Blueknight Energy Partners (BKEP) 10-Q 7 May 15 2015 Q1 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	3 Months Ended
	Mar. 31, 2015	1-May-15
Entity Information [Line Items]
Entity Registrant Name	Blueknight Energy Partners, L.P.
Entity Central Index Key	1392091
Current Fiscal Year End Date	-19
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		32,915,481
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Current assets:
Cash and cash equivalents	$2,383	$2,661
Accounts receivable, net of allowance for doubtful accounts of $222 and $218 at December 31, 2014 and March 31, 2015, respectively	10,272	9,051
Receivables from related parties, net of allowance for doubtful accounts of $225 for both dates	2,765	2,316
Prepaid insurance	2,104	1,582
Investments	0	2,079
Other current assets	3,888	3,805
Total current assets	21,412	21,494
Property, plant and equipment, net of accumulated depreciation of $192,440 and $198,600 at December 31, 2014 and March 31, 2015, respectively	309,233	310,163
Investment in unconsolidated affiliate	19,131	20,381
Goodwill	7,216	7,216
Debt issuance costs, net	2,866	3,085
Intangibles and other assets, net	2,043	2,056
Total assets	361,901	364,395
Current liabilities:
Accounts payable	6,898	7,626
Accrued interest payable	202	233
Accrued property taxes payable	1,684	2,046
Unearned revenue	1,213	1,531
Unearned revenue with related parties	802	909
Accrued payroll	3,619	6,520
Other current liabilities	3,199	3,204
Total current liabilities	17,617	22,069
Unearned revenue with related parties, noncurrent	107	116
Other long-term liabilities	4,324	3,620
Interest rate swaps liability	4,440	2,634
Long-term debt	224,000	216,000
Commitments and contingencies (Note 12)
Partners’ capital:
Series A Preferred Units (30,158,619 units issued and outstanding for both dates)	204,599	204,599
Common unitholders (32,774,163 and 32,915,481 units issued and outstanding at December 31, 2014 and March 31, 2015, respectively)	517,388	525,767
General partner interest (1.8% interest with 1,127,755 general partner units outstanding at both dates)	-610,574	-610,410
Total Partners’ capital	111,413	119,956
Total liabilities and Partners’ capital	$361,901	$364,395

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, except Share data, unless otherwise specified
Current assets:
Accounts receivable, allowance for doubtful accounts	$218	$222
Receivables from related parties, allowance for doubtful accounts	225	225
Accumulated Depreciation and Impairments, property plant and equipment	$198,600	$192,440
Partners’ capital:
Series A Preferred unitholders, units issued	30,158,619	30,158,619
Preferred Units, Outstanding	30,158,619	30,158,619
Common unitholders, units issued	32,915,481	32,774,163
Common unitholders, units outstanding	32,915,481	32,774,163
General partner interest, units outstanding	1,127,755	1,127,755
General partner percentage interest	1.80%	1.80%

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Service revenue:
Third party revenue	$32,123	$34,236
Related party revenue	10,233	12,206
Total revenue	42,356	46,442
Expense:
Operating	32,386	35,500
General and administrative	4,977	4,487
Total expense	37,363	39,987
Gain on sale of assets	304	397
Operating income	5,297	6,852
Other income (expense):
Equity earnings (loss) in unconsolidated affiliate	656	-204
Interest expense (net of capitalized interest of $80 and $23, respectively)	-4,283	-2,655
Income before income taxes	1,670	3,993
Provision for income taxes	91	101
Net income	1,579	3,892
Allocation of net income for calculation of earnings per unit:
General partner interest in net income	103	93
Preferred interest in net income	5,391	5,391
Loss available to limited partners	($3,915)	($1,592)
Basic and diluted net loss per common unit	($0.12)	($0.07)
Common units	32,894	22,900

CONSOLIDATED_STATEMENTS_OF_OPE1

CONSOLIDATED STATEMENTS OF OPERATIONS CONSOLIDATED STATEMENT OF OPERATIONS (Parenthetical) (USD $)	3 Months Ended
In Millions, except Share data in Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Income Statement [Abstract]
Capitalized interest	$0.10	$0.10
Diluted net income per common unit	($0.12)	($0.07)
Weighted Average Limited Partnership Units Outstanding, Diluted	32,894	22,900

CONSOLIDATED_STATEMENTS_OF_CHA

CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERS' CAPITAL (USD $)	Total	Common Unitholders [Member]	Series A Preferred Unitholders [Member]	General Partner Interest [Member]
In Thousands, unless otherwise specified
Balance at Dec. 31, 2014	$119,956	$525,767	$204,599	($610,410)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,579	-3,839	5,391	27
Equity-based incentive compensation	11	10		1
Profits interest contribution	37			37
Distributions	-10,170	-4,550	-5,391	-229
Balance at Mar. 31, 2015	$111,413	$517,388	$204,599	($610,574)

