federal income tax purposes.
	STOCK BASED COMPENSATION - The Partnership’s general partner adopted the Blueknight Energy Partners G.P. L.L.C. Long-Term Incentive Plan (the “LTIP”). The compensation committee of the Board administers the LTIP. The LTIP authorizes the grant of an aggregate of 2.6 million common units deliverable upon vesting. Although other types of awards are contemplated under the LTIP, awards issued to date 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. Certain of the phantom unit awards also include distribution equivalent rights (“DERs”). 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. Cash distributions paid on DERs are accounted for as partnership distributions. Recipients of restricted units are entitled to receive cash distributions paid on common units during the vesting period.
	The Partnership classifies unit award grants as either equity or liability awards. All award grants made under the Plan from its inception through December 31, 2012 have been classified as equity awards. Fair value for award grants classified as equity is determined on the grant date of the award and this value is recognized as compensation expense ratably over the requisite service period of unit award grants, which generally is the vesting period. Fair value for equity awards is calculated as the closing price of the Partnership’s common units representing limited partner interests in the Partnership (“common units”) on the grant date and is reduced by the present value of estimated cash distributions to be paid on common units during the vesting period to the extent a unit award does not include DERs. Compensation expense related to unit-based payments is included in operating and general and administrative expenses on the Partnership’s consolidated statements of operations.
	FAIR VALUE OF FINANCIAL INSTRUMENTS  -  The Partnership measures all financial instruments, including derivatives embedded in other contracts, at fair value and recognizes them in the consolidated balance sheet as an asset or a liability, depending on its rights and obligations under the applicable contract.  The changes in the fair value of financial instruments are recognized currently in earnings, in other (income) expenses, on the consolidated statement of operations.

DISCONTINUED_OPERATIONS_Notes

DISCONTINUED OPERATIONS (Notes)	12 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
Discontinued Operations	'
	DISCONTINUED OPERATIONS
	Northumberland, PA Asphalt Facility
	On November 1, 2013, the Partnership entered into a litigation settlement in which title to our Northumberland, Pennsylvania asphalt facility was conveyed on November 21, 2013 to the counterparty to the settlement agreement in return for complete indemnification from any and all environmental liabilities or lawsuits related to the facility (see Note16). The Partnership recognized a loss on the disposal of the facility of $0.6 million. The financial results of the Partnership's operations related to the Northumberland asphalt facility are reflected as discontinued operations in the consolidated statements of operations. All prior periods presented have been recast to reflect the discontinued operations.
	The amounts of revenue, costs and income taxes reported in discontinued operations are set forth in the table below for the periods indicated:
		For the twelve months ended December 31,
		2011		2012			2013
		(in thousands)
	Total revenue	652		663			583
	Expenses:
	Operating	103		122			149
	Gain on sale of assets	—		—			56
	Loss on disposal of operations	—		—			(621		)
	Income (loss) from discontinued operations	549		541			(131		)
	Basic and diluted income (loss) from discontinued operations per common unit	$	0.02	$	0.02		$	(0.01	)
	Basic and diluted income (loss) from discontinued operations per subordinated unit	$	0.01	$	—		$	—
	The following table discloses the major classes of discontinued assets and liabilities related to the Northumberland asphalt facility at the disposal date:
		21-Nov-13
		Northumberland asphalt facility
		(in thousands)
	Assets
	Accounts Receivable	$	4
	Plant, property and equipment, net	—
	Other assets	—
	Assets of discontinued operations	$	4
	Liabilities
	Accounts Payable	$	13
	Deferred Revenue	28
	Other liabilities	84
	Liabilities of discontinued operations	$	125
	Thompson to Webster Pipeline System
	In September 2013, the Partnership experienced an oil spill on its Thompson to Webster Gathering System. As the costs associated with future maintenance of the pipeline and the potential future realizable cash flows from this pipeline were assessed, the Partnership determined that it was not economically feasible for it to continue to operate the pipeline. The Partnership assessed the recoverability of the carrying value of this asset and determined it was impaired. This resulted in $5.7 million of impairment expense being recorded in 2013, which reduced the carrying value of this pipeline to the discounted future net cash flows we expect to realize from this asset. During the discussions with the current shipper on necessary future maintenance and the possibility of idling the system, the shipper expressed interest in purchasing the system. On December 30, 2013, the sale to the shipper was finalized. The financial information of the Thompson to Webster pipeline facility is reflected as discontinued operations in the consolidated statements of operations. All prior periods presented have been recast to reflect the discontinued operations.
	Continuing cash flows will be generated under a Transition Services Agreement with the purchaser. The term of the agreement is six months commencing December 31, 2013, and is cancellable by the purchaser with a 30 day notice. There is no renewal option. The Transition Services Agreement provides for a monthly fee of $15,000 and reimbursement of direct expenses. Direct expenses are expected to be insignificant.
	The amounts of revenue, costs and income taxes reported in discontinued operations are set forth in the table below for the periods indicated:
		For the twelve months ended December 31,
		2011		2012			2013
		(in thousands)
	Total revenue	2,863		2,883			2,302
	Expenses:
	Operating	2,151		1,452			1,354
	Gain (loss) on sale of assets	—		(21		)	1,532
	Asset impairment expense	—		—			(5,732		)
	Income (loss) from discontinued operations	$	712	$	1,410		$	(3,252	)
	Basic and diluted income (loss) from discontinued operations per common unit	$	0.02	$	0.06		$	(0.13	)
	Basic and diluted income (loss) from discontinued operations per subordinated unit	$	0.02	$	—		$	—
	The following table discloses the major classes of discontinued assets and liabilities related to the Thompson-Webster system at the disposal date:
		30-Dec-13
		Thompson to Webster pipeline system
		(in thousands)
	Assets
	Accounts Receivable	$	400
	Plant, property and equipment, net	1,000
	Assets of discontinued operations	$	1,400
	Liabilities
	Accounts Payable	$	1
	Deferred Revenue	148
	Other liabilities	$	339
	Liabilities of discontinued operations	$	488

PROPERTY_PLANT_AND_EQUIPMENT

PROPERTY, PLANT AND EQUIPMENT	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
PROPERTY, PLANT AND EQUIPMENT	'
	PROPERTY, PLANT AND EQUIPMENT
		Estimated Useful Lives (Years)	December 31, 2012			December 31, 2013
			(dollars in thousands)
	Land	N/A	$	16,405		$	16,374
	Land improvements	20-Oct	6,287			6,306
	Pipelines and facilities	30-May	101,392			144,261
	Storage and terminal facilities	Oct-35	232,102			234,208
	Transportation equipment	10-Mar	18,003			16,735
	Office property and equipment and other	20-Mar	26,009			26,371
	Pipeline linefill and tank bottoms	N/A	5,993			10,193
	Construction-in-progress	N/A	14,766			14,008
	Property, plant and equipment, gross		420,957			468,456
	Accumulated depreciation and impairments		(153,216		)	(171,056		)
	Property, plant and equipment, net		$	267,741		$	297,400
	Depreciation expense for the years ended December 31, 2011, 2012 and 2013 was $22.7 million, $23.0 million and $24.2 million, respectively. In the years ended December 31, 2011, 2012 and 2013 the Partnership recorded asset impairment expense of $0.9 million, $1.8 million and $6.9 million, respectively.

INTANGIBLES_AND_OTHER_ASSETS_N

INTANGIBLES AND OTHER ASSETS, NET (Notes)	12 Months Ended
	Dec. 31, 2013
Intangibles and Other Assets [Abstract]	'
Intangibles And Other Assets, Net [Text Block]	'
	INTANGIBLES AND OTHER ASSETS, NET
	Other assets, net of accumulated amortization, consist of the following (in thousands):
		December 31,
		2012			2013
	Customer relationships	$	661		$	661
	Deposits	476			1,181
	Prepaid insurance	518			337
	Other prepaid expenses	70			49
	Intangibles and other assets, gross	1,725			2,228
	Accumulated amortization of intangible assets	(69		)	(102		)
	Intangibles and other assets, net	$	1,656		$	2,126
	Amortization expense related to intangibles was $0.1 million for each of the twelve months ended December 31, 2011 and December 31, 2012 and was less than $0.1 million for the twelve months ended December 31, 2013.  The estimated aggregate amortization expense on amortizable intangible assets currently owned by the Partnership is as follows (in thousands):
	For twelve months ending:
	December 31, 2014	$	33
	December 31, 2015	33
	December 31, 2016	33
	December 31, 2017	33
	December 31, 2018	33
	Thereafter	394
	Total estimated aggregate amortization expense	$	559
	In connection with the acquisition of a producer field services business in December 2010, the Partnership recorded intangibles for customer relationships of $0.7 million and a non-compete agreement of $0.2 million.  Both of these assets relate to the crude oil trucking and producer field services operating segment.  The customer relationships are being amortized over twenty years. In December 2012, the non-compete agreement was determined to be impaired due to the death of the counterpart to the agreement and an impairment expense of $0.1 million was recognized. This expense is included in operating expenses on the Partnership’s consolidated statements of operations.

DEBT

DEBT	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
DEBT	'
	DEBT
	On June 28, 2013, the Partnership entered into an amended and restated credit agreement which consists of a $400.0 million revolving loan facility. As of March 10, 2014, approximately $277.0 million of revolver borrowings and $0.5 million of letters of credit were outstanding under the credit facility, leaving the Partnership with approximately $122.5 million available capacity for additional revolver borrowings and letters of credit under the credit facility, although the Partnership’s ability to borrow such funds may be limited by the financial covenants in the credit facility. In connection with entering into the amended and restated credit agreement, the Partnership paid certain upfront fees to the lenders thereunder, and the Partnership paid certain arrangement and other fees to the arranger and administrative agent of the credit agreement.  The proceeds of loans made under the amended and restated credit agreement may be used for working capital and other general corporate purposes of the Partnership. All references herein to the credit agreement on or after June 28, 2013 refer to the amended and restated credit agreement.
	The credit agreement is guaranteed by all of the Partnership’s existing subsidiaries (other than immaterial 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, including all material pipeline, gathering and processing assets, all material storage tanks and asphalt facilities, all material working capital assets and a pledge of all of the Partnership’s equity interests in its subsidiaries.
	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 $500.0 million for all revolving loan commitments under the credit agreement.
	The credit agreement will mature on June 28, 2018, and all amounts outstanding under the credit agreement will become due and payable on such date.  The Partnership may prepay all loans under the credit agreement at any time without premium or penalty (other than customary LIBOR breakage costs), subject to certain notice requirements. 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%) 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 credit agreement does not have a floor for the alternate base rate or the eurodollar rate.  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.
	The maximum permitted consolidated total leverage ratio is 4.50 to 1.00, provided that the maximum permitted consolidated total leverage ratio is 5.00 to 1.00 from and after (i) the last day of the fiscal quarter immediately preceding the fiscal quarter in which a specified acquisition (as defined in the credit agreement) occurs to and including the last day of the second full fiscal quarter following the fiscal quarter in which such specified acquisition occurred and (ii) the date on which the Partnership issues qualified senior notes (as defined in the credit agreement, but generally being unsecured indebtedness with no required principal payments prior to June 28, 2019) 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 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 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;
	•	enter into operating leases; and
	•	make certain amendments to the Partnership’s partnership agreement.
	At December 31, 2013, the Partnership’s consolidated total leverage ratio was 3.63 to 1.00 and the consolidated interest coverage ratio was 7.80 to 1.00.  The Partnership was in compliance with all covenants of its credit agreement as of December 31, 2013.
	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. 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 10 for additional information regarding distributions.
	Each of the following is an event of default under the credit agreement:
	•	failure to pay any principal, interest, fees, expenses or other amounts when due;
	•	failure to meet the quarterly financial covenants;
	•	failure to observe any other agreement, obligation or covenant in the credit agreement or any related loan document, subject to cure periods for certain failures;
	•	the failure of any representation or warranty to be materially true and correct when made;
	•	the Partnership’s, or any of its restricted subsidiaries,’ default under other indebtedness that exceeds a threshold amount;
	•	judgments against the Partnership or any of its restricted subsidiaries, in excess of a threshold amount;
	•	certain ERISA events involving the Partnership or its restricted subsidiaries resulting in a material adverse effect on the Partnership;
	•	bankruptcy or other insolvency events involving the General Partner, the Partnership or any of its restricted subsidiaries; and
	•	a change of control (as defined in the credit agreement, but generally being (i) the General Partner ceasing to own 100% of the Partnership’s general partner interest or ceasing to control the Partnership, or (ii) Vitol Holding B.V. (together with its affiliates, “Vitol”) and Charlesbank Capital Partners, LLC (together with its affiliates, “Charlesbank”) ceasing to collectively own and control 50.0% or more of the membership interests of the General Partner).
	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 have letters of credit issued under the credit agreement.
	Upon the execution of the amended and restated credit agreement, the Partnership expensed $1.8 million of debt issuance costs related to the extinguished term loan, and the Partnership expensed $0.2 million in debt issuance costs related to its revolving loan facility, leaving a remaining balance of $0.5 million ascribed to those lenders with commitments under both the prior and the amended and restated credit facility. During the twelve months ended December 31, 2013, the Partnership capitalized debt issuance costs of $0.2 million related to the prior credit facility and $3.4 million related to the current credit facility. The Partnership did not incur any debt issuance costs in the twelve months ended December 31, 2012. The debt issuance costs are being amortized over the term of the amended and restated credit agreement. Interest expense related to debt issuance cost amortization for the twelve months ended December 31, 2011, 2012 and 2013 was $2.0 million, $1.8 million and $3.3 million, respectively.
	During the twelve months ended December 31, 2011, 2012 and 2013, the weighted average interest rate under the Partnership's credit agreement, excluding the $2.0 million of debt issuance costs related to the prior credit facility that was expensed in the twelve months ended December 31, 2013, was 5.38%, 5.22% and 5.99%, respectively, resulting in interest expense of approximately $12.8 million, $11.3 million and $10.7 million, respectively. As of December 31, 2013, borrowings under the Partnership’s amended and restated credit agreement bore interest at a weighted average interest rate of 3.42%.
	During the twelve months ended December 31, 2011 2012 and 2013, the Partnership capitalized interest of less than $0.1 million, $0.2 million and $1.0 million, respectively.

NET_INCOME_PER_LIMITED_PARTNER

NET INCOME PER LIMITED PARTNER UNIT	12 Months Ended
	Dec. 31, 2013
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 entities’ 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):
		Year ended December 31,
		2011			2012		2013
	Net income	33,475			31,565		28,035
	General partner interest in net income	912			774		647
	Preferred interest in net income	16,446			21,564		21,564
	Accretion of discount on increasing rate preferred units	2,243			—		—
	Beneficial conversion feature attributable to preferred units	43,259			1,853		—
	Beneficial conversion feature attributable to repurchased preferred units	(6,892		)	—		—
	Gain on extinguishment attributable to redemption of convertible debt, recorded as a capital transaction	(2,375		)	—		—
	Income (loss) available to limited partners	$	(20,118	)	$	7,374	$	5,824
	Basic and diluted weighted average number of units:
	Common units	22,059			22,666		22,706
	Subordinated units(1)	8,817			—		—
	Restricted and phantom units	699			550		651
	Basic and diluted income (loss) from continuing operations per common unit	$	(0.65	)	$	0.24	$	0.39
	Basic and diluted income (loss) from discontinued operations per common unit	$	0.04		$	0.08	$	(0.14	)
	Basic and diluted net income (loss) per common unit	$	(0.61	)	$	0.32	$	0.25
	Basic and diluted net loss from continuing operations per subordinated unit	$	(0.55	)	$	—	$	—
	Basic and diluted net income (loss) from discontinued operations per subordinated unit	$	0.03		$	—	$	—
	Basic and diluted net loss per subordinated unit	$	(0.52	)	$	—	$	—
	_________________
	(1) On September 14, 2011, Vitol and Charlesbank transferred all of the Partnership's outstanding subordinated units to the Partnership and the Partnership canceled such subordinated units.