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash flows from operating activities:
Net income	$1,579	$3,892
Adjustments to reconcile net income to net cash provided by operating activities:
Provision for uncollectible receivables from third parties	-4	0
Depreciation and amortization	6,646	6,317
Amortization and write-off of debt issuance costs	219	199
Unrealized loss related to interest rate swaps	1,806	355
Gain on sale of assets	304	397
Equity-based incentive compensation	11	-53
Equity (earnings) loss in unconsolidated affiliate	656	-204
Gain related to investments	-267	0
Changes in assets and liabilities
Decrease (increase) in accounts receivable	-1,217	719
Decrease (increase) in receivables from related parties	-449	433
Decrease in prepaid insurance	278	261
Decrease (increase) in other current assets	-83	373
Decrease in other assets	4	76
Decrease in accounts payable	-135	-1,072
Decrease in accrued interest payable	-31	-238
Decrease in accrued property taxes	-362	-431
Increase in unearned revenue	424	832
Decrease in unearned revenue from related parties	-116	-8
Decrease in accrued payroll	-2,901	-3,673
Decrease in other accrued liabilities	-360	-1,569
Net cash provided by operating activities	4,082	6,220
Cash flows from investing activities:
Capital expenditures	-6,413	-7,878
Proceeds from sale of assets	417	453
Distributions from unconsolidated affiliate	1,906	0
Proceeds from sale of investments	2,346	0
Net cash used in investing activities	-1,744	-7,425
Cash flows from financing activities:
Payment on insurance premium financing agreement	-483	-597
Borrowings under credit facility	25,000	15,000
Payments under credit facility	-17,000	-7,000
Capital contribution related to profits interest	37	37
Distributions	-10,170	-8,511
Net cash used in financing activities	-2,616	-1,071
Net decrease in cash and cash equivalents	-278	-2,276
Cash and cash equivalents at beginning of period	2,661	3,182
Cash and cash equivalents at end of period	2,383	906
Supplemental disclosure of cash flow information:
Increase (decrease) in accounts payable related to purchase of property, plant and equipment	-593	2,346
Increase in accrued liabilities related to insurance premium financing agreement	$800	$899

ORGANIZATION_AND_NATURE_OF_BUS

ORGANIZATION AND NATURE OF BUSINESS	3 Months Ended
	Mar. 31, 2015
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	3 Months Ended
	Mar. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
BASIS OF CONSOLIDATION AND PRESENTATION	BASIS OF CONSOLIDATION AND PRESENTATION
	The financial statements have been prepared in accordance with accounting principles and practices generally accepted in the United States of America (“GAAP”).  The consolidated statements of operations for the three months ended March 31, 2014 and 2015, the consolidated statement of changes in partners’ capital for the three months ended March 31, 2015, the consolidated statements of cash flows for the three months ended March 31, 2014 and 2015, and the consolidated balance sheet as of March 31, 2015 are unaudited.  In the opinion of management, the unaudited consolidated financial statements have been prepared on the same basis as the audited financial statements and include all adjustments necessary to state fairly the financial position and results of operations for the respective interim periods.  All adjustments are of a recurring nature unless otherwise disclosed herein.  The 2014 year-end consolidated balance sheet data was derived from audited financial statements but does not include all disclosures required by GAAP.  These unaudited consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and notes thereto included in the Partnership’s annual report on Form 10-K for the year ended December 31, 2014 filed with the Securities and Exchange Commission (the “SEC”) on March 11, 2015 (the “2014 Form 10-K”).  Interim financial results are not necessarily indicative of the results to be expected for an annual period.  The Partnership’s significant accounting policies are consistent with those disclosed in Note 4 of the Notes to Consolidated Financial Statements in its 2014 Form 10-K.
	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. 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 consolidated balance sheet. Distributions to the Partnership reduce the carrying value of its investment and are 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.
	In November 2014, the Partnership received 30,393 Class A Common Units of SemCorp in connection with the settlement of two unsecured claims the Partnership filed in connection with SemCorp's predecessor's bankruptcy filing in 2008. The fair market value of these units on the date of receipt was $2.5 million. In March 2015, the Partnership sold all of these units for a total of $2.3 million.