PARTNERS_CAPITAL_AND_DISTRIBUT

PARTNERS' CAPITAL AND DISTRIBUTIONS	12 Months Ended
	Dec. 31, 2013
Partners' Capital Account, Distributions [Abstract]	'
PARTNERS' CAPITAL AND DISTRIBUTIONS	'
	PARTNERS’ CAPTIAL AND DISTRIBUTIONS
	In accordance with the terms of its partnership agreement, each quarter the Partnership distributes all of its available cash (as defined in the partnership agreement) to its unitholders. Generally, distributions are allocated: first, 98% to the Series A Preferred Unitholders and 2% to its general partner until the Partnership distributes for each Series A Preferred Unit an amount equal to the Series A quarterly distribution amount discussed below; then 98% to the Series A Preferred Unitholders and 2% to its general partner until the Partnership distributes for each Series A Preferred Unit an amount equal to any Series A cumulative distribution arrearage; and, thereafter, 98% to the common unitholders and 2% to its general partner.  Distributions are also paid to the holders of restricted units and phantom units as disclosed in Note 13.
	Pursuant to the terms of a global transaction agreement with Vitol and Charlesbank, the Partnership issued and sold 10,769,231 Preferred Units to each Purchaser (or 21,538,462 Preferred Units in the aggregate) for a cash purchase price of $6.50 per Preferred Unit, resulting in total gross proceeds of approximately $140 million.
	These Preferred Units are convertible at the holders’ option into common units.  The Preferred Units were issued at a discount to the market price of the common units into which they are convertible.  This discount totaling $54.5 million represents a beneficial conversion feature and is reflected as an increase in common and subordinated unitholders’ capital and a decrease in Preferred Unitholders’ capital to reflect the fair value of the Preferred Units at issuance on the Partnership’s consolidated statement of changes in partners’ capital for the twelve months ended December 31, 2010.  The beneficial conversion feature is considered a dividend and has been distributed ratably from the issuance date of October 25, 2010 through the first conversion date which is January 2012, resulting in an increase in preferred capital and a decrease in common and subordinated unitholders’ capital.  The impact of the beneficial conversion feature is also included in earnings per unit for the twelve months ended December 31, 2011 and 2012.
	Holders of the Preferred Units were entitled to quarterly distributions of 2.125% per unit per quarter (or 8.5% per unit on an annual basis) for each quarter during the one year period after the date of issuance of the Preferred Units (pro-rated with respect to the period commencing on the date of issuance and ending on December 31, 2010 based on the number of days in such period). In the case of any quarter beginning one year after the date of the issuance of the Preferred Units, the holders of the Preferred Units were entitled to quarterly distributions of 4.375% per unit per quarter (or 17.5% per unit on an annual basis) but this amount was decreased to 2.75% per unit per quarter (or 11.0% per unit on an annual basis) upon affirmative vote of the unitholders in September 2011.  If the Partnership fails to pay in full any distribution on the Preferred Units, the amount of such unpaid distribution will accrue and accumulate from the last day of the quarter for which such distribution is due until paid in full.
	On October 3, 2011, the Partnership commenced the rights offering.  Pursuant to the terms of the rights offering, the Partnership distributed to its common unitholders of record as of the close of business on September 27, 2011, 0.5412 rights for each outstanding common unit, with each whole right entitling the holder to acquire, for a subscription price of $6.50, a newly issued Preferred Unit.  The rights offering expired on October 31, 2011.
	The rights offering was over-subscribed and, accordingly, on November 9, 2011, the Partnership issued a total of 11,846,990 Preferred Units to unitholders that exercised their rights.  The Partnership received net proceeds of approximately $77 million from the rights offering.  The net proceeds from the rights offering, after deducting expenses, were used to redeem convertible debentures in the aggregate principal amount of $50 million plus accrued interest thereon that the Partnership issued to Vitol and Charlesbank and to repurchase an aggregate of 3,225,494 Preferred Units from Vitol and Charlesbank.
	The Partnership paid distributions of $11.4 million during 2011 on the Preferred Units for the portion of the quarter ended December 31, 2010 during which the Preferred Units were outstanding and for the quarters ending March 31, 2011, June 30, 2011 and September 30, 2011. The Partnership paid distributions totaling $21.2 million during 2012 on the Preferred Units for the quarters ending December 31, 2011, March 31, 2012, June 30, 2012 and September 30, 2012. The Partnership paid distributions totaling $21.6 million during 2013 on the Preferred Units for the quarters ending December 31, 2012, March 31, 2013, June 30, 2013 and September 30, 2013. On January 22, 2014, the Board approved a distribution of $0.17875 per Preferred Unit, or a total distribution of $5.4 million, for the quarter ending December 31, 2013.  The Partnership paid this distribution on the Preferred Units on February 14, 2014 to unitholders of record as of February 4, 2014.
	The Partnership paid distributions totaling $10.3 million during 2012 on the common units for the quarters ending December 31, 2011, March 31, 2012, June 30, 2012 and September 30, 2012. Of the $10.3 million paid during 2012, approximately $0.2 million was paid to holders of phantom and restricted units under the Partnership’s long-term incentive plan. The Partnership paid distributions totaling $10.8 million during 2013 on the common units for the quarters ending December 31, 2012, March 31, 2013, June 30, 2013 and September 30, 2013. Of the $10.8 million paid during 2013, approximately $0.2 million was paid to holders of phantom and restricted units under the Partnership’s long-term incentive plan. In addition, the Board declared a cash distribution of $0.1265 per unit on its outstanding common units, a 3.3% increase over the previous quarter’s distribution. The distribution was paid on February 14, 2014 to unitholders of record on February 4, 2014. The distribution is for the twelve months ended December 31, 2013. The total distribution was approximately $3.0 million, with approximately $2.9 million and less than $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.

Major_Customers_and_Concentrat

Major Customers and Concentration of Credit Risk (Notes)	12 Months Ended
	Dec. 31, 2013
Risks and Uncertainties [Abstract]	'
Concentration Risk Disclosure [Text Block]	'
	MAJOR CUSTOMERS AND CONCENTRATION OF CREDIT RISK
	For the twelve months ended December 31, 2013, Vitol accounted for at least 60% but not more than 70% of total crude oil terminalling and storage revenue, and MV Purchasing, LLC accounted for at least 10% but not more than 20% of total crude oil terminalling and storage revenue.  Vitol, Valero Marketing and Supply Co. and ExxonMobil Corporation each accounted for at least 10% but no more than 35% of crude oil pipeline services revenue in 2013.  Vitol and MV Purchasing, LLC accounted for at least 15% but not more than 30% of crude oil trucking and producer field services revenue in 2013.  Ergon Asphalt & Emulsions, Heartland Asphalt Materials, Inc., Nustar Marketing, LLC and Suncor Energy USA accounted for at least 10% but not more than 25% of asphalt services revenue in 2013.  MV Purchasing, LLC and Vitol comprised 14% and 19% of total accounts receivable, respectively, at December 31, 2013.
	Financial instruments that potentially subject the Partnership to concentrations of credit risk consist principally of trade receivables. The Partnership’s accounts receivable are primarily from producers, purchasers and shippers of crude oil and asphalt product and at times will include Vitol. This industry concentration has the potential to impact the Partnership’s overall exposure to credit risk in that the customers may be similarly affected by changes in economic, industry or other conditions. The Partnership periodically reviews credit exposure and financial information of its counterparties.

RELATED_PARTY_TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
RELATED PARTY TRANSACTIONS	'
	RELATED PARTY TRANSACTIONS
	The Partnership provides crude oil gathering, transportation, terminalling and storage services to Vitol.  For the twelve months ended December 31, 2011, 2012 and 2013, the Partnership recognized revenues of $44.1 million, $48.2 million and $51.2 million, respectively, for services provided to Vitol.  As of December 31, 2012 and 2013, the Partnership had receivables from Vitol of $3.1 million and $3.0 million, respectively.
	The Partnership also provides operating and administrative services to Advantage Pipeline. For the twelve months ended December 31, 2013, the Partnership recognized revenues of $0.6 million, for services provided to Advantage Pipeline. As of December 31, 2013, the Partnership had receivables from Advantage Pipeline of $0.2 million.
	The Partnership also had a receivable from its General Partner of $0.5 million as of December 31, 2012.
	Vitol Omnibus Agreement
	On February 15, 2010, the Partnership entered into an Omnibus Agreement (the “Vitol Omnibus Agreement”) with Vitol.  Pursuant to the Vitol Omnibus Agreement, the Partnership agreed to provide certain of its employees, consultants and agents (the “Designated Persons”) to Vitol for use by Vitol’s crude oil marketing division.  In return, Vitol agreed to reimburse the Partnership in an amount equal to (i) the wages, salaries, bonuses, make whole payments, payroll taxes and the cost of all employee benefits of each Designated Person, in each case as adjusted to properly reflect the time spent by such Designated Person in the performance services for Vitol, (ii) all direct expenses, including, without limitation, any travel and entertainment expenses, incurred by each Designated Person in connection with such Designated Person’s provision of services for Vitol, (iii) a monthly charge of $1,500 per Designated Person for each Designated Person that performs services for Vitol during any portion of such month, plus (iv) the sum of subsections (i) through (iii) above multiplied by 0.10.  In addition, the Vitol Omnibus Agreement provides that if during any month any Designated Person has spent more than 80% of his time performing services for Vitol, then Vitol will have the right for the succeeding three months to request that such individual be transitioned directly to the employment of Vitol.  The Vitol Omnibus Agreement was reviewed and approved by the Board’s conflicts committee in accordance with the Partnership’s procedures for approval of related party transactions and the provisions of the Partnership’s partnership agreement. During the twelve months ended December 31, 2012 the Partnership received payments of $0.2 million pursuant to the Vitol Omnibus Agreement. The Partnership and Vitol terminated the Vitol Omnibus Agreement on March 27, 2012.
	Vitol Storage Agreements
	In connection with the Partnership’s acquisition of certain of its crude oil storage assets from SemGroup Corporation (“SemCorp”) in May 2008, the Partnership was assigned from SemCorp a storage agreement with Vitol under which the Partnership provided crude oil storage services to Vitol (the “2008 Vitol Storage Agreement”).  The initial term of the 2008 Vitol Storage Agreement was from June 1, 2008 through June 30, 2010. This agreement was amended in 2010 to extend the term of the agreement until June 1, 2011 and again in 2011 to extend the term of the agreement to June 1, 2012.  Because Vitol was a third party (and not a related or affiliated party) at the time of entering into the 2008 Vitol Storage Agreement, such agreement was not approved by the Board or the Board’s conflicts committee in accordance with the Partnership’s procedures for approval of related party transactions.  Vitol became a related party when it acquired the General Partner in November 2009 (the “Vitol Change of Control”).  Since the amendments occurred subsequent to the Vitol Change of Control, they were reviewed and approved by the Board’s conflicts committee in accordance with the Partnership’s procedures for approval of related party transactions and the provisions of the partnership agreement.   The Partnership earned revenues under this agreement of approximately $13.2 million and $5.5 million during the twelve months ended December 31, 2011 and 2012 respectively. The 2008 Vitol Storage Agreement expired according to its terms on June 1, 2012. The Partnership believes that the rates it charged Vitol under the 2008 Vitol Storage Agreement were fair and reasonable to the Partnership and its unitholders and were comparable with the rates the Partnership charged third parties.
	In March 2010, the Partnership entered into a second crude oil storage services agreement with Vitol under which the Partnership began providing additional crude oil storage services to Vitol effective May 1, 2010 (the “2010 Vitol Storage Agreement”).  The initial term of the 2010 Vitol Storage Agreement is five years commencing on May 1, 2010, subject to automatic renewal periods for successive one year periods until terminated by either party with ninety days prior notice.  The 2010 Vitol Storage Agreement was reviewed and approved by the Board’s conflicts committee in accordance with the Partnership’s procedures for approval of related party transactions and the provisions of the partnership agreement.  Service revenues under the 2010 Vitol Storage Agreement are based on the 2.0 million barrels of storage capacity of the crude oil storage tanks that are dedicated to Vitol under the agreement. The Partnership generated revenues under this agreement of approximately $12.3 million, $11.5 million, and $9.0 million during the twelve months ended December 31, 2011, 2012 and 2013, respectively. In March 2013, the 2010 Vitol Storage Agreement was amended to adjust the rates the Partnership charges Vitol for services provided under the agreement. The Partnership believes that the rates it charges Vitol under the 2010 Vitol Storage Agreement are fair and reasonable to the Partnership and its unitholders and are comparable with the rates the Partnership charges third parties.
	In 2012, the Partnership entered into three new crude oil storage services agreements with Vitol, the “2012 Vitol 12-month Storage Agreement” and the “2012 Vitol 6-month Storage Agreement,” which became effective June 1, 2012, and the “Vitol September 2012 Storage Agreement,” which became effective September 1, 2012. The Partnership believes that the rates it charges Vitol under each of these agreements, as amended, are fair and reasonable to the Partnership and its unitholders and are comparable with the rates the Partnership charges third parties. The Board’s conflicts committee reviewed and approved each of these agreements and each of the amendments described below in accordance with the Partnership’s procedures for approval of related party transactions and the provisions of the partnership agreement.
	Service revenues under the 2012 Vitol 12-month Storage Agreement are based on the 1.0 million barrels of storage capacity of the crude oil storage tanks that are dedicated to Vitol under the agreement. The initial term of the 2012 Vitol 12-month Storage Agreement was from June 1, 2012 through May 31, 2013. In March 2013, the 2012 Vitol 12-month Storage Agreement was amended to extend the term through March 31, 2014 and to adjust the rates the Partnership charges Vitol for services provided under the agreement. The Partnership generated revenues under this agreement of approximately $3.2 million and $4.3 million for the twelve months ended December 31, 2012 and 2013, respectively.
	Service revenues under the 2012 Vitol 6-month Storage Agreement are based on the 0.5 million barrels of storage capacity of the crude oil storage tanks that are dedicated to Vitol under the agreement. The initial term of the 2012 Vitol 6-month Storage Agreement was from June 1, 2012 through November 30, 2012. Upon expiration of the initial term, this agreement became subject to a rolling 90 day cancellation notice. In March 2013, the 2012 Vitol 6-month Storage Agreement was amended to extend the term through October 31, 2013 and to adjust the rates the Partnership charges Vitol for services provided under the agreement. In October 2013, the 2012 Vitol 6-month Storage Agreement was amended again to extend the term through March 31, 2014 and to adjust the rates the Partnership charges Vitol for services provided under the agreement effective as of November 1, 2013. The Partnership generated revenues under this agreement of approximately $1.6 million and $2.1 million for the twelve months ended December 31, 2012 and 2013, respectively.
	Service revenues under the Vitol September 2012 Storage Agreement are based on the 0.5 million barrels of storage capacity of the crude oil storage tanks that are dedicated to Vitol under the agreement. The initial term of the Vitol September 2012 Storage Agreement was from September 1, 2012 to February 28, 2013. In March 2013, the Vitol September 2012 Storage Agreement was amended to extend the term through October 31, 2013 and to adjust the rates the Partnership charges Vitol for services provided under the agreement. In October 2013, the Vitol September 2012 Storage Agreement was amended again to extend the term through March 31, 2014 and to adjust the rates the Partnership charges Vitol for services provided under the agreement effective as of November 1, 2013. The Partnership generated revenues under this agreement of approximately $0.9 million and $2.1 million for the twelve months ended December 31, 2012 and 2013, respectively.
	Vitol Throughput Capacity Agreement
	In August 2010, the Partnership and Vitol entered into a Throughput Capacity Agreement (the “ENPS Throughput Agreement”).  Pursuant to the ENPS Throughput Agreement, Vitol purchased 100% of the throughput capacity on the Partnership’s Eagle North Pipeline System (“ENPS”).  The Partnership put ENPS in service in December 2010.  In September 2010, Vitol paid the Partnership a prepaid fee equal to $5.5 million, and Vitol agreed to pay additional usage fees for every barrel delivered by or on behalf of Vitol on ENPS.  This $5.5 million fee received from Vitol was accounted for as a long-term payable to a related party.  In addition, if the payments made by Vitol in any contract year under the ENPS Throughput Agreement were in the aggregate less than $2.4 million, then Vitol was obligated to pay the Partnership a deficiency payment equal to $2.4 million minus the aggregate amount of all payments made by Vitol during such contract year.  In March 2012, the Partnership received a deficiency payment of $0.3 million from Vitol in relation to the 2011 contract year.  In February 2013, the Partnership received a deficiency payment of $0.2 million from Vitol in relation to the 2012 contract year. The ENPS Throughput Agreement was approved by the Board’s conflicts committee in accordance with the Partnership’s procedures for approval of related party transactions and the provisions of its partnership agreement.
	During the twelve months ended December 31, 2011, 2012 and 2013 the Partnership incurred interest expense under this agreement of approximately $0.7 million, $0.5 million and $0.1 million, respectively. The agreement had an effective annual interest rate of 14.1%. In April 2013, the Partnership repurchased 100% of the throughput capacity on ENPS from Vitol for $2.5 million, and the ENPS Throughput Agreement was terminated.
	Vitol Operating and Maintenance Agreement
	In August 2011, the Partnership and Vitol entered into an operating and maintenance agreement (the “Vitol O&M Agreement”) relating to the operation and maintenance of Vitol’s crude oil terminal located in Midland, Texas (the “Midland Terminal”). Pursuant to the Vitol O&M Agreement, the Partnership provides certain operating and maintenance services with respect to the Midland Terminal. The term of the Vitol O&M Agreement commenced on September 1, 2012 and will continue for five years. During the twelve months ended December 31, 2012 and 2013, the Partnership generated revenues of $0.2 million and $0.8 million, respectively, under the Vitol O&M Agreement. The Partnership believes that the rates it charges Vitol under the Vitol O&M Agreement are fair and reasonable to the Partnership and its unitholders and are comparable with the rates the Partnership charges third parties. The Board’s conflicts committee reviewed and approved the Vitol O&M Agreement in accordance with the Partnership’s procedures for approval of related party transactions and the provisions of the partnership agreement.
	Vitol Shared Services Agreement
	In August 2012, the Partnership and Vitol entered into a shared services agreement (the “Vitol Shared Services Agreement”) pursuant to which the Partnership provides Vitol certain strategic assessment, economic evaluation and project design services. The original term of the Vitol Shared Services Agreement commenced on August 1, 2012 and continued for one year. In August 2013, the term of the Vitol Shared Services Agreement was automatically renewed for one year. The Vitol Shared Services Agreement renews annually unless terminated by either party as provided in the agreement. During the twelve months ended December 31, 2012 and 2013, the Partnership generated revenues of $0.3 million and $0.6 million, respectively, under the Vitol Shared Services Agreement. The Partnership believes that the rates it charges Vitol under the Vitol Shared Services Agreement are fair and reasonable to the Partnership and its unitholders. The Board’s conflicts committee reviewed and approved the Vitol Shared Services Agreement in accordance with the Partnership’s procedures for approval of related party transactions and the provisions of the partnership agreement.
	Vitol’s Commitment under the Partnership’s Prior Credit Agreement
	Vitol was a lender under the Partnership’s prior credit agreement and committed to loan the Partnership $15.0 million pursuant to such agreement.  During the twelve months ended December 31, 2011, 2012, and 2013, Vitol received its pro rata portion of the interest payments in connection with being a lender under the credit agreement and received approximately $0.7 million, $0.7 million, and $0.3 million, respectively, in connection therewith. Vitol is not a lender under the Partnership’s amended and restated credit agreement.
	Advantage Pipeline Operating and Administrative Services Agreement
	In January 2013, the Partnership and Advantage Pipeline entered into an operating and administrative services agreement (the “Advantage O&A Services Agreement”) pursuant to which the Partnership will operate Advantage Pipeline’s Pecos River Pipeline in west Texas. Under the Advantage O&A Services Agreement, the Partnership will also provide certain administrative services to Advantage Pipeline. The initial term of the Advantage O&A Services Agreement commenced on January 31, 2013 and shall continue for ten years, with the Partnership and Advantage Pipeline each having an option to extend the term for an additional five years. During the twelve months ended December 31, 2013, the Partnership earned revenues of $0.3 million under this agreement.