PROPERTY_PLANT_AND_EQUIPMENT

PROPERTY, PLANT AND EQUIPMENT	3 Months Ended
	Mar. 31, 2015
Property, Plant and Equipment [Abstract]
PROPERTY, PLANT AND EQUIPMENT	PROPERTY, PLANT AND EQUIPMENT
		Estimated Useful Lives (Years)	December 31, 2014			March 31,
						2015
			(dollars in thousands)
	Land	N/A	$	18,292		$	19,287
	Land improvements	20-Oct	6,398			6,398
	Pipelines and facilities	30-May	168,537			175,333
	Storage and terminal facilities	Oct-35	240,004			242,027
	Transportation equipment	10-Mar	13,557			13,219
	Office property and equipment and other	20-Mar	28,958			29,050
	Pipeline linefill and tank bottoms	N/A	10,186			10,186
	Construction-in-progress	N/A	16,671			12,333
	Property, plant and equipment, gross		502,603			507,833
	Accumulated depreciation		(192,440		)	(198,600		)
	Property, plant and equipment, net		$	310,163		$	309,233
	Depreciation expense for the three months ended March 31, 2014 and 2015 was $6.3 million and $6.6 million, respectively.

DEBT

DEBT	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
DEBT	DEBT
	On June 28, 2013, the Partnership entered into an amended and restated credit agreement that consists of a $400.0 million revolving loan facility. On September 15, 2014, the Partnership amended its credit facility to, among other things, amend the maximum permitted consolidated total leverage ratio as discussed below and to increase the limit on material project adjustments to EBITDA (as defined in the credit agreement).
	As of May 1, 2015, approximately $231.0 million of revolver borrowings and $0.9 million of letters of credit were outstanding under the credit facility, leaving the Partnership with approximately $168.1 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. 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, as amended on September 15, 2014.
	The credit agreement is guaranteed by all of the Partnership’s existing subsidiaries. Obligations under the credit agreement are secured by first priority liens on substantially all of the Partnership’s assets and those of the guarantors.
	The credit agreement includes procedures for additional financial institutions to become revolving lenders, or for any existing lender to increase its revolving commitment thereunder, subject to an aggregate maximum of $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 1.0%) plus an applicable margin that ranges from 1.0% to 2.0%.  The Partnership pays a per annum fee on all letters of credit issued under the credit agreement, which fee equals the applicable margin for loans accruing interest based on the eurodollar rate, and the Partnership pays a commitment fee ranging from 0.375% to 0.5% on the unused commitments under the credit agreement.  The applicable margins for the Partnership’s interest rate, the letter of credit fee and the commitment fee vary quarterly based on the Partnership’s consolidated total leverage ratio (as defined in the credit agreement, being generally computed as the ratio of consolidated total debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges).
	The credit agreement includes financial covenants that are tested on a quarterly basis, based on the rolling four-quarter period that ends on the last day of each fiscal quarter.
	Prior to the date on which the Partnership issues qualified senior notes in an aggregate principal amount (when combined with all other qualified senior notes previously or concurrently issued) that equals or exceeds $200.0 million, the maximum permitted consolidated total leverage ratio is 4.50 to 1.00; provided that:
	•	after the Partnership delivers the Knight Warrior Pipeline Initiation Certificate (as defined in the credit agreement, but generally meaning that the Partnership has spent at least $15.0 million of the projected capital expenditures for its Knight Warrior pipeline project), the maximum permitted consolidated total leverage ratio is 5.00 to 1.00 for the fiscal quarters ending March 31, 2015 through September 30, 2016, 4.75 to 1.00 for the fiscal quarter ending December 31, 2016, and 4.50 to 1.00 for each fiscal quarter thereafter;
	•	after the Partnership delivers the Knight Warrior Pipeline Leverage Election Certificate (as defined in the credit agreement, but generally meaning that the Partnership has spent at least 50% of the projected capital expenditures for the Knight Warrior pipeline project), the Partnership may elect to increase the maximum permitted consolidated total leverage ratio to 5.50 to 1.00 for two consecutive fiscal quarters ending on or before September 30, 2016; and
	•	if the Partnership makes a specified acquisition (as defined in the credit agreement, but generally being an acquisition with consideration in excess of $10.0 million), the Partnership may elect to increase the maximum permitted consolidated total leverage ratio to 5.00 to 1.00 from and after the last day of the fiscal quarter immediately preceding the fiscal quarter in which such acquisition occurs to and including the last day of the second full fiscal quarter following the fiscal quarter in which such acquisition occurred.