LONGTERM_INCENTIVE_PLAN

LONG-TERM INCENTIVE PLAN	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
LONG-TERM INCENTIVE PLAN	'
	LONG-TERM INCENTIVE PLAN
	In July 2007, the General Partner adopted the Long-Term Incentive Plan (the “LTIP”). The compensation committee of the Board administers the LTIP. The LTIP authorizes the grant of an aggregate of 2.6 million common units deliverable upon vesting.  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. Certain of 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 units are entitled to receive cash distributions paid on common units during the vesting period which distributions 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 each of December 2011, 2012, and 2013 7,500 restricted common units were granted which vest in one-third increments over three years.  These grants were made in connection with the anniversary of the independent directors joining the Board. The fair value of the restricted units for the 2011 and 2012 grants was less than $0.1 million, while the fair value of the restricted units for the 2013 grant was $0.1 million.
	In March 2011, 2012, 2013 and 2014 grants for 299,900, 353,300, 251,106 and 276,773 phantom units, respectively, were made, which vest or vested on January 1, 2014, January 1, 2015, January 1, 2016 and January 1, 2017, respectively.  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 weighted average grant date fair-value of the awards is $8.25, $6.76, $8.75 and $9.06 per unit, respectively, which is the closing market price on the grant date of the awards. The value of these award grants was approximately $2.5 million, $2.4 million, $2.2 million and $2.5 million, respectively, on their grant date. In June 2013, grants of 1,300 phantom units that were to vest on January 1, 2014 and 3,500 units that were to vest on January 1, 2015 were made. The weighted average grant date fair-value of the awards is $8.40, which is the closing market price on the grant date. The value of these award grants was $40,320. The phantom units granted in June 2013 were subsequently forfeited in November 2013. The unrecognized estimated compensation cost of outstanding phantom units at December 31, 2013 was $1.8 million, which will be recognized over the remaining vesting period. On January 1, 2014 164,650 units of the March 2011 grant vested.
	In September 2012, Mark Hurley was granted 500,000 phantom units under the LTIP upon his employment as the Chief Executive Officer of the General Partner. 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. These units vest ratably over five years pursuant to the Employee Phantom Unit Agreement between Mr. Hurley and the General Partner and do not include DERs. The weighted average grant date fair value for the units of $5.62 was determined based on the closing market price of the Partnership’s common units on the grant date of the award, less the present value of the estimated distributions to be paid to holders of an outstanding common unit prior to the vesting of the underlying award. The value of this award grant was approximately $2.8 million on the grant date, and the unrecognized estimated compensation cost at December 31, 2013 was $2.1 million and will be expensed over the remaining vesting period.
	The Partnership’s equity-based incentive compensation expense for the twelve months ended December 31, 2011, 2012 and 2013 was $0.5 million, $1.9 million and $2.3 million, respectively.
	Activity pertaining to phantom common units and restricted common unit awards granted under the Plan is as follows:
		Number of Units	Weighted Average Grant Date Fair Value
	Nonvested at December 31, 2012	1,016,703	$	6.51
	Granted	263,406	8.74
	Vested	162,957	6.35
	Forfeited	58,990	7.67
	Nonvested at December 31, 2013	1,058,162	$	7.03

EMPLOYEE_BENEFIT_PLAN

EMPLOYEE BENEFIT PLAN	12 Months Ended
	Dec. 31, 2013
Compensation and Retirement Disclosure [Abstract]	'
EMPLOYEE BENEFIT PLAN	'
	EMPLOYEE BENEFIT PLAN
	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 $1.3 million for each of the twelve months ended December 31, 2011 and 2012, and $1.4 million for the twelve months ended December 31, 2013 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 $0.9 million for each of the twelve months ended December 31, 2011 and 2012, and $0.8 million for the twelve months ended December 31, 2013, for discretionary profit sharing contributions under the 401(k) Plan.

PROFITS_INTEREST_OF_BLUEKNIGHT

PROFITS INTEREST OF BLUEKNIGHT GP HOLDING, LLC (Notes)	12 Months Ended
	Dec. 31, 2013
PROFITS INTEREST OF BLUEKNIGHT GP HOLDING, LLC [Abstract]	'
Profits Interest Of Parent Company [Text Block]	'
	PROFITS INTEREST OF BLUEKNIGHT GP HOLDING, LLC
	In October 2012, the owners of Blueknight GP Holding, LLC (“HoldCo”), the owner of the General Partner, admitted Mr. Hurley as a member of HoldCo.  In connection with his admission as a member of HoldCo, Mr. Hurley was issued a non-voting economic interest in HoldCo (the “Profits Interest”).   Mr. Hurley’s Profits Interest in HoldCo will vest in 20% increments on each of October 4, 2013, 2014, 2015, 2016 and 2017 and entitle Mr. Hurley, to the extent vested, to (i) 2% of the total amount of proceeds and/or distributions in excess of $100,000,000 received by HoldCo in connection with a transaction resulting in a change of control of the Partnership, and (ii) 2% of the portion of any interim quarterly distribution received by HoldCo in excess of $1,250,000.  As of December 31, 2013 20% of the Profits Interest is vested.
	Although the entire economic burden of the Profits Interest, which is equity classified, is borne solely by HoldCo and does not impact the Partnership’s cash or units outstanding, the intent of the Profits Interest is to provide a performance incentive and encourage retention of Mr. Hurley. Therefore, the Partnership recognizes the grant date fair value of the Profits Interest as compensation expense over the service period. The expense is also reflected as a capital contribution and thus, results in a corresponding credit to Partners’ Capital in the Partnership’s Consolidated Financial Statements.  Less than $0.1 million and $0.1 million was recognized as expense in 2012 and 2013, respectively.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENT AND CONTINGENCIES	'
	COMMITMENTS AND CONTINGENCIES
	The Partnership leases certain real property, equipment and operating facilities under various operating and capital leases. It also incurs costs associated with leased land, rights-of-way, permits and regulatory fees, the contracts for which generally extend beyond one year but can be cancelled at any time should they not be required for operations. Future non-cancellable commitments related to these items at December 31, 2013, are summarized below (in thousands):
		Operating Leases
	For twelve months ending:
	December 31, 2014	$	7,034
	December 31, 2015	6,100
	December 31, 2016	3,524
	December 31, 2017	2,386
	December 31, 2018	1,774
	Thereafter	1,360
	Total future minimum lease payments	$	22,178
	Rental expense related to leases was $5.8 million, $6.5 million and $7.5 million for each of the years ended December 31, 2011, 2012 and 2013, respectively.
	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.
	On October 27, 2008, Keystone Gas Company (“Keystone”) filed suit against the Partnership in Oklahoma State District Court in Creek County alleging that it is the rightful owner of certain segments of the Partnership’s pipelines and related rights of way, located in Payne and Creek Counties, that the Partnership acquired from SemCorp in connection with the Partnership’s initial public offering in 2007. Keystone seeks to quiet title to the specified rights of way and pipelines and seeks damages up to the net profits derived from the disputed pipelines. There has been no determination of the extent of potential damages for the Partnership’s use of such pipelines. The Partnership has filed a counterclaim against Keystone alleging that it is wrongfully using a segment of a pipeline that is owned by the Partnership in Payne and Creek Counties. The Partnership intends to vigorously defend these claims. No trial date has been set by the court. The parties are engaged in discovery as well as settlement negotiations. Any settlement will not have a material adverse effect on the Partnership's financial condition or results of operations.
	In March and April 2009, nine current or former executives (the “Claimants”) of SemCorp and certain of its affiliates filed wage claims with the Oklahoma Department of Labor against the General Partner.  Their claims arise from the General Partner’s Long-Term Incentive Plan, Employee Phantom Unit Agreement (“Phantom Unit Agreement”).  Most claimants alleged that phantom units previously awarded to them vested upon the change of control that occurred in July 2008.  One claimant alleged that his phantom units vested upon his termination.  The claimants contended the General Partner’s failure to deliver certificates for the phantom units within 60 days after vesting caused them to be damaged, and they sought recovery of approximately $2.0 million in damages and penalties.  In September 2013, this matter was settled on favorable terms to the Partnership, and it did not have a material adverse effect on the Partnership's financial condition or results of operations.
	On February 13, 2013, the Partnership filed suit against Koch Industries, Inc. (together with certain of its subsidiaries, “Koch”), a previous owner of the Partnership’s asphalt facility located in Northumberland, Pennsylvania.  The suit was filed in the United States District Court for the Middle District of Pennsylvania.  The Partnership sought a declaration that Koch is responsible for any assessment and cleanup costs related to certain environmental liabilities.  Koch brought counter claims and took the position that the Partnership has the responsibility to assess the polychlorinated biphenyl (“PCB”) contamination at such facility although the contamination occurred prior to the Partnership becoming the owner of such facility.  To avoid the expense and uncertainty of litigation, in November 2013, the Partnership and Koch executed a settlement agreement for this matter.  As a condition of the settlement, Koch will indemnify the Partnership and its tenant at this facility from and against any and all liabilities or lawsuits arising from or relating to the asphalt facility located in Northumberland, Pennsylvania.  In connection with the settlement, the Partnership conveyed title to the asphalt facility to Koch, and Koch is responsible for any assessment and cleanup costs related to PCB liabilities associated with this facility.  The settlement closed in the fourth quarter of 2013.  The settlement of this matter did not have a material adverse effect on the Partnership’s financial condition or results of operation.
	On February 6, 2012, the Partnership filed suit against SemCorp and others in Oklahoma County District Court. By way of background, SemCorp entities were responsible through June 2010, pursuant to a Shared Services Agreement with the Partnership dated April 7, 2009, for the physical management and control of crude oil belonging to the Partnership’s customers and with the operation of the Partnership’s Oklahoma pipeline system and its Cushing, Oklahoma terminal. Prior to April 1, 2010, SemCorp had also provided accounting services relating to the Partnership’s crude oil assets and its customers’ crude oil at the Cushing Terminal, also in accordance with the Shared Services Agreement. In the suit, the Partnership is seeking a judgment that SemCorp immediately return approximately 140,000 barrels of crude oil linefill belonging to the Partnership, and the Partnership is seeking judgment in an amount in excess of $75,000 for actual damages, special damages, punitive damages, pre-judgment interest, reasonable attorney’s fees and costs, and such other relief that the Court deems equitable and just.  On March 22, 2012, SemCorp filed a motion to dismiss and transfer to Tulsa County.  On April 18, 2012, SemCorp filed a motion for summary judgment, and, on May 1, 2012, the District Court of Oklahoma County ordered a transfer to Tulsa County.  The Partnership contested SemCorp’s motion for summary judgment, which was referred to a special master for report and recommendation.  On June 10, 2013, the special master filed a report with the District Court of Tulsa County, finding a shortage in the Partnership’s Cushing Terminal and Oklahoma pipeline system of approximately 148,000 barrels and an excess of approximately 130,000 in SemCorp’s physical inventory. The Special Master noted that she was unable to more precisely trace the shortage and length (excess held by SemCorp) due to the manner in which SemCorp operated the Cushing Terminal and maintained related records. On June 25, 2013, the Partnership filed a notice of non-objection and motion to adopt the special master’s report, which was granted on February 12, 2014. On September 17, 2013, the Partnership filed a motion for summary judgment as to the liability of SemCorp for the Partnership’s claims for breach of contract and negligence by a bailee.  On October 7, 2013, SemCorp renewed its motion for summary judgment, which the Partnership timely opposed.  On February 20, 2014, the Court denied summary judgment motions of both SemCorp and the Partnership. The Court also found that discovery had not officially closed and referred all discovery matters to the Special Master, as appropriate, and made other procedural rulings. Discovery proceedings will move forward as directed by the Special Master, and the Partnership will also re-plead certain of its claims in accordance with the Court’s directives. The Partnership intends to seek additional damages from SemCorp related to various injuries to the Partnership as a result of SemCorp's refusal to return the Partnership’s crude oil or to pay the Partnership for the fair market value of the missing oil.  No trial date is set.
	On July 13, 2012, the Partnership and one of its employees were named in a motor vehicle negligence suit in the District Court of Woodward County, Oklahoma arising out of an accident involving one of the Partnership’s crude oil tanker trucks.  The accident resulted in the death of one of the occupants of the other vehicle and injuries to the other occupant.  The plaintiff was seeking damages in excess of $75,000 from the Partnership.  The Partnership submitted the claim to its insurance carriers, and, in September 2013, a fair and reasonable resolution of this matter was reached with the plaintiff within applicable policy limits. This matter did not have a material adverse impact on the Partnership's consolidated results of operations or financial condition.
	In late November 2013, one of the Partnership's pipelines in East Texas leaked approximately 500 barrels of oil. The response and clean-up cost is expected to total approximately $2.1 million all of which is reflected in the Partnership's 2013 results of operations. The Partnership made a claim against its pollution liability insurance provider (Aspen) to cover the expenses related to the spill and has paid its deductible of $250,000.  In early February, Aspen filed a lawsuit against the Partnership to rescind the policy.   The Partnership believes the lawsuit is an attempt by Aspen to avoid paying a valid claim, and the Partnership plans to vigorously defend the suit if planned discussions with Aspen are unsuccessful.
	The Partnership may become the subject of additional private or government actions regarding these matters in the future.  Litigation may be time-consuming, expensive and disruptive to normal business operations, and the outcome of litigation is difficult to predict.  The defense of these lawsuits may result in the incurrence of significant legal expense, both directly and as the result of the Partnership’s indemnification obligations.  The litigation may also divert management’s attention from the Partnership’s operations which may cause its business to suffer.  An unfavorable outcome in any of these matters may have a material adverse effect on the Partnership’s business, financial condition, results of operations, cash flows, ability to make distributions to its unitholders, the trading price of the Partnership’s common units and its ability to conduct its business. All or a portion of the defense costs and any amount the Partnership may be required to pay to satisfy a judgment or settlement of these claims may or may not be covered by insurance.
	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 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.

ENVIRONMENTAL_REMEDIATION_Note

ENVIRONMENTAL REMEDIATION (Notes)	12 Months Ended
	Dec. 31, 2013
ENVIRONMENTAL REMEDIATION [Abstract]	'
Environmental Loss Contingency Disclosure [Text Block]	'
	ENVIRONMENTAL REMEDIATION
	The Partnership maintains insurance of various types with varying levels of coverage that it considers adequate under the circumstances to cover its operations and properties. The insurance policies are subject to deductibles and retention levels that the Partnership considers reasonable and not excessive. Consistent with insurance coverage generally available in the industry, in certain circumstances the Partnership’s insurance policies provide limited coverage for losses or liabilities relating to gradual pollution, with broader coverage for sudden and accidental occurrences. Although the Partnership maintains a program designed to prevent and, as applicable, to detect and address such releases promptly, damages and liabilities incurred due to environmental releases from its assets may substantially affect its business.
	At December 31, 2012 and 2013, the Partnership was not aware of any existing conditions that may cause it to incur significant expenditures in the future for the remediation of existing contamination. As such, the Partnership has not reflected in the accompanying financial statements any liabilities for environmental obligations to be incurred in the future based on existing contamination. Changes in the Partnership’s estimates and assumptions may occur as a result of the passage of time and the occurrence of future events.