	From and after the date on which the Partnership issues qualified senior notes in an aggregate principal amount (when combined with all other qualified senior notes previously or concurrently issued) that equals or exceeds $200.0 million, the maximum permitted consolidated total leverage ratio is 5.00 to 1.00; provided that after the Partnership delivers the Knight Warrior Pipeline Initiation Certificate, the maximum permitted consolidated total leverage ratio is 5.50 to 1.00 for the fiscal quarters ending March 31, 2015 through September 30, 2016, and 5.00 to 1.00 for each fiscal quarter thereafter.
	The maximum permitted consolidated senior secured leverage ratio (as defined in the credit agreement, but generally computed as the ratio of consolidated total secured debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges) is 3.50 to 1.00, but this covenant is only tested from and after the date on which the Partnership issues qualified senior notes in an aggregate principal amount (when combined with all other qualified senior notes previously or concurrently issued) that equals or exceeds $200.0 million.
	The minimum permitted consolidated interest coverage ratio (as defined in the credit agreement, but generally computed as the ratio of consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges to consolidated interest expense) is 2.50 to 1.00.
	In addition, the credit agreement contains various covenants that, among other restrictions, limit the Partnership’s ability to:
	•	create, issue, incur or assume indebtedness;
	•	create, incur or assume liens;
	•	engage in mergers or acquisitions;
	•	sell, transfer, assign or convey assets;
	•	repurchase the Partnership’s equity, make distributions to unitholders and make certain other restricted payments;
	•	make investments;
	•	modify the terms of certain indebtedness, or prepay certain indebtedness;
	•	engage in transactions with affiliates;
	•	enter into certain hedging contracts;
	•	enter into certain burdensome agreements;
	•	change the nature of the Partnership’s business;
	•	enter into operating leases; and
	•	make certain amendments to the Partnership’s partnership agreement.
	At March 31, 2015, the Partnership’s consolidated total leverage ratio was 3.43 to 1.00 and the consolidated interest coverage ratio was 7.11 to 1.00.  The Partnership was in compliance with all covenants of its credit agreement as of March 31, 2015.
	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 6 for additional information regarding distributions.
	In addition to other customary events of default, the Credit Agreement includes an event of default if (i) the General Partner ceases to own 100% of the Partnership’s general partner interest or ceases to control the Partnership or (ii) Vitol Holding B.V. (together with its affiliates, “Vitol”) and Charlesbank Capital Partners, LLC cease 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.
	During the three months ended March 31, 2014 and 2015, the Partnership capitalized no debt issuance costs for either period. 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 each of the three months ended March 31, 2014 and 2015 was $0.2 million.
	During the three months ended March 31, 2014 and 2015, the weighted average interest rate under the Partnership’s credit agreement was 3.44% and 3.41%, respectively, resulting in interest expense of approximately $2.4 million and $1.9 million, respectively. As of March 31, 2015, borrowings under the Partnership’s amended and restated credit agreement bore interest at a weighted average interest rate of 3.41%.
	During the three months ended March 31, 2014 and 2015, the Partnership capitalized interest of $0.1 million and less than $0.1 million, respectively.
	The Partnership is exposed to market risk for changes in interest rates related to its credit facility. Interest rate swap agreements are used to manage a portion of the exposure related to changing interest rates by converting floating-rate debt to fixed-rate debt. In March 2014 the Partnership entered into two interest rate swap agreements with an aggregate notional amount of $200.0 million. The first agreement has a notional amount of $100.0 million, became effective June 28, 2014, and matures on June 28, 2018. Under the terms of the first interest rate swap agreement, the Partnership pays a fixed rate of 1.45% and receives one-month LIBOR with monthly settlement. The second agreement has a notional amount of $100.0 million, became 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 1.97% and will receive one-month LIBOR with monthly settlement. During the three months ended March 31, 2015, the Partnership recorded swap interest expense of $0.6 million. The Partnership did not have any swap interest expense for the three months ended March 31, 2014. The fair market value of the interest rate swaps at December 31, 2014 and March 31, 2015 is a liability of $2.6 million and $4.4 million, respectively, and is recorded in long-term derivative liabilities on the consolidated balance sheets. The interest rate swaps do not receive hedge accounting treatment under ASC 815 - Derivatives and Hedging. Changes in the fair value of the interest rate swaps are recorded in interest expense in the consolidated statements of operations.