FAIR_VALUE_MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
FAIR VALUE MEASUREMENTS	'
	FAIR VALUE MEASUREMENTS
	The Partnership utilizes a three-tier framework for assets and liabilities required to be measured at fair value. In addition, 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 these assets and liabilities 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.
	The Partnership had no recurring financial assets or liabilities subject to fair value measurements as of December 31, 2012 or December 31, 2013.
	Included in other income in the Partnership’s consolidated statements of operations for the twelve months ended December 31, 2011 is a $20.2 million change in fair value of a derivative liability. The fair value of the embedded derivative within the subordinated convertible debentures was derived using a valuation model and was classified as Level 3. The valuation model used is a discounted cash flow model (income approach) that assumes future distribution payments by the Partnership and utilizes interest rates and credit spreads for subordinated debt to preferred equity to determine the fair value of the derivative embedded within the subordinated convertible debentures. In connection with the establishment of the conversion price for the Preferred Units following the special meeting of the Partnership’s unitholders in September 2011, the number of Preferred Units issuable upon conversion of the subordinated convertible debentures was an amount equal to (i) the sum of the outstanding principal and any accrued and unpaid interest being converted, divided by (ii) 6.50.  The establishment of the conversion rate resulted in the embedded derivative meeting the scope exception in ASC 815-15 – Embedded Derivatives, and, therefore, the Partnership reclassified the embedded derivative as partners’ capital on September 14, 2011.
	Also included in other income in the Partnership’s consolidated statements of operations for the twelve months ended December 31, 2011 is a $1.9 million change in fair value of the rights offering liability. The fair value of the rights offering liability related to certain rights that were offered to common unitholders under the approved Global Transaction Agreement was derived using a valuation model and was classified as Level 3.  The valuation model used is a probability-weighted model (income approach) and assumes the number of rights that are exercised as well as the expected fair value of the Preferred Units at the time such rights are exercised.
	The following table sets forth a reconciliation of changes in the fair value of the Partnership’s financial liabilities classified as Level 3 in the fair value hierarchy (in thousands):
			Measurements Using Significant Unobservable Inputs (Level 3)
			For the Twelve
			Months Ended December 31, 2011
	Beginning Balance		$	37,991
	Total gains or losses (realized/unrealized):
	Included in earnings		(22,107		)
	Included in other comprehensive income		—
	Purchases, issuances, and settlements(1)		(15,884		)
	Transfers in and/or out of Level 3		—
	Ending Balance		$	—
	The amount of  total income for the period included in earnings attributable to the change in unrealized gains for liabilities still held at the reporting date		$	—
	____________________
	-1	As noted above, the Partnership reclassified the embedded derivative within subordinated convertible debentures to partners’ capital as of September 14, 2011.
	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 December 31, 2013, the carrying values on the 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 December 31, 2013 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	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
OPERATING SEGMENTS	'
	OPERATING SEGMENTS
	The Partnership’s operations consist of four operating segments: (i) crude oil terminalling and storage services, (ii) crude oil pipeline services, (iii) crude oil trucking and producer field services, and (iv) asphalt services.
	CRUDE OIL TERMINALLING AND STORAGE SERVICES —The Partnership provides crude oil terminalling and storage services at its terminalling and storage facilities located in Oklahoma and Texas.
	CRUDE OIL PIPELINE SERVICES —The Partnership owns and operates three pipeline systems, the Mid-Continent system, the East Texas system and ENPS, 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 and storage 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 system. It refers to its second pipeline system, which is located in Texas, as the East Texas system.  The Partnership refers to its third system, originating in Cushing, Oklahoma and terminating in Ardmore, Oklahoma, as ENPS.
	CRUDE OIL TRUCKING AND PRODUCER FIELD 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.  Crude oil producer field services consist of a number of producer field services, ranging from gathering condensates from natural gas companies to hauling produced water to disposal wells.
	ASPHALT SERVICES —The Partnership provides asphalt product and residual fuel terminalling, storage and blending services at its 42 terminalling and storage facilities located in twenty-one states.
	The Partnership’s management evaluates performance based upon segment operating margin, which includes revenues from related parties and external customers and operating expenses excluding depreciation and amortization. The non-GAAP measure of operating margin (in the aggregate and by segment) is presented in the following table. The Partnership computes the components of operating margin by using amounts that are determined in accordance with GAAP. A reconciliation of operating margin 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 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):
		For the twelve months ended December 31,
		2011				2012				2013
	Crude Oil Terminalling and Storage Services
	Service revenue
	Third party revenue	$	11,067			$	11,825			$	11,910
	Related party revenue	27,608				23,983				19,148
	Total revenue for reportable segments	38,675				35,808				31,058
	Operating expenses (excluding depreciation and amortization)	4,555				3,941				3,979
	Operating margin (excluding depreciation and amortization)	34,120				31,867				27,079
	Additions to long-lived assets	5,401				4,611				5,516
	Total assets (end of period)	$	69,840			$	67,051			$	64,591
	Crude Oil Pipeline Services
	Service revenue
	Third party revenue	$	14,121			$	13,696			$	15,658
	Related party revenue	4,807				5,677				9,018
	Total revenue for reportable segments	18,928				19,373				24,676
	Operating expenses (excluding depreciation and amortization)	14,558				16,572				17,767
	Operating margin (excluding depreciation and amortization)	4,370				2,801				6,909
	Additions to long-lived assets	6,144				12,396				51,609
	Total assets (end of period)	$	99,228			$	105,498			169,739
	Crude Oil Trucking and Producer Field Services
	Service revenue
	Third party revenue	$	44,366			$	46,164			$	51,545
	Related party revenue	11,561				17,688				21,645
	Total revenue for reportable segments	55,927				63,852				73,190
	Operating expenses (excluding depreciation and amortization)	50,465				56,194				63,123
	Operating margin (excluding depreciation and amortization)	5,462				7,658				10,067
	Additions to long-lived assets	1,362				3,451				1,779
	Total assets (end of period)	$	15,917			$	18,646			$	20,073
	Asphalt  Services
	Service revenue
	Third party revenue	$	59,550			$	59,011			$	63,803
	Related party revenue	$	113			$	805			$	1,944
	Total revenue for reportable segments	59,663				59,816				65,747
	Operating expenses (excluding depreciation and amortization)	$	22,657			$	23,215			$	24,779
	Operating margin (excluding depreciation and amortization)	37,006				36,601				40,968
	Additions to long-lived assets	6,080				6,260				6,052
	Total assets (end of period)	$	119,770			$	108,630			$	100,345
	Total operating margin (excluding depreciation and amortization)(1)	$	80,958			$	78,927			$	85,023
	____________________
	-1	The following table reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes (in thousands):
			Twelve months ended December 31,
			2011				2012				2013
	Operating margin (excluding depreciation and amortization)		$	80,958			$	78,927			$	85,023
	Depreciation and amortization on continuing operations		(22,496		)		(22,824		)		(23,962		)
	General and administrative expenses		(17,311		)		(19,795		)		(17,482		)
	Asset impairment expense		(867		)		(1,942		)		(524		)
	Gain on sale of assets		3,008				7,271				1,073
	Interest expense		(32,898		)		(11,705		)		(11,615		)
	Equity loss in unconsolidated entity		—				—				(502		)
	Change in fair value of embedded derivative within convertible debt		20,224				—				—
	Change in fair value of rights offering contingency		1,883				—				—
	Income from continuing operations before income taxes		$	32,501			$	29,932			$	32,011

INCOME_TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
INCOME TAXES	'
	INCOME TAXES
	The anticipated after-tax economic benefit of an investment in the Partnership’s common units depends largely on the Partnership being treated as a partnership for federal income tax purposes. If less than 90% of the gross income of a publicly traded partnership, such as the Partnership, for any taxable year is “qualifying income” from sources such as the transportation, marketing (other than to end users), or processing of crude oil, natural gas or products thereof, interest, dividends or similar sources, that partnership will be taxable as a corporation under Section 7704 of the Internal Revenue Code for federal income tax purposes for that taxable year and all subsequent years.
	If the Partnership were treated as a corporation for federal income tax purposes, then it would pay federal income tax on its income at the corporate tax rate, which is currently a maximum of 35%, and would likely pay state income tax at varying rates. Distributions would generally be taxed again to unitholders as corporate distributions and none of the Partnership’s income, gains, losses, deductions or credits would flow through to its unitholders. Because a tax would be imposed upon the Partnership as an entity, cash available for distribution to its unitholders would be substantially reduced. Treatment of the Partnership as a corporation would result in a material reduction in the anticipated cash flow and after-tax return to unitholders and thus would likely result in a substantial reduction in the value of the Partnership’s common units.
	The Partnership has entered into storage contracts and leases with third party customers with respect to substantially all of its asphalt facilities. At the time of entering into such agreements, it was unclear under current tax law as to whether the rental income from the leases, and the fees attributable to certain of the processing services the Partnership provides under certain of the storage contracts, constitute “qualifying income.” In the second quarter of 2009, the Partnership submitted a request for a ruling from the IRS that rental income from the leases constitutes “qualifying income.” In October 2009, the Partnership received a favorable ruling from the IRS. As part of this ruling, however, the Partnership agreed to transfer, and has transferred, certain of its asphalt processing assets and related fee income to a subsidiary taxed as a corporation. This transfer occurred in the first quarter of 2010.  Such subsidiary is required to pay federal income tax on its income at the corporate tax rate, which is currently a maximum of 35%, and will likely pay state (and possibly local) income tax at varying rates. Distributions from this subsidiary will generally be taxed again to unitholders as corporate distributions and none of the income, gains, losses, deductions or credits of this subsidiary will flow through to the Partnership’s unitholders.
	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 December 31, 2013 are presented below (dollars in thousands):
	Deferred tax assets
	Difference in bases of property, plant and equipment	$	1,012
	Deferred tax asset	1,012
	Less: valuation allowance	(1,012		)
	Net deferred tax asset	$	—
	Given that the Partnership’s subsidiary that is taxed as a corporation has a limited earnings history for purposes of determining the likelihood of realizing the benefits of the deferred tax assets, the Partnership has provided a full valuation allowance against its deferred tax asset.

RECENTLY_ISSUED_ACCOUNTING_STA

RECENTLY ISSUED ACCOUNTING STANDARDS	12 Months Ended
	Dec. 31, 2013
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]	'
RECENTLY ISSUED ACCOUNTING STANDARDS	'RECENTLY ISSUED ACCOUNTING STANDARDSIn July 2012, the FASB issued ASU 2012-02, “Testing Indefinite-Lived Intangible Assets for Impairment,” which allows an entity to first assess qualitative factors to determine whether it is necessary to perform a quantitative impairment test. Under these amendments, an entity would not be required to calculate the fair value of an indefinite-lived intangible asset unless the entity determines, based on qualitative assessment, that it is not more likely than not that the indefinite-lived intangible asset is impaired. The amendments include a number of events and circumstances for an entity to consider in conducting the qualitative assessment. The Partnership adopted this guidance beginning in its December 31, 2012 annual impairment test, and the impact was not material.In July 2013, the FASB issued ASU 2013-11, “Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists.” The amendment provides explicit guidance on the financial statement presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. The amendments in this update are effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The Partnership is evaluating the impact of this guidance, which will be adopted beginning with the Partnership’s quarterly report for the period ending March 31, 2014.

QUARTERLY_FINANCIAL_DATA_Notes

QUARTERLY FINANCIAL DATA (Notes)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Data [Abstract]	'
Quarterly Financial Information [Text Block]	'
	QUARTERLY FINANCIAL DATA (UNAUDITED)
	Summarized quarterly financial data is as follows (in thousands, except per unit data):
		First Quarter		Second Quarter		Third Quarter			Fourth Quarter			Total
	2012:00:00
	Revenues	$	43,225	$	43,084	$	46,335		$	46,205		$	178,849
	Operating income	14,089		8,774		10,453			8,321			41,637
	Income from continuing operations	10,942		5,804		7,429			5,439			29,614
	Income from discontinued operations	1,052		343		478			78			1,951
	Net income	11,994		6,147		7,907			5,517			31,565
	Total basic and diluted net income per common unit	0.2		0.02		0.1			—			0.32
	2013:00:00
	Revenues	$	44,536	$	45,678	$	54,669		$	49,788		$	194,671
	Operating income	8,168		9,704		18,363			7,893			44,128
	Income from continuing operations	5,306		4,934		16,030			5,148			$	31,418
	Income (loss) from discontinued operations	716		1,231		(5,489		)	159			(3,383		)
	Net income	6,022		6,165		10,541			5,307			28,035
	Total basic net income per common unit	0.02		0.03		0.21			(0.01		)	0.25
	Total diluted net income per common unit	0.02		0.03		0.19			(0.01		)	0.25

SUBSEQUENT_EVENTS_Notes

SUBSEQUENT EVENTS (Notes)	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events [Text Block]	'
	SUBSEQUENT EVENTS
	In March 2014 the Partnership entered into two interest rate swap agreements with an aggregate notional value of $200.0 million. The first agreement becomes effective June 28, 2014 and matures on June 28, 2018. Under the terms of the first interest rate swap agreement, the Partnership will pay a fixed rate of 1.45% and will receive one-month LIBOR with monthly settlement. The second agreement becomes effective January 28, 2015 and matures on January 28, 2019. Under the terms of the second interest rate swap agreement, the Partnership will pay a fixed rate of 1.92% and will receive one-month LIBOR with monthly settlement.

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Use of Estimates, Policy [Policy Text Block]	'
	USE OF ESTIMATES -The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts and disclosure of contingencies. Management makes significant estimates including: (1) allowance for doubtful accounts receivable; (2) estimated useful lives of assets, which impacts depreciation; (3) estimated cash flows and fair values inherent in impairment tests; (4) accruals related to revenues and expenses; (5) the estimated fair value of financial instruments; and (6) liability and contingency accruals. Although management believes these estimates are reasonable, actual results could differ from these estimates.
Cash and Cash Equivalents, Policy [Policy Text Block]	'
	CASH AND CASH EQUIVALENTS - The Partnership includes as cash and cash equivalents, cash and all investments with maturities at date of purchase of three months or less which are readily convertible into known amounts of cash.
Trade and Other Accounts Receivable, Policy [Policy Text Block]	'
	ACCOUNTS RECEIVABLE - The majority of the Partnership’s accounts receivable relates to its trucking and producer field services and asphalt services activities. Accounts receivable included in the balance sheets are reflected net of the allowance for doubtful accounts of $0.5 million and $0.1 million at December 31, 2012 and 2013, respectively.
	The Partnership reviews all outstanding accounts receivable balances on a monthly basis and records a reserve for amounts that the Partnership expects will not be fully recovered. Although the Partnership considers its allowance for doubtful trade accounts receivable to be adequate, there is no assurance that actual amounts will not vary significantly from estimated amounts.
Property, Plant and Equipment, Policy [Policy Text Block]	'
	PROPERTY, PLANT AND EQUIPMENT - Property, plant and equipment are recorded at cost. Expenditures for maintenance and repairs that do not add capacity or extend the useful life of an asset are expensed as incurred. The carrying value of the assets is based on estimates, assumptions and judgments relative to useful lives and salvage values. As assets are disposed of, the cost and related accumulated depreciation are removed from the accounts, and any resulting gain or loss is included in operating income in the statements of operations.
	Depreciation is calculated using the straight-line method, based on estimated useful lives of the assets. These estimates are based on various factors including age (in the case of acquired assets), manufacturing specifications, technological advances and historical data concerning useful lives of similar assets. Uncertainties that impact these estimates include changes in laws and regulations relating to restoration and abandonment requirements, economic conditions and supply and demand in the area. When assets are put into service, management makes estimates with respect to useful lives and salvage values that it believes are reasonable. However, subsequent events could cause management to change its estimates, thus impacting the future calculation of depreciation.
	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 (see Note 16).  Such obligations are recognized in the period incurred if reasonably estimable.
Impairment or Disposal of Long-Lived Assets, Including Intangible Assets, Policy [Policy Text Block]	'
	IMPAIRMENT OF LONG-LIVED ASSETS AND OTHER INTANGIBLE ASSETS - Long-lived assets with recorded values that are not expected to be recovered through future cash flows are written-down to estimated fair value. A long-lived asset is tested for impairment when events or circumstances indicate that its carrying value may not be recoverable. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the carrying value exceeds the sum of the undiscounted cash flows, an impairment loss equal to the amount by which the carrying value exceeds the fair value of the asset is recognized. Fair value is generally determined from estimated discounted future net cash flows.  The Partnership recognized impairment charges of $0.5 million and $0.3 million during the year ended December 31, 2011 related to an office building located in St. Louis, Missouri and an office building located in Abilene, Texas, respectively.  As of December 31, 2011, the office building in Abilene, Texas was classified as held for sale, and the Partnership subsequently sold this asset in January of 2012. The Partnership recognized total fixed asset impairment charges of $1.8 million during the year ended December 31, 2012 that included $1.0 million related to Oklahoma gathering pipeline assets and $0.7 million related to a Bay City, Michigan residual fuel oil facility. The Oklahoma gathering pipeline assets were sold during the summer of 2013 and demolition began on the Bay City facility in December 2013. The Partnership recognized total fixed asset impairment charges of $6.9 million during the year ended December 31, 2013 that included $5.7 million related to the Thompson pipeline system located in southern Texas. This system was sold in December 2013 (see Note 5).
	Acquired customer relationships and non-compete agreements are capitalized and amortized over useful lives ranging from 4 to 20 years using the straight-line method of amortization. An impairment loss is recognized for definite-lived intangibles if the carrying amount of an intangible asset is not recoverable and its carrying amount exceeds its fair value. No impairment charge was recognized in the twelve months ended December 31, 2011 and 2013 with respect to amortizable intangibles. In December 2012, the Partnership recognized an impairment loss of $0.1 million related to a non-compete agreement due to the death of the counterpart to the agreement.
Equity Method Investments, Policy [Policy Text Block]	'
	EQUITY METHOD INVESTMENTS - The Partnership’s investment in Advantage Pipeline, L.L.C. (“Advantage Pipeline”), over which the Partnership has significant influence but not control, is accounted for by the equity method. The Partnership does not consolidate any part of the assets or liabilities of its equity investee. As of December 31, 2013, the Partnership's investment represents a 30% ownership interest in Advantage Pipeline. The Partnership’s share of net income or loss is reflected as one line item on the Partnership’s Consolidated Statements of Operations entitled “Equity earnings in unconsolidated affiliate” and will increase or decrease, as applicable, the carrying value of the Partnership’s investment in the unconsolidated affiliate on the balance sheet. Distributions to the Partnership will reduce the carrying value of its investment and will be reflected in the Partnership’s Consolidated Statements of Cash Flows in the line item “Distributions from unconsolidated affiliate.” In turn, contributions will increase the carrying value of the Partnership’s investment and will be reflected in the Partnership’s Consolidated Statements of Cash Flows in investing activities. The Partnership evaluates its equity investment for impairment in accordance with FASB guidance with respect to the equity method of accounting for investments in common stock. An impairment of an equity investment results when factors indicate that the investment’s fair value is less than its carrying value and the reduction in value is other than temporary in nature.
Debt, Policy [Policy Text Block]	'
	DEBT ISSUANCE COSTS - Costs incurred in connection with the issuance of long-term debt related to the Partnership’s credit facilities are capitalized and amortized using the straight-line method over the term of the related debt. Use of the straight-line method does not differ materially from the “effective interest” method of amortization.
Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]	'
	GOODWILL - Goodwill represents the excess of the cost of acquisitions over the amounts assigned to assets acquired and liabilities assumed. Goodwill is not amortized but is tested annually for impairment and when events and circumstances warrant an interim evaluation. Goodwill is tested for impairment at a level of reporting referred to as a reporting unit. The Partnership has four reporting units comprised of (i) its crude oil terminalling and storage services, (ii) its crude oil pipeline services, (iii) its crude oil trucking and producer field services, and (iv) its asphalt services.  The Partnership has recorded goodwill of $6.3 million related to its crude oil pipeline services reporting unit and $0.9 million related to its crude oil trucking and producer field services reporting unit. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is considered not impaired. The impairment test is generally based on the estimated discounted future net cash flows of the respective reporting unit, utilizing discount rates and other factors in determining the fair value of the reporting unit.  Inputs in our estimated discounted future net cash flows include existing and estimated future asset utilization, estimated growth rates in future cash flows, and estimated terminal values (these are all considered level 3 inputs). The Partnership did not recognize any impairment of goodwill, including in its most recent impairment test conducted in the fourth quarter of 2013.
Environmental Costs, Policy [Policy Text Block]	'
	ENVIRONMENTAL MATTERS - Liabilities for loss contingencies, including environmental remediation costs, arising from claims, assessments, litigation, fines, penalties and other sources are charged to expense when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated. The Partnership recorded loss contingencies related to environmental matters of $0.2 million and $1.8 million as of December 31, 2012 and 2013, respectively.
Revenue Recognition, Policy [Policy Text Block]	'
	REVENUE RECOGNITION - The Partnership’s revenues consist of (i) terminalling and storage revenues, (ii) gathering, transportation and producer field services revenues and (iii) fuel surcharge revenues.
	Terminalling and storage revenues consist of (i) storage service fees from actual storage used on a month-to-month basis; (ii) storage service fees resulting from short-term and long-term contracts for committed space that may or may not be utilized by the customer in a given month; and (iii) terminal throughput service charges to pump crude oil to connecting carriers or to deliver asphalt product out of the Partnership’s terminals. Terminal throughput service charges are recognized as the crude oil exits the terminal and is delivered to the connecting crude oil carrier or third-party terminal and as the asphalt product is delivered out of the Partnership’s terminal. Storage service revenues are recognized as the services are provided and the amounts earned on a monthly basis.
	Gathering and transportation services revenues consist of service fees recognized for the gathering of crude oil for the Partnership’s customers and the transportation of the crude oil to refiners, to common carrier pipelines for ultimate delivery to refiners, or to terminalling and storage facilities owned by the Partnership and others. Revenue for the gathering and transportation of crude oil is recognized when the service is performed and is based upon regulated and non-regulated tariff rates and the related transport volumes.  Producer field services revenue consists of a number of services ranging from gathering condensates from natural gas producers to hauling produced water to disposal wells.  Revenue for producer field services is recognized when the service is performed.
	Fuel surcharge revenues are comprised of revenues recognized for the reimbursement of fuel and power consumed to operate the Partnership’s asphalt product storage tanks and terminals.  The Partnership recognizes fuel surcharge revenues in the period in which the related fuel and power expenses are incurred.
Income Tax, Policy [Policy Text Block]	'
	INCOME AND OTHER TAXES - For federal and most state income tax purposes, the majority of income, gains, losses, expenses, deductions and tax credits generated by the Partnership flow through to the unitholders of the Partnership. In 2007, the state of Texas implemented a partnership-level tax based on a percentage of the revenue earned for services provided in the state of Texas. The Partnership has estimated its liability related to this tax to be $0.3 million and $0.4 million at December 31, 2012 and 2013, respectively, which is reported as a provision for income taxes on its consolidated statements of operations.  See Note 20 for a discussion of certain risks related to the Partnership’s ability to be treated as a partnership for federal income tax purposes.
Share-based Compensation, Option and Incentive Plans Policy [Policy Text Block]	'
	STOCK BASED COMPENSATION - The Partnership’s general partner adopted the Blueknight Energy Partners G.P. L.L.C. Long-Term Incentive Plan (the “LTIP”). The compensation committee of the Board administers the LTIP. The LTIP authorizes the grant of an aggregate of 2.6 million common units deliverable upon vesting. Although other types of awards are contemplated under the LTIP, awards issued to date 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. Certain of the phantom unit awards also include distribution equivalent rights (“DERs”). 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. Cash distributions paid on DERs are accounted for as partnership distributions. Recipients of restricted units are entitled to receive cash distributions paid on common units during the vesting period.
	The Partnership classifies unit award grants as either equity or liability awards. All award grants made under the Plan from its inception through December 31, 2012 have been classified as equity awards. Fair value for award grants classified as equity is determined on the grant date of the award and this value is recognized as compensation expense ratably over the requisite service period of unit award grants, which generally is the vesting period. Fair value for equity awards is calculated as the closing price of the Partnership’s common units representing limited partner interests in the Partnership (“common units”) on the grant date and is reduced by the present value of estimated cash distributions to be paid on common units during the vesting period to the extent a unit award does not include DERs. Compensation expense related to unit-based payments is included in operating and general and administrative expenses on the Partnership’s consolidated statements of operations.
Fair Value of Financial Instruments, Policy [Policy Text Block]	'
	FAIR VALUE OF FINANCIAL INSTRUMENTS  -  The Partnership measures all financial instruments, including derivatives embedded in other contracts, at fair value and recognizes them in the consolidated balance sheet as an asset or a liability, depending on its rights and obligations under the applicable contract.  The changes in the fair value of financial instruments are recognized currently in earnings, in other (income) expenses, on the consolidated statement of operations.

DISCONTINUED_OPERATIONS_DISCON

DISCONTINUED OPERATIONS DISCONTINUED OPERATIONS (Tables)	12 Months Ended
	Dec. 31, 2013
Northumberland, PA Asphalt Facility [Member]	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	'
	The amounts of revenue, costs and income taxes reported in discontinued operations are set forth in the table below for the periods indicated:
		For the twelve months ended December 31,
		2011		2012			2013
		(in thousands)
	Total revenue	652		663			583
	Expenses:
	Operating	103		122			149
	Gain on sale of assets	—		—			56
	Loss on disposal of operations	—		—			(621		)
	Income (loss) from discontinued operations	549		541			(131		)
	Basic and diluted income (loss) from discontinued operations per common unit	$	0.02	$	0.02		$	(0.01	)
	Basic and diluted income (loss) from discontinued operations per subordinated unit	$	0.01	$	—		$	—
	The following table discloses the major classes of discontinued assets and liabilities related to the Northumberland asphalt facility at the disposal date:
		21-Nov-13
		Northumberland asphalt facility
		(in thousands)
	Assets
	Accounts Receivable	$	4
	Plant, property and equipment, net	—
	Other assets	—
	Assets of discontinued operations	$	4
	Liabilities
	Accounts Payable	$	13
	Deferred Revenue	28
	Other liabilities	84
	Liabilities of discontinued operations	$	125
Thompson To Webster System [Member]	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	'
	The amounts of revenue, costs and income taxes reported in discontinued operations are set forth in the table below for the periods indicated:
		For the twelve months ended December 31,
		2011		2012			2013
		(in thousands)
	Total revenue	2,863		2,883			2,302
	Expenses:
	Operating	2,151		1,452			1,354
	Gain (loss) on sale of assets	—		(21		)	1,532
	Asset impairment expense	—		—			(5,732		)
	Income (loss) from discontinued operations	$	712	$	1,410		$	(3,252	)
	Basic and diluted income (loss) from discontinued operations per common unit	$	0.02	$	0.06		$	(0.13	)
	Basic and diluted income (loss) from discontinued operations per subordinated unit	$	0.02	$	—		$	—
	The following table discloses the major classes of discontinued assets and liabilities related to the Thompson-Webster system at the disposal date:
		30-Dec-13
		Thompson to Webster pipeline system
		(in thousands)
	Assets
	Accounts Receivable	$	400
	Plant, property and equipment, net	1,000
	Assets of discontinued operations	$	1,400
	Liabilities
	Accounts Payable	$	1
	Deferred Revenue	148
	Other liabilities	$	339
	Liabilities of discontinued operations	$	488

PROPERTY_PLANT_AND_EQUIPMENT_T

PROPERTY, PLANT AND EQUIPMENT (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Schedule of Property, Plant and Equipment	'
		Estimated Useful Lives (Years)	December 31, 2012			December 31, 2013
			(dollars in thousands)
	Land	N/A	$	16,405		$	16,374
	Land improvements	20-Oct	6,287			6,306
	Pipelines and facilities	30-May	101,392			144,261
	Storage and terminal facilities	Oct-35	232,102			234,208
	Transportation equipment	10-Mar	18,003			16,735
	Office property and equipment and other	20-Mar	26,009			26,371
	Pipeline linefill and tank bottoms	N/A	5,993			10,193
	Construction-in-progress	N/A	14,766			14,008
	Property, plant and equipment, gross		420,957			468,456
	Accumulated depreciation and impairments		(153,216		)	(171,056		)
	Property, plant and equipment, net		$	267,741		$	297,400

INTANGIBLES_AND_OTHER_ASSETS_N1

INTANGIBLES AND OTHER ASSETS, NET (Tables)	12 Months Ended
	Dec. 31, 2013
INTANGIBLES AND OTHER ASSETS, NET [Abstract]	'
Schedule of Finite-Lived Intangible Assets [Table Text Block]	'
	Other assets, net of accumulated amortization, consist of the following (in thousands):
		December 31,
		2012			2013
	Customer relationships	$	661		$	661
	Deposits	476			1,181
	Prepaid insurance	518			337
	Other prepaid expenses	70			49
	Intangibles and other assets, gross	1,725			2,228
	Accumulated amortization of intangible assets	(69		)	(102		)
	Intangibles and other assets, net	$	1,656		$	2,126
Schedule of Finite-Lived Intangible Assets, Future Amortization Expense [Table Text Block]	'
	The estimated aggregate amortization expense on amortizable intangible assets currently owned by the Partnership is as follows (in thousands):
	For twelve months ending:
	December 31, 2014	$	33
	December 31, 2015	33
	December 31, 2016	33
	December 31, 2017	33
	December 31, 2018	33
	Thereafter	394
	Total estimated aggregate amortization expense	$	559

NET_INCOME_PER_LIMITED_PARTNER1

NET INCOME PER LIMITED PARTNER UNIT (Tables)	12 Months Ended
	Dec. 31, 2013
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):
		Year ended December 31,
		2011			2012		2013
	Net income	33,475			31,565		28,035
	General partner interest in net income	912			774		647
	Preferred interest in net income	16,446			21,564		21,564
	Accretion of discount on increasing rate preferred units	2,243			—		—
	Beneficial conversion feature attributable to preferred units	43,259			1,853		—
	Beneficial conversion feature attributable to repurchased preferred units	(6,892		)	—		—
	Gain on extinguishment attributable to redemption of convertible debt, recorded as a capital transaction	(2,375		)	—		—
	Income (loss) available to limited partners	$	(20,118	)	$	7,374	$	5,824
	Basic and diluted weighted average number of units:
	Common units	22,059			22,666		22,706
	Subordinated units(1)	8,817			—		—
	Restricted and phantom units	699			550		651
	Basic and diluted income (loss) from continuing operations per common unit	$	(0.65	)	$	0.24	$	0.39
	Basic and diluted income (loss) from discontinued operations per common unit	$	0.04		$	0.08	$	(0.14	)
	Basic and diluted net income (loss) per common unit	$	(0.61	)	$	0.32	$	0.25
	Basic and diluted net loss from continuing operations per subordinated unit	$	(0.55	)	$	—	$	—
	Basic and diluted net income (loss) from discontinued operations per subordinated unit	$	0.03		$	—	$	—
	Basic and diluted net loss per subordinated unit	$	(0.52	)	$	—	$	—
	_________________
	(1) On September 14, 2011, Vitol and Charlesbank transferred all of the Partnership's outstanding subordinated units to the Partnership and the Partnership canceled such subordinated units.

LONGTERM_INCENTIVE_PLAN_Tables

LONG-TERM INCENTIVE PLAN (Tables)	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Schedule Of Phantom Common Units And Restricted Common Units Activity	'
	Activity pertaining to phantom common units and restricted common unit awards granted under the Plan is as follows:
		Number of Units	Weighted Average Grant Date Fair Value
	Nonvested at December 31, 2012	1,016,703	$	6.51
	Granted	263,406	8.74
	Vested	162,957	6.35
	Forfeited	58,990	7.67
	Nonvested at December 31, 2013	1,058,162	$	7.03

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2013
COMMITMENTS AND CONTINGENCIES [Abstract]	'
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	'
	Future non-cancellable commitments related to these items at December 31, 2013, are summarized below (in thousands):
		Operating Leases
	For twelve months ending:
	December 31, 2014	$	7,034
	December 31, 2015	6,100
	December 31, 2016	3,524
	December 31, 2017	2,386
	December 31, 2018	1,774
	Thereafter	1,360
	Total future minimum lease payments	$	22,178

FAIR_VALUE_MEASUREMENTS_Fair_V

FAIR VALUE MEASUREMENTS Fair Value Measures (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]	'
	The following table sets forth a reconciliation of changes in the fair value of the Partnership’s financial liabilities classified as Level 3 in the fair value hierarchy (in thousands):
			Measurements Using Significant Unobservable Inputs (Level 3)
			For the Twelve
			Months Ended December 31, 2011
	Beginning Balance		$	37,991
	Total gains or losses (realized/unrealized):
	Included in earnings		(22,107		)
	Included in other comprehensive income		—
	Purchases, issuances, and settlements(1)		(15,884		)
	Transfers in and/or out of Level 3		—
	Ending Balance		$	—
	The amount of  total income for the period included in earnings attributable to the change in unrealized gains for liabilities still held at the reporting date		$	—
	____________________
	-1	As noted above, the Partnership reclassified the embedded derivative within subordinated convertible debentures to partners’ capital as of September 14, 2011.

OPERATING_SEGMENTS_Tables

OPERATING SEGMENTS (Tables)	12 Months Ended
	Dec. 31, 2013
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):
		For the twelve months ended December 31,
		2011				2012				2013
	Crude Oil Terminalling and Storage Services
	Service revenue
	Third party revenue	$	11,067			$	11,825			$	11,910
	Related party revenue	27,608				23,983				19,148
	Total revenue for reportable segments	38,675				35,808				31,058
	Operating expenses (excluding depreciation and amortization)	4,555				3,941				3,979
	Operating margin (excluding depreciation and amortization)	34,120				31,867				27,079
	Additions to long-lived assets	5,401				4,611				5,516
	Total assets (end of period)	$	69,840			$	67,051			$	64,591
	Crude Oil Pipeline Services
	Service revenue
	Third party revenue	$	14,121			$	13,696			$	15,658
	Related party revenue	4,807				5,677				9,018
	Total revenue for reportable segments	18,928				19,373				24,676
	Operating expenses (excluding depreciation and amortization)	14,558				16,572				17,767
	Operating margin (excluding depreciation and amortization)	4,370				2,801				6,909
	Additions to long-lived assets	6,144				12,396				51,609
	Total assets (end of period)	$	99,228			$	105,498			169,739
	Crude Oil Trucking and Producer Field Services
	Service revenue
	Third party revenue	$	44,366			$	46,164			$	51,545
	Related party revenue	11,561				17,688				21,645
	Total revenue for reportable segments	55,927				63,852				73,190
	Operating expenses (excluding depreciation and amortization)	50,465				56,194				63,123
	Operating margin (excluding depreciation and amortization)	5,462				7,658				10,067
	Additions to long-lived assets	1,362				3,451				1,779
	Total assets (end of period)	$	15,917			$	18,646			$	20,073
	Asphalt  Services
	Service revenue
	Third party revenue	$	59,550			$	59,011			$	63,803
	Related party revenue	$	113			$	805			$	1,944
	Total revenue for reportable segments	59,663				59,816				65,747
	Operating expenses (excluding depreciation and amortization)	$	22,657			$	23,215			$	24,779
	Operating margin (excluding depreciation and amortization)	37,006				36,601				40,968
	Additions to long-lived assets	6,080				6,260				6,052
	Total assets (end of period)	$	119,770			$	108,630			$	100,345
	Total operating margin (excluding depreciation and amortization)(1)	$	80,958			$	78,927			$	85,023
	____________________
	-1	The following table reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes (in thousands):
			Twelve months ended December 31,
			2011				2012				2013
	Operating margin (excluding depreciation and amortization)		$	80,958			$	78,927			$	85,023
	Depreciation and amortization on continuing operations		(22,496		)		(22,824		)		(23,962		)
	General and administrative expenses		(17,311		)		(19,795		)		(17,482		)
	Asset impairment expense		(867		)		(1,942		)		(524		)
	Gain on sale of assets		3,008				7,271				1,073
	Interest expense		(32,898		)		(11,705		)		(11,615		)
	Equity loss in unconsolidated entity		—				—				(502		)
	Change in fair value of embedded derivative within convertible debt		20,224				—				—
	Change in fair value of rights offering contingency		1,883				—				—
	Income from continuing operations before income taxes		$	32,501			$	29,932			$	32,011

INCOME_TAXES_Tables

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2013
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 December 31, 2013 are presented below (dollars in thousands):
	Deferred tax assets
	Difference in bases of property, plant and equipment	$	1,012
	Deferred tax asset	1,012
	Less: valuation allowance	(1,012		)
	Net deferred tax asset	$	—

QUARTERLY_FINANCIAL_DATA_Table

QUARTERLY FINANCIAL DATA (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Data [Abstract]	'
Schedule of Quarterly Financial Information [Table Text Block]	'
	Summarized quarterly financial data is as follows (in thousands, except per unit data):
		First Quarter		Second Quarter		Third Quarter			Fourth Quarter			Total
	2012:00:00
	Revenues	$	43,225	$	43,084	$	46,335		$	46,205		$	178,849
	Operating income	14,089		8,774		10,453			8,321			41,637
	Income from continuing operations	10,942		5,804		7,429			5,439			29,614
	Income from discontinued operations	1,052		343		478			78			1,951
	Net income	11,994		6,147		7,907			5,517			31,565
	Total basic and diluted net income per common unit	0.2		0.02		0.1			—			0.32
	2013:00:00
	Revenues	$	44,536	$	45,678	$	54,669		$	49,788		$	194,671
	Operating income	8,168		9,704		18,363			7,893			44,128
	Income from continuing operations	5,306		4,934		16,030			5,148			$	31,418
	Income (loss) from discontinued operations	716		1,231		(5,489		)	159			(3,383		)
	Net income	6,022		6,165		10,541			5,307			28,035
	Total basic net income per common unit	0.02		0.03		0.21			(0.01		)	0.25
	Total diluted net income per common unit	0.02		0.03		0.19			(0.01		)	0.25

ORGANIZATION_AND_NATURE_OF_BUS1

ORGANIZATION AND NATURE OF BUSINESS (Narrative) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2013
	States	Operating-segments
		States
ORGANIZATION AND NATURE OF BUSINESS [Abstract]	'	'
Number of states in which entity operates (in states)	22	22
Number of Operating Segments	4	4

RECENT_EVENTS_Narrative_Detail

RECENT EVENTS (Narrative) (Details) (Advantage Pipeline, L.L.C. [Member])	Feb. 04, 2013
	mi
Business Acquisition [Line Items]	'
Equity Method Investment, Ownership Percentage	30.00%
Miles of Crude Oil Pipeline	70
Advantage Pipeline Phase I [Member]	'
Business Acquisition [Line Items]	'
Miles of Crude Oil Pipeline	36

RECENT_EVENTS_Narrative_2_Deta

RECENT EVENTS (Narrative 2) (Details) (Revolving Credit Facility [Member], USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Revolving Credit Facility [Member]	'
Debt Instrument [Line Items]	'
Revolving credit facility amount	$400

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

Share data in Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Operating-segments

Noncompete Agreements [Member]

Noncompete Agreements [Member]

Customer Relationships [Member]

Customer Relationships [Member]

Customer Relationships [Member]

State and Local Jurisdiction [Member]

State and Local Jurisdiction [Member]

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

Crude Oil Pipeline Services [Member]

Crude Oil Trucking and Producer Field Services [Member]

St. Louis, Missouri [Member]

Abilene, Texas [Member]

OKLAHOMA

Bay City, Michigan [Member]

Texas [Member]

Advantage Pipeline, L.L.C. [Member]

Minimum [Member]

Maximum [Member]

Phantom Share Units (PSUs) [Member]

Office Building [Member]

Office Building [Member]

Pipelines [Member]

Residual Fuel Oil Facility [Member]

Pipelines [Member]

Thompson To Webster System [Member]

Accounting Policies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accounts receivable, allowance for doubtful accounts

$69,000

$69,000

$469,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Tangible Asset Impairment Charges

'

6,877,000

1,846,000

867,000

'

'

'

'

'

'

'

'

'

'

500,000

300,000

1,000,000

700,000

5,700,000

'

Finite-Lived Intangible Asset, Useful Life

'

'

'

'

'

'

'20 years

'4 years

'20 years

'

'

'

'

'

'

'

'

'

'

'

Impairment of Intangible Assets

'

0

96,000

0

100,000

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

30.00%

Number of Operating Segments

4

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of units authorized

'

'

'

'

'

'

'

'

'

'

'

2.6

'

'

'

'

'

'

'

'

Goodwill

7,216,000

7,216,000

7,216,000

'

'

'

'

'

'

'

'

'

6,300,000

900,000

'

'

'

'

'

'

Provision for income taxes

'

593,000

318,000

287,000

'

'

'

'

'

400,000

300,000

'

'

'

'

'

'

'

'

'

Accrual for Environmental Loss Contingencies

$1,800,000

$1,800,000

$200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

DISCONTINUED_OPERATIONS_Northu

DISCONTINUED OPERATIONS Northumberland, PA Asphalt Facility (Details) (USD $)

3 Months Ended

12 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Nov. 21, 2013

Northumberland, PA Asphalt Facility [Member]

Northumberland, PA Asphalt Facility [Member]

Northumberland, PA Asphalt Facility [Member]

Northumberland, PA Asphalt Facility [Member]

Asphalt Services [Member]

Asphalt Services [Member]

Asphalt Services [Member]

Asphalt Services [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total revenue

'

'

'

'

'

'

'

'

'

'

'

$583

$663

$652

'

Operating

'

'

'

'

'

'

'

'

'

'

'

149

122

103

'

Gain on sale of assets

'

'

'

'

'

'

'

'

'

'

'

56

0

0

'

Loss on disposal of operations

'

'

'

'

'

'

'

'

'

'

'

-621

0

0

'

Income (loss) from discontinued operations

159

-5,489

1,231

716

78

478

343

1,052

-3,383

1,951

1,261

-131

541

549

'

Basic and diluted income (loss) from discontinued operations per common unit (usd per unit)

'

'

'

'

'

'

'

'

($0.14)

$0.08

$0.04

($0.01)

$0.02

$0.02

'

Basic and diluted income (loss) from discontinued operations per subordinated unit (usd per unit)

'

'

'

'

'

'

'

'

'

'

'

$0

$0

$0.01

'

Accounts Receivable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

Plant, property and equipment, net

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

Other assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

Assets of discontinued operations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

Accounts Payable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13

Deferred Revenue

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28

Other liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

84

Liabilities of discontinued operations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$125

DISCONTINUED_OPERATIONS_Thomps

DISCONTINUED OPERATIONS Thompson-to-Webster system (Details) (USD $)

3 Months Ended

12 Months Ended

6 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 30, 2013

Jun. 30, 2014

Thompson To Webster System [Member]

Thompson To Webster System [Member]

Thompson To Webster System [Member]

Thompson To Webster System [Member]

Thompson To Webster System [Member]

Crude Oil Pipeline Services [Member]

Crude Oil Pipeline Services [Member]

Crude Oil Pipeline Services [Member]

Crude Oil Pipeline Services [Member]

Crude Oil Pipeline Services [Member]

Transition Services Agreement [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Agreement term

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'P6M

Termination notice period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'30 days

Agreement monthly fee

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$15,000

Total revenue

'

'

'

'

'

'

'

'

'

'

'

2,302,000

2,883,000

2,863,000

'

'

Operating

'

'

'

'

'

'

'

'

'

'

'

1,354,000

1,452,000

2,151,000

'

'

Gain (loss) on sale of assets

'

'

'

'

'

'

'

'

'

'

'

1,532,000

-21,000

0

'

'

Asset impairment expense

'

'

'

'

'

'

'

'

-524,000

-1,942,000

-867,000

-5,732,000

0

0

'

'

Income (loss) from discontinued operations

159,000

-5,489,000

1,231,000

716,000

78,000

478,000

343,000

1,052,000

-3,383,000

1,951,000

1,261,000

-3,252,000

1,410,000

712,000

'

'

Basic and diluted income (loss) from discontinued operations per common unit (usd per unit)

'

'

'

'

'

'

'

'

($0.14)

$0.08

$0.04

($0.13)

$0.06

$0.02

'

'

Basic and diluted income (loss) from discontinued operations per subordinated unit (usd per unit)

'

'

'

'

'

'

'

'

'

'

'

$0

$0

$0.02

'

'

Accounts Receivable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

400,000

'

Plant, property and equipment, net

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

'

Assets of discontinued operations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,400,000

'

Accounts Payable

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000

'

Deferred Revenue

'

'

'

'

'

'

'

'

'

'

'

'

'

'

148,000

'

Other liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

339,000

'

Liabilities of discontinued operations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$488,000

'

PROPERTY_PLANT_AND_EQUIPMENT_D

PROPERTY, PLANT AND EQUIPMENT (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment, gross	$468,456,000	$420,957,000	'
Accumulated Depreciation and Impairments, property plant and equipment	171,056,000	153,216,000	'
Property, plant and equipment, net	297,400,000	267,741,000	'
Depreciation	24,200,000	23,000,000	22,700,000
Tangible Asset Impairment Charges	6,877,000	1,846,000	867,000
Land [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment, gross	16,374,000	16,405,000	'
Land improvements [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment, gross	6,306,000	6,287,000	'
Land improvements [Member] | Minimum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Estimated Useful Lives	'10 years	'	'
Land improvements [Member] | Maximum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Estimated Useful Lives	'20 years	'	'
Pipelines and facilities [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment, gross	144,261,000	101,392,000	'
Pipelines and facilities [Member] | Minimum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Estimated Useful Lives	'5 years	'	'
Pipelines and facilities [Member] | Maximum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Estimated Useful Lives	'30 years	'	'
Storage and terminal facilities [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment, gross	234,208,000	232,102,000	'
Storage and terminal facilities [Member] | Minimum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Estimated Useful Lives	'10 years	'	'
Storage and terminal facilities [Member] | Maximum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Estimated Useful Lives	'35 years	'	'
Transportation equipment [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment, gross	16,735,000	18,003,000	'
Transportation equipment [Member] | Minimum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Estimated Useful Lives	'3 years	'	'
Transportation equipment [Member] | Maximum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Estimated Useful Lives	'10 years	'	'
Office property and equipment and other [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment, gross	26,371,000	26,009,000	'
Office property and equipment and other [Member] | Minimum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Estimated Useful Lives	'3 years	'	'
Office property and equipment and other [Member] | Maximum [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Estimated Useful Lives	'20 years	'	'
Pipeline linefill and tank bottoms [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment, gross	10,193,000	5,993,000	'
Construction-in-progress [Member]	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'
Property, plant and equipment, gross	$14,008,000	$14,766,000	'

INTANGIBLES_AND_OTHER_ASSETS_N2

INTANGIBLES AND OTHER ASSETS, NET Narrative (Details) (USD $)	12 Months Ended				1 Months Ended	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2012	Dec. 31, 2010	Dec. 31, 2010
				Customer Relationships [Member]	Noncompete Agreements [Member]	Noncompete Agreements [Member]	Crude Oil Trucking and Producer Field Services [Member]	Crude Oil Trucking and Producer Field Services [Member]
							Customer Relationships [Member]	Noncompete Agreements [Member]
Finite-Lived Intangible Assets [Line Items]	'	'	'	'	'	'	'	'
Finite-lived Intangible Assets Acquired	'	'	'	'	'	'	$700,000	$200,000
Finite-Lived Intangible Asset, Useful Life	'	'	'	'20 years	'	'	'	'
Impairment of Intangible Assets	0	96,000	0	'	100,000	100,000	'	'
Amortization of Intangible Assets	$33,028.68	$100,000	$100,000	'	'	'	'	'

INTANGIBLES_AND_OTHER_ASSETS_N3

INTANGIBLES AND OTHER ASSETS, NET Other Assets, Net of Accumulated Depreciation (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
INTANGIBLE AND OTHER ASSETS, NET [Abstract]	'	'
Customer relationships	$661	$661
Deposits	1,181	476
Prepaid insurance	337	518
Other prepaid expenses	49	70
Intangibles and other assets, gross	2,228	1,725
Accumulated amortization of intangible assets	-102	-69
Intangibles and other assets, net	$2,126	$1,656

INTANGIBLES_AND_OTHER_ASSETS_N4

INTANGIBLES AND OTHER ASSETS, NET ESTIMATED AGGREGATE AMORTIZATION EXPENSE ON INTANGIBLE ASSETS (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
For the twelve months ending:	'
31-Dec-14	$33
31-Dec-15	33
31-Dec-16	33
31-Dec-17	33
31-Dec-18	33
Thereafter	394
Finite-lived Intangible Assets, Net	$559

DEBT_Credit_Agreements_Details

DEBT (Credit Agreements) (Details) (USD $)

12 Months Ended

3 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2013

Jun. 30, 2013

Dec. 31, 2013

Jun. 28, 2013

Dec. 31, 2013

Dec. 31, 2013

Mar. 07, 2014

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Mar. 07, 2014

Blueknight General Partners G. P., L.L.C. [Member]

Vitol or Charlesbank [Member]

Secured Debt and Revolving Credit Facility [Member]

Secured Debt and Revolving Credit Facility [Member]

Secured Debt [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Letter of Credit [Member]

Minimum [Member]

Maximum [Member]

Subsequent Event [Member]

Federal funds rate [Member]

Eurodollar rate [Member]

Applicable margin based on ABR [Member]

Applicable margin based on ABR [Member]

Applicable margin based on Eurodollar rate [Member]

Applicable margin based on Eurodollar rate [Member]

Subsequent Event [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revolving credit facility amount

'

'

'

'

'

'

'

'

'

$400,000,000

'

'

'

'

'

'

'

'

'

'

'

Repayments of Long-term Debt

280,411,000

44,000,000

28,862,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revolver borrowings

'

'

'

'

'

'

'

'

'

'

'

'

'

277,000,000

'

'

'

'

'

'

'

Letters of credit outstanding, amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000

Unused borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

122,500,000

'

'

'

'

'

'

'

Maximum borrowing capacity including additional lenders

'

'

'

'

'

'

'

'

'

500,000,000

'

'

'

'

'

'

'

'

'

'

'

Credit agreement lender commitment amount

0

15,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Basis spread on variable rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

1.00%

1.00%

2.00%

2.00%

3.00%

'

Unused capacity, commitment fee (as a percent)

'

'

'

'

'

'

'

'

'

'

'

0.38%

0.50%

'

'

'

'

'

'

'

'

Consolidated total leverage (as a ratio), Maximum permitted

'

'

'

'

'

'

'

'

'

4.5

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Maximum Covenant Consolidated Total Leverage Base Ratio

'

'

'

'

'

'

'

'

'

5

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Covenant, Issued Qualified Senior Notes

'

'

'

'

'

'

'

'

'

'

'

200,000,000

'

'

'

'

'

'

'

'

'

Debt Instrument Maximum Covenant Consolidated Senior Secured Leverage Ratio

'

'

'

'

'

'

'

'

'

3.5

'

'

'

'

'

'

'

'

'

'

'

Consolidated interest coverage (as a ratio), minimum permitted

'

'

'

'

'

'

'

'

'

2.5

'

'

'

'

'

'

'

'

'

'

'

Consolidated total leverage (as a ratio), actual

'

'

'

'

'

'

'

'

'

3.63

'

'

'

'

'

'

'

'

'

'

'

Consolidated interest coverage (as a ratio), actual

'

'

'

'

'

'

'

'

'

7.8

'

'

'

'

'

'

'

'

'

'

'

Credit agreement, Constitute a change of control, if ceases to own, directly or indirectly, exactly 50% of the membership interests of the General Partner or if General Partner ceases to be controlled (as a percent)

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit agreement, Constitute a change of control if Vitol Holding BV and Charlesbank ceasing to collectively own and control 50% of the GP

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Write off of Deferred Debt Issuance Cost

'

'

'

'

'

2,000,000

'

1,800,000

200,000

'

'

'

'

'

'

'

'

'

'

'

'

Debt issuance costs, net

3,580,000

3,225,000

'

'

'

'

'

'

'

'

500,000

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate During Period

5.99%

5.22%

5.38%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt issuance costs

3,681,000

0

280,000

'

'

200,000

0

'

'

3,400,000

'

'

'

'

'

'

'

'

'

'

'

Amortization and write-off of debt issuance costs

3,300,000

1,800,000

2,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest expense for long-term debt

10,700,000

11,300,000

12,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average interest rate (as a percent)

'

'

'

'

'

'

'

'

'

3.42%

'

'

'

'

'

'

'

'

'

'

'

Interest Costs Capitalized

$1,047,749.36

$150,412.62

$20,600.30

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

NET_INCOME_PER_LIMITED_PARTNER2

NET INCOME PER LIMITED PARTNER UNIT (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Earnings Per Share [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Net income	$5,307	$10,541	$6,165	$6,022	$5,517	$7,907	$6,147	$11,994	$28,035	$31,565	$33,475
General partner interest in net income	'	'	'	'	'	'	'	'	-647	-774	-912
Preferred interest in net income	'	'	'	'	'	'	'	'	21,564	21,564	16,446
Accretion of discount on increasing rate preferred units	'	'	'	'	'	'	'	'	0	0	-2,243
Beneficial conversion feature attributable to preferred units	'	'	'	'	'	'	'	'	0	1,853	43,259
Gain on extinguishment attributable to redemption of convertible debt, recorded as a capital transaction	'	'	'	'	'	'	'	'	0	0	2,375
Income (loss) available to limited partners	'	'	'	'	'	'	'	'	5,824	7,374	-20,118
Income (Loss) from Continuing Operations, Per Diluted Share	'	'	'	'	'	'	'	'	$0.39	$0.24	($0.65)
Basic and diluted income (loss) from discontinued operations per common unit (usd per unit)	'	'	'	'	'	'	'	'	($0.14)	$0.08	$0.04
Basic and diluted weighted average number of units:	'	'	'	'	'	'	'	'	'	'	'
Weighted average common units outstanding - basic	'	'	'	'	'	'	'	'	22,706,000	22,666,000	22,059,000
Weighted Average Subordinated Partnership Units Outstanding Basic And Diluted	'	'	'	'	'	'	'	'	0	0	8,817,000
Weighted average common units outstanding - diluted	'	'	'	'	'	'	'	'	22,706,000	22,666,000	22,059,000
Restricted and phantom units	'	'	'	'	'	'	'	'	651,000	550,000	699,000
Basic and diluted income (loss) from continuing operations per common unit	'	'	'	'	'	'	'	'	$0.39	$0.24	($0.65)
Basic and diluted income (loss) from discontinued operations per common unit	'	'	'	'	'	'	'	'	($0.14)	$0.08	$0.04
Basic net income (loss) per common unit	($0.01)	$0.21	$0.03	$0.02	'	'	'	'	$0.25	$0.32	($0.61)
Diluted net income per common unit	($0.01)	$0.19	$0.03	$0.02	$0	$0.10	$0.02	$0.20	$0.25	$0.32	($0.61)
Basic and diluted net loss from continuing operations per subordinated unit	'	'	'	'	'	'	'	'	$0	$0	($0.55)
Basic and diluted income (loss) from discontinued operations per subordinated unit	'	'	'	'	'	'	'	'	$0	$0	$0.03
Beneficial Conversion Feature Attributable To Repurchased Preferred Units	'	'	'	'	'	'	'	'	$0	$0	$6,892
Basic and diluted net loss per subordinated unit	'	'	'	'	'	'	'	'	$0	$0	($0.52)

PARTNERS_CAPITAL_AND_DISTRIBUT1

PARTNERS' CAPITAL AND DISTRIBUTIONS (Narrative) (Details) (USD $)

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 30, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Nov. 09, 2011

Oct. 03, 2011

Dec. 31, 2010

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2010

Dec. 31, 2010

Dec. 31, 2010

Dec. 31, 2011

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Series A Preferred Unitholders [Member]

Phantom Share Units and Restricted Units [Member]

Phantom Share Units and Restricted Units [Member]

Common Unitholders [Member]

Common Unitholders [Member]

Common Unitholders [Member]

General Partner Interest [Member]

General Partner Interest [Member]

General Partner Interest [Member]

General Partner Interest [Member]

Phantom and restricted unitholders [Member]

Global Transaction Agreement [Member]

Global Transaction Agreement [Member]

Global Transaction Agreement [Member]

Global Transaction Agreement [Member]

Vitol or Charlesbank [Member]

First Tier Cash Distribution for each Series A Preferred Unit an Amount Equal to the Series A Quarterly Distribution Amount [Member]

Second Tier Cash Distribution for each Series A Preferred Unit an Amount Equal to the Series A Cumulative Distribution Arrearage [Member]

Third Tier Cash Distribution [Member]

First Tier Cash Distribution for each Series A Preferred Unit an Amount Equal to the Series A Quarterly Distribution Amount [Member]

Second Tier Cash Distribution for each Series A Preferred Unit an Amount Equal to the Series A Cumulative Distribution Arrearage [Member]

Third Tier Cash Distribution [Member]

Phantom Share Units and Restricted Units [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Preferred Stock [Member]

Each Quarter One Year Period After Date of Issuance [Member]

Each Quarter Beginning One Year After Date of Issuance [Member]

Each Quarter After Affirmative Vote of Unitholder Proposals [Member]

Partners' Capital Account, Distributions, Allocation Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

98.00%

98.00%

98.00%

'

'

'

'

'

'

'

2.00%

2.00%

2.00%

'

'

'

'

'

Series A Preferred unitholders, units issued

'

30,158,619

30,159,958

'

'

'

'

'

'

11,846,990

'

21,538,462

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,769,231

'

'

'

Preferred Units, Cash Price Per Unit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$6.50

'

'

'

Proceeds from Issuance of Preferred Limited Partners Units

'

0

0

77,005,000

'

77,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

140,000,000

'

'

'

Beneficial conversion feature of Preferred Units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

54,500,000

'

'

'

Quarterly Distribution, Per Unit Per Quarter, Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.13%

4.38%

2.75%

Quarterly Distributions, Per Unit Per Quarter, Annual Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.50%

17.50%

11.00%

Quarterly Distributions, Period of Distributions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'

Common Unit, Rights Per Each Outstanding Preferred Unit

'

'

'

'

'

'

'

'

'

'

0.5412

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Unit, Issued, Subscription Price

'

'

'

'

'

'

'

'

'

'

$6.50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayments of Convertible Debt

'

0

0

50,028,000

'

50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Repurchased During Period, Shares

'

'

'

'

'

'

'

'

'

'

'

'

3,225,494

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Distribution Made to Limited Partner, Cash Distributions Paid

'

'

'

'

'

'

21,600,000

21,200,000

11,400,000

'

'

'

'

'

'

'

'

200,000

200,000

'

10,800,000

10,300,000

'

'

'

'

'

'

'

'

'

Distribution Made to Member or Limited Partner, Distributions Declared (in dollars per unit)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.18

'

'

$0.13

'

'

'

'

'

'

'

'

'

'

'

Distribution Made to Member or Limited Partner, Distributions Declared, Percentage Increase Over Previous Quarter Distribution

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.30%

'

'

'

'

'

'

'

'

'

'

'

Distribution Made to Member or Limited Partner, Cash Distributions Declared

$3,000,000

'

'

'

$5,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$2,900,000

'

'

$100,000

'

'

'

$100,000

'

'

'

'

Major_Customers_and_Concentrat1

Major Customers and Concentration of Credit Risk (Details) (Customer Concentration Risk [Member])	12 Months Ended
	Dec. 31, 2013
Vitol and MV Purchasing, LLC [Member] | Crude Oil Trucking and Producer Field Services [Member] | Sales Revenue, Services, Net [Member] | Minimum [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	15.00%
Vitol and MV Purchasing, LLC [Member] | Crude Oil Trucking and Producer Field Services [Member] | Sales Revenue, Services, Net [Member] | Maximum [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	30.00%
Ergon Asphalt & Emulsions, Heartland Asphalt Materials, Inc., Nustar Marketing, LLC and Suncor Energy USA [Member] | Asphalt Services [Member] | Sales Revenue, Services, Net [Member] | Minimum [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	10.00%
Ergon Asphalt & Emulsions, Heartland Asphalt Materials, Inc., Nustar Marketing, LLC and Suncor Energy USA [Member] | Asphalt Services [Member] | Sales Revenue, Services, Net [Member] | Maximum [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	25.00%
MV Purchasing, LLC [Member] | Accounts Receivable [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	14.00%
MV Purchasing, LLC [Member] | Crude Oil Terminalling and Storage Services [Member] | Sales Revenue, Services, Net [Member] | Minimum [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	10.00%
MV Purchasing, LLC [Member] | Crude Oil Terminalling and Storage Services [Member] | Sales Revenue, Services, Net [Member] | Maximum [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	20.00%
Vitol, Suncor Energy USA, Valero Marketing and Supply Co. and ExxonMobile Corporation [Member] | Crude Oil Pipeline Services [Member] | Sales Revenue, Services, Net [Member] | Minimum [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	10.00%
Vitol, Suncor Energy USA, Valero Marketing and Supply Co. and ExxonMobile Corporation [Member] | Crude Oil Pipeline Services [Member] | Sales Revenue, Services, Net [Member] | Maximum [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	35.00%
Vitol [Member] | Accounts Receivable [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	19.00%
Vitol [Member] | Crude Oil Terminalling and Storage Services [Member] | Sales Revenue, Services, Net [Member] | Minimum [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	60.00%
Vitol [Member] | Crude Oil Terminalling and Storage Services [Member] | Sales Revenue, Services, Net [Member] | Maximum [Member]	'
Concentration Risk [Line Items]	'
Concentration Risk, Percentage	70.00%

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Related Party Transaction [Line Items]	'	'	'
Related party revenue	$51,755	$48,153	$44,089
Receivables from related parties	3,149	3,522	'
Vitol [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Related party revenue	51,200	48,200	44,100
Receivables from related parties	3,000	3,100	'
Advantage Pipeline, L.L.C. [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Related party revenue	600	'	'
Receivables from related parties	200	'	'
General Partner [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Receivables from related parties	$0	$500	'

RELATED_PARTY_TRANSACTIONS_Vit

RELATED PARTY TRANSACTIONS (Vitol Omnibus Agreement) (Details) (USD $)	12 Months Ended								0 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Feb. 15, 2010	Dec. 31, 2012
				Vitol [Member]	Vitol [Member]	Vitol [Member]	Vitol [Member]	Vitol [Member]	Vitol [Member]	Vitol [Member]
							Vitol Operating and Maintenance Agreement [Member]	Vitol Operating and Maintenance Agreement [Member]	Vitol Omnibus Agreement [Member]	Vitol Omnibus Agreement [Member]
Related Party Transaction [Line Items]	'	'	'	'	'	'	'	'	'	'
Monthly charge per Designated Person for each Designated Person that performs services for Vitol during any portion of such month	'	'	'	'	'	'	'	'	1,500	'
Multiplier rate (as a decimal)	'	'	'	'	'	'	'	'	0.1	'
If during any month any Designated Person has spent more than 80% of his time performing services for Vitol, then Vitol will have the right for the succeeding three months to request that such individual be transitioned directly to the employment of Vitol (as a percent)	'	'	'	'	'	'	'	'	80.00%	'
Related party revenue	$51,755	$48,153	$44,089	$51,200	$48,200	$44,100	$800	$200	'	$200

RELATED_PARTY_TRANSACTIONS_Vit1

RELATED PARTY TRANSACTIONS (Vitol Storage Agreements) (Details) (USD $)

12 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 01, 2012

Dec. 31, 2012

Dec. 31, 2011

2-May-10

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 01, 2012

Dec. 31, 2013

Dec. 31, 2012

Jun. 01, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Contracts

2008 Vitol Storage Agreements [Member]

2008 Vitol Storage Agreements [Member]

2010 Vitol Storage Agreements [Member]

2010 Vitol Storage Agreements [Member]

2010 Vitol Storage Agreements [Member]

2010 Vitol Storage Agreements [Member]

Vitol 2012 12 Month Storage Agreement [Member]

Vitol 2012 12 Month Storage Agreement [Member]

Vitol 2012 12 Month Storage Agreement [Member]

Vitol 2012 6 Month Storage Agreement [Member]

Vitol 2012 6 Month Storage Agreement [Member]

Vitol 2012 6 Month Storage Agreement [Member]

Vitol September 2012 Storage Agreement [Member]

Vitol September 2012 Storage Agreement [Member]

bbl

bbl

bbl

bbl

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Related party revenue

$51,755

$48,153

$44,089

$51,200

$48,200

$44,100

'

$5,500

$13,200

'

$9,000

$11,500

$12,300

'

$4,300

$3,200

'

$2,100

$1,600

$2,100

$900

Initial term (in years)

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'12 months

'

'

'6 months

'

'

'

'

Automatic renewal period (in years)

'

'

'

'

'

'

'

'

'

'1 year

'

'

'

'

'

'

'

'

'

'

'

Termination period by either party prior notice (in days)

'

'

'

'

'

'

'

'

'

'90 days

'

'

'

'

'

'

'

'

'

'

'

Number of new crude oil storage services agreements with Vitol (in contracts)

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Barrels of storage capacity of crude oil storage tanks dedicated to related party (in barrels)

'

'

'

'

'

'

'

'

'

2,000,000

'

'

'

1,000,000

'

'

500,000

'

'

500,000

'

RELATED_PARTY_TRANSACTIONS_Vit2

RELATED PARTY TRANSACTIONS (Vitol Throughput Capacity Agreement) (Details) (USD $)	1 Months Ended				12 Months Ended
	Apr. 30, 2013	Feb. 28, 2013	Mar. 31, 2012	Aug. 31, 2010	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Sep. 30, 2010
Related Party Transaction [Line Items]	'	'	'	'	'	'	'	'
Repayments of related party debt	'	'	'	'	$2,681,000	$1,636,000	$1,183,000	'
(ENPS) Vitol Throughput Capacity Agreement [Member] | Vitol [Member]	'	'	'	'	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'	'	'	'	'
Purchase of Thoughput Capacity Related to Pipeline System	'	'	'	100.00%	'	'	'	'
Due from related party	'	'	'	'	'	'	'	5,500,000
Payments made in any contract year, minimum, required deficiency payment, equal to amount, minus the aggregate amount of all payments made by Vitol during such contract year	'	'	'	'	2,400,000	'	'	'
Deficiency payment received	'	200,000	300,000	'	'	'	'	'
Interest expense	'	'	'	'	100,000	500,000	700,000	'
Effective annual interest rate (as a percent)	'	'	'	'	14.10%	'	'	'
Repayments of related party debt	$2,500,000	'	'	'	'	'	'	'
Subsequent Event [Member] | (ENPS) Vitol Throughput Capacity Agreement [Member] | Vitol [Member]	'	'	'	'	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'	'	'	'	'
Repurchase of Thoughput Capacity Related to Pipeline System	100.00%	'	'	'	'	'	'	'

RELATED_PARTY_TRANSACTIONS_Oth

RELATED PARTY TRANSACTIONS (Other Vitol Agreements) (Details) (USD $)

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Aug. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Aug. 02, 2013

Aug. 01, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Vitol [Member]

Advantage Pipeline, L.L.C. [Member]

Secured Debt [Member]

Vitol Operating and Maintenance Agreement [Member]

Vitol Operating and Maintenance Agreement [Member]

Vitol Operating and Maintenance Agreement [Member]

Vitol Shared Services Agreement [Member]

Vitol Shared Services Agreement [Member]

Vitol Shared Services Agreement [Member]

Vitol Shared Services Agreement [Member]

Vitol’s Commitment under the Partnership’s Credit Agreement [Member]

Vitol’s Commitment under the Partnership’s Credit Agreement [Member]

Vitol’s Commitment under the Partnership’s Credit Agreement [Member]

Vitol [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Vitol’s Commitment under the Partnership’s Credit Agreement [Member]

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Initial term (in years)

'

'

'

'

'

'

'5 years

'

'

'

'1 year

'

'

'

'

'

'

'

Related Party Transaction, Renewed Term

'

'

'

'

'

'

'

'

'

'1 year

'

'

'

'

'

'

'

'

Related party revenue

$51,755,000

$48,153,000

$44,089,000

$51,200,000

$48,200,000

$44,100,000

'

$800,000

$200,000

'

'

$600,000

$300,000

'

'

'

$600,000

'

Credit agreement lender commitment amount

0

15,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15,000,000

Pro rata portion of interest payments received by Vitol under credit agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

$300,000

$700,000

$700,000

'

'

RELATED_PARTY_TRANSACTIONS_Adv

RELATED PARTY TRANSACTIONS (Advantage Pipeline Operating and Administrative Services Agreement) (Details) (USD $)	12 Months Ended				0 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Jan. 31, 2013	Dec. 31, 2013
				Advantage Pipeline, L.L.C. [Member]	Advantage Pipeline, L.L.C. [Member]	Advantage Pipeline, L.L.C. [Member]
					Operating and Administrative Services Agreement [Member]	Operating and Administrative Services Agreement [Member]
Related Party Transaction [Line Items]	'	'	'	'	'	'
Initial term (in years)	'	'	'	'	'10 years	'
Related Party Transaction, Option to Extend Term	'	'	'	'	'5 years	'
Related party revenue	$51,755	$48,153	$44,089	$600	'	$300

LONGTERM_INCENTIVE_PLAN_Detail

LONG-TERM INCENTIVE PLAN (Details) (USD $)

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 31, 2014

Jun. 30, 2013

Mar. 31, 2013

Mar. 31, 2012

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 30, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jan. 02, 2014

Jun. 30, 2013

Mar. 31, 2011

Jun. 30, 2013

Mar. 31, 2012

Mar. 31, 2014

Mar. 31, 2013

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

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

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

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

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

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

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

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

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

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

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

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

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

January 2014 Vesting [Member]

January 2014 Vesting [Member]

January 2014 Vesting [Member]

January 2015 Vesting [Member]

January 2015 Vesting [Member]

January 2016 Vesting [Member]

January 2016 Vesting [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

Restricted common units [Member]

Restricted common units [Member]

Restricted common units [Member]

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

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

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

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

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

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

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

Chief Executive Officer [Member]

Chief Executive Officer [Member]

Independent Directors [Member]

Independent Directors [Member]

Independent Directors [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

Phantom common units [Member]

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of units authorized

'

'

'

'

'

'

'

'

2,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Vesting period

'

'

'

'

'

'

'

'

'

'

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

Award vesting rights percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

33.00%

33.00%

33.00%

'

'

'

'

'

'

'

Value of award grants (in dollars)

'

'

'

$2,500,000

$40,320

$2,200,000

$2,400,000

$2,500,000

'

'

'

$2,800,000

'

$64,650

$49,200

$42,750

'

'

'

'

'

'

'

Unrecognized estimated compensation cost (in dollars)

'

'

'

'

'

'

'

'

1,800,000

'

'

'

2,100,000

'

'

'

'

'

'

'

'

'

'

Equity-based incentive compensation expense (in dollars)

$1,912,000

$1,897,000

$544,000

'

'

'

'

'

$2,300,000

$1,900,000

$500,000

'

'

'

'

'

'

'

'

'

'

'

'

Number of Units [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Units, Nonvested, Beginning balance

'

'

'

'

'

'

'

'

1,016,703

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Units, Granted

'

'

'

'

'

'

'

'

263,406

'

'

500,000

'

7,500

7,500

7,500

'

1,300

299,900

3,500

353,300

276,773

251,106

Number of Units, Vested

'

'

'

'

'

'

'

'

162,957

'

'

'

'

'

'

'

164,650

'

'

'

'

'

'

Number of Units, Forfeited

'

'

'

'

'

'

'

'

58,990

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Units, Nonvested, Ending balance

'

'

'

'

'

'

'

'

1,058,162

1,016,703

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted Average Grant Date Fair Value [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

$6.51

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

$9.06

$8.40

$8.75

$6.76

$8.25

$8.74

'

'

$5.62

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

$6.35

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

$7.67

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

$7.03

$6.51

'

'

'

'

'

'

'

'

'

'

'

'

'

EMPLOYEE_BENEFIT_PLAN_Details

EMPLOYEE BENEFIT PLAN (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
401 (k) Plan [Member]	'	'	'
Defined Contribution Plans Disclosure [Line Items]	'	'	'
Employer discretionary contribution amount	$1.40	$1.30	$1.30
Profit Sharing [Member]	'	'	'
Defined Contribution Plans Disclosure [Line Items]	'	'	'
Employer discretionary contribution amount	$0.80	$0.90	$0.90

PROFITS_INTEREST_OF_BLUEKNIGHT1

PROFITS INTEREST OF BLUEKNIGHT GP HOLDING, LLC (Details) (Chief Executive Officer [Member], USD $)	12 Months Ended		1 Months Ended		1 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Oct. 31, 2012	Dec. 31, 2013	Oct. 31, 2012
			Blueknight GP Holding, LLC [Member]	Blueknight GP Holding, LLC [Member]	Minimum [Member]
					Blueknight GP Holding, LLC [Member]
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]	'	'	'	'	'
Chief Executive Officer Non Voting Economic Interest In Company Vesting Percentage Increments	'	'	20.00%	'	'
Non Voting Economic Interest In Company Percentage Of Total Proceeds And Or Distributions Received By Company In Connection With A Transaction Resulting In A Change Of Control Of The Partnership	'	'	2.00%	'	'
Total Proceeds And Or Distributions Received By Company Connection With Transaction Resulting In Change Of Control Of Partnership Before Non Voting Economic Interest In Company Percentage	'	'	'	'	$100,000,000
Chief Executive Officer Non Voting Economic Interest In Company Percentage Of Quarterly Distributions Received By Company	'	'	2.00%	'	'
Minimum Quarterly Distributions Received By Company Before Chief Executive Officer Non Voting Economic Interest In Company Percentage Of Quarterly Distributions Received By Company Applies	'	'	1,250,000	'	'
Chief Executive Officer Non Voting Economic Interest In Company Amount Vested	'	'	'	20.00%	'
Chief Executive Officer Non Voting Economic Interest In Company, Amount Recognized During Period	$100,000	$100,000	'	'	'

COMMITMENTS_AND_CONTINGENCIES_1

COMMITMENTS AND CONTINGENCIES (Narrative) (Details) (USD $)

12 Months Ended

0 Months Ended

2 Months Ended

1 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jul. 08, 2009

Apr. 30, 2009

Jun. 10, 2013

Feb. 06, 2012

Jul. 13, 2012

Nov. 30, 2013

Dec. 31, 2013

Feb. 06, 2012

Jul. 13, 2012

Dismissed [Member]

Dismissed [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Minimum [Member]

Minimum [Member]

Wage Claims [Member]

Wage Claims [Member]

Physical Management and Control of Crude Oil [Member]

Physical Management and Control of Crude Oil [Member]

Motor Vehicle Negligence Suit [Member]

Insurance Claims [Member]

Insurance Claims [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Person

Person

bbl

bbl

Person

Pipeline_Systems

Physical Management and Control of Crude Oil [Member]

Motor Vehicle Negligence Suit [Member]

bbl

Commitments and Contingencies Disclosure [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Operating Leases, Rent Expense

$7,500,000

$6,500,000

$5,800,000

'

'

'

'

'

'

'

'

'

Loss Contingencies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Number of plaintiffs (in plaintiffs)

'

'

'

9

1

'

'

'

'

'

'

'

Claimants contended the Partnership's general partner's failure to deliver certificates for the phantom units after vesting, (in days) maximum

'

'

'

'

'60

'

'

'

'

'

'

'

Damages sought

'

'

'

'

2,000,000

'

'

'

'

'

'

75,000

Judgement seeking immediate return of crude cil Linefill belonging to company (in BOE)

'

'

'

'

'

'

140,000

'

'

'

'

'

Gain contingency, unrecorded amount

'

'

'

'

'

'

'

'

'

'

75,000

'

Gain Contingency, Partnership's Shortage Found by Special Master

'

'

'

'

'

148,000

'

'

'

'

'

'

Gain Contingency, Defendent's Overage Found By Special Master

'

'

'

'

'

130,000

'

'

'

'

'

'

Loss Contingency, Number of Deaths Related to Court Case

'

'

'

'

'

'

'

1

'

'

'

'

Number of Pipelines Systems Owned And Operated

'

'

'

'

'

'

'

'

1

'

'

'

Number of Barrels

'

'

'

'

'

'

'

'

500

'

'

'

Loss Contingency, Estimate of Possible Loss

'

'

'

'

'

'

'

'

'

2,100,000

'

'

Insurance Deductible Paid

'

'

'

'

'

'

'

'

'

$250,000

'

'

COMMITMENTS_AND_CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES Operating Leases (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]	'
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$7,034
Operating Leases, Future Minimum Payments, Due in Two Years	6,100
Operating Leases, Future Minimum Payments, Due in Three Years	3,524
Operating Leases, Future Minimum Payments, Due in Four Years	2,386
Operating Leases, Future Minimum Payments, Due in Five Years	1,774
Operating Leases, Future Minimum Payments, Due Thereafter	1,360
Operating Leases, Future Minimum Payments Due	$22,178

FAIR_VALUE_MEASUREMENTS_narrat

FAIR VALUE MEASUREMENTS narrative (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2011	Dec. 31, 2010
				Fair Value, Inputs, Level 3 [Member]	Fair Value, Inputs, Level 3 [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'	'	'	'
Fair Value, Measurement with Unobservable Inputs Reconciliations, Recurring Basis, Liability Value	'	'	'	$0	$37,991
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings	'	'	'	-22,107	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Other Comprehensive Income (Loss)	'	'	'	0	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Transfers, Net	'	'	'	-15,884	'
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers, Net	'	'	'	0	'
Fair Value, Liabilities Measured on Recurring Basis, Change in Unrealized Gain (Loss)	'	'	'	0	'
Change in fair value of embedded derivative within convertible debt	0	0	20,224	'	'
Change In Fair Value Of Rights Offering Liability	$0	$0	($1,883)	'	'

OPERATING_SEGMENTS_Details

OPERATING SEGMENTS (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Number of Operating Segments	'	'	'	'	'	'	'	'	4	'	'
Service revenue	'	'	'	'	'	'	'	'	'	'	'
Third party revenue	'	'	'	'	'	'	'	'	$142,916	$130,696	$129,104
Related party revenue	'	'	'	'	'	'	'	'	51,755	48,153	44,089
Total revenue for reportable segments	49,788	54,669	45,678	44,536	46,205	46,335	43,084	43,225	194,671	178,849	173,193
Operating margin (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	85,023	78,927	80,958
Total assets (end of period)	354,748	'	'	'	299,825	'	'	'	354,748	299,825	'
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes	'	'	'	'	'	'	'	'	'	'	'
Operating margin (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	85,023	78,927	80,958
Depreciation and amortization on continuing operations	'	'	'	'	'	'	'	'	-23,962	-22,824	-22,496
General and administrative expenses	'	'	'	'	'	'	'	'	-17,482	-19,795	-17,311
Gain on sale of assets	'	'	'	'	'	'	'	'	1,073	7,271	3,008
Gain on sale of assets	'	'	'	'	'	'	'	'	2,661	7,250	3,008
Asset impairment expense	'	'	'	'	'	'	'	'	-524	-1,942	-867
Interest expense (net of capitalized interest of $21, $150 and $1,048, respectively)	'	'	'	'	'	'	'	'	-11,615	-11,705	-32,898
Change in fair value of embedded derivative within convertible debt	'	'	'	'	'	'	'	'	0	0	20,224
Change In Fair Value Of Rights Offering Liability	'	'	'	'	'	'	'	'	0	0	1,883
Equity loss in unconsolidated affiliate	'	'	'	'	'	'	'	'	-502	0	0
Income from continuing operations before income taxes	'	'	'	'	'	'	'	'	32,011	29,932	32,501
Crude Oil Terminalling and Storage Services [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Property, Plant and Equipment, Additions	'	'	'	'	'	'	'	'	5,516	4,611	5,401
Service revenue	'	'	'	'	'	'	'	'	'	'	'
Third party revenue	'	'	'	'	'	'	'	'	11,910	11,825	11,067
Related party revenue	'	'	'	'	'	'	'	'	19,148	23,983	27,608
Total revenue for reportable segments	'	'	'	'	'	'	'	'	31,058	35,808	38,675
Operating expenses (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	3,979	3,941	4,555
Operating margin (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	27,079	31,867	34,120
Total assets (end of period)	64,591	'	'	'	67,051	'	'	'	64,591	67,051	69,840
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes	'	'	'	'	'	'	'	'	'	'	'
Operating margin (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	27,079	31,867	34,120
Crude Oil Pipeline Services [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Property, Plant and Equipment, Additions	'	'	'	'	'	'	'	'	51,609	12,396	6,144
Number of Pipelines Systems Owned And Operated	'	'	'	'	'	'	'	'	3	'	'
Service revenue	'	'	'	'	'	'	'	'	'	'	'
Third party revenue	'	'	'	'	'	'	'	'	15,658	13,696	14,121
Related party revenue	'	'	'	'	'	'	'	'	9,018	5,677	4,807
Total revenue for reportable segments	'	'	'	'	'	'	'	'	24,676	19,373	18,928
Operating expenses (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	17,767	16,572	14,558
Operating margin (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	6,909	2,801	4,370
Total assets (end of period)	169,739	'	'	'	105,498	'	'	'	169,739	105,498	99,228
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes	'	'	'	'	'	'	'	'	'	'	'
Operating margin (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	6,909	2,801	4,370
Crude Oil Trucking and Producer Field Services [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Property, Plant and Equipment, Additions	'	'	'	'	'	'	'	'	1,779	3,451	1,362
Service revenue	'	'	'	'	'	'	'	'	'	'	'
Third party revenue	'	'	'	'	'	'	'	'	51,545	46,164	44,366
Related party revenue	'	'	'	'	'	'	'	'	21,645	17,688	11,561
Total revenue for reportable segments	'	'	'	'	'	'	'	'	73,190	63,852	55,927
Operating expenses (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	63,123	56,194	50,465
Operating margin (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	10,067	7,658	5,462
Total assets (end of period)	20,073	'	'	'	18,646	'	'	'	20,073	18,646	15,917
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes	'	'	'	'	'	'	'	'	'	'	'
Operating margin (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	10,067	7,658	5,462
Asphalt Services [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Property, Plant and Equipment, Additions	'	'	'	'	'	'	'	'	6,052	6,260	6,080
Number of terminalling and storage facilities providing asphalt product and residual fuel terminalling storage and blending services (in terminalling and storage facilities)	42	'	'	'	'	'	'	'	42	'	'
Number of states that Asphalt product and residual fuel terminalling, storage and blending services at its terminalling and storage facilities are provided (in states)	21	'	'	'	'	'	'	'	21	'	'
Service revenue	'	'	'	'	'	'	'	'	'	'	'
Third party revenue	'	'	'	'	'	'	'	'	63,803	59,011	59,550
Related party revenue	'	'	'	'	'	'	'	'	1,944	805	113
Total revenue for reportable segments	'	'	'	'	'	'	'	'	65,747	59,816	59,663
Operating expenses (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	24,779	23,215	22,657
Operating margin (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	40,968	36,601	37,006
Total assets (end of period)	100,345	'	'	'	108,630	'	'	'	100,345	108,630	119,770
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes	'	'	'	'	'	'	'	'	'	'	'
Operating margin (excluding depreciation and amortization)	'	'	'	'	'	'	'	'	$40,968	$36,601	$37,006

INCOME_TAXES_Details

INCOME TAXES (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Gross income of a partnership, for any taxable year is qualifying income will be taxable as a corporation for federal income tax purposes for that taxable year and all subsequent years, maximum (as a percent)	90.00%
Federal statutory income tax rate (as a percent)	35.00%
Difference in bases of property, plant and equipment	$1,012
Deferred tax asset	1,012
Less: valuation allowance	-1,012
Net deferred tax asset	$0

QUARTERLY_FINANCIAL_DATA_Detai

QUARTERLY FINANCIAL DATA (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Quarterly Financial Data [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total revenue	$49,788	$54,669	$45,678	$44,536	$46,205	$46,335	$43,084	$43,225	$194,671	$178,849	$173,193
Operating Income (Loss)	7,893	18,363	9,704	8,168	8,321	10,453	8,774	14,089	44,128	41,637	43,292
Income (Loss) from Continuing Operations Attributable to Parent	5,148	16,030	4,934	5,306	5,439	7,429	5,804	10,942	31,418	29,614	32,214
Income (loss) from discontinued operations (including asset impairment expense of $6,353 for the year ended December 31, 2013) (See Note 5)	159	-5,489	1,231	716	78	478	343	1,052	-3,383	1,951	1,261
Net income	$5,307	$10,541	$6,165	$6,022	$5,517	$7,907	$6,147	$11,994	$28,035	$31,565	$33,475
Basic net income (loss) per common unit	($0.01)	$0.21	$0.03	$0.02	'	'	'	'	$0.25	$0.32	($0.61)
Diluted net income per common unit	($0.01)	$0.19	$0.03	$0.02	$0	$0.10	$0.02	$0.20	$0.25	$0.32	($0.61)

SUBSEQUENT_EVENTS_Details

SUBSEQUENT EVENTS (Details) (Subsequent Event [Member], USD $)	Mar. 10, 2014
In Millions, unless otherwise specified
Subsequent Event [Line Items]	'
Derivative, Notional Amount	$200
Interest Rate Swap June 28, 2014	'
Subsequent Event [Line Items]	'
Derivative, Fixed Interest Rate	1.45%
Interest Rate Swap January 28, 2015	'
Subsequent Event [Line Items]	'
Derivative, Fixed Interest Rate	1.92%