NET_INCOME_PER_LIMITED_PARTNER

NET INCOME PER LIMITED PARTNER UNIT	3 Months Ended
	Mar. 31, 2015
Earnings Per Share [Abstract]
NET INCOME PER LIMITED PARTNER UNIT	NET INCOME PER LIMITED PARTNER UNIT
	For purposes of calculating earnings per unit, the excess of distributions over earnings or excess of earnings over distributions for each period are allocated to the Partnership’s general partner based on the general partner’s ownership interest at the time. The following sets forth the computation of basic and diluted net income (loss) per common unit (in thousands, except per unit data):
		Three Months ended
		March 31,
		2014			2015
	Net income	3,892			1,579
	General partner interest in net income	93			103
	Preferred interest in net income	5,391			5,391
	Loss available to limited partners	$	(1,592	)	$	(3,915	)
	Basic and diluted weighted average number of units:
	Common units	22,900			32,894
	Restricted and phantom units	526			562
	Basic and diluted net loss per common unit	$	(0.07	)	$	(0.12	)

PARTNERS_CAPITAL_AND_DISTRIBUT

PARTNERS' CAPITAL AND DISTRIBUTIONS	3 Months Ended
	Mar. 31, 2015
Partners' Capital Account, Distributions [Abstract]
PARTNERS' CAPITAL AND DISTRIBUTIONS	PARTNERS’ CAPITAL AND DISTRIBUTIONS
	On September 22, 2014, the Partnership issued and sold 9,775,000 common units for a public offering price of $7.61, resulting in proceeds of approximately $71.2 million, net of underwriters' discount and offering expenses of $3.2 million.
	On April 21, 2015, the Board approved a distribution of $0.17875 per preferred unit, or a total distribution of $5.4 million, for the quarter ending March 31, 2015.  The Partnership will pay this distribution on the preferred units on May 15, 2015 to unitholders of record as of May 5, 2015.
	In addition, on April 21, 2015, the Board declared a cash distribution of $0.1395 per unit on its outstanding common units, a 2.2% increase over the previous quarter’s distribution. The distribution will be paid on May 15, 2015 to unitholders of record on May 5, 2015. The distribution is for the three months ended March 31, 2015. The total distribution will be approximately $5.0 million, with approximately $4.6 million and $0.3 million to be paid to the Partnership’s common unitholders and general partner, respectively, and $0.1 million to be paid to holders of phantom and restricted units pursuant to awards granted under the Partnership’s long-term incentive plan.

RELATED_PARTY_TRANSACTIONS

RELATED PARTY TRANSACTIONS	3 Months Ended
	Mar. 31, 2015
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	RELATED PARTY TRANSACTIONS
	The Partnership provides crude oil gathering, transportation, terminalling and storage services to Vitol as well as certain operating, strategic assessment, economic evaluation and project design services.  For the three months ended March 31, 2014 and 2015, the Partnership recognized revenues of $12.0 million and $9.9 million, respectively, for services provided to Vitol. As of December 31, 2014 and March 31, 2015, the Partnership had receivables from Vitol of $2.3 million and $2.7 million, net of allowance for doubtful accounts. As of December 31, 2014 and March 31, 2015, the Partnership had unearned revenues from Vitol of $1.0 million and $0.9 million, respectively.
	The Partnership also provides operating and administrative services to Advantage Pipeline. For the three months ended March 31, 2014 and 2015, the Partnership earned revenues of $0.2 million and $0.3 million, respectively, for services provided to Advantage Pipeline. As of December 31, 2014 and March 31, 2015, the Partnership had receivables from Advantage Pipeline of less than $0.1 million for both periods.

LONGTERM_INCENTIVE_PLAN

LONG-TERM INCENTIVE PLAN	3 Months Ended
	Mar. 31, 2015
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. Effective April 29, 2014, the Partnership's unitholders approved an amendment to the LTIP to increase the number of common units reserved for issuance under the incentive plan by 1,500,000 common units from 2,600,000 common units to 4,100,000 common units. The common units are 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 under ASC 718 - Stock Compensation and, accordingly, the fair value of the awards as of the grant date is expensed over the vesting period.
	In each of December 2012, 2013 and 2014, 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 grant date fair value of the restricted units for the 2012 and 2014 grants was less than $0.1 million while the grant date fair value of the restricted units for the 2013 grant was $0.1 million.
	In March 2013, 2014 and 2015, grants for 251,106, 276,773 and 266,076 phantom units, respectively, were made, which vest on January 1, 2016, January 1, 2017 and January 1, 2018, 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 $8.75, $9.06 and $7.74 per unit, respectively, which is the closing market price on the grant date of the awards. The value of these award grants was approximately $2.2 million, $2.5 million and $2.1 million respectively, on their grant date. The unrecognized estimated compensation cost of outstanding phantom units at March 31, 2015 was $3.8 million, which will be recognized over the remaining vesting period.
	In September 2012, Mr. 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 March 31, 2015 was $1.4 million and will be expensed over the remaining vesting period.
	The Partnership’s equity-based incentive compensation expense for each of the three months ended March 31, 2014 and 2015 was $0.5 million.
	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, 2014	1,020,264	$	7.46
	Granted	266,076	7.74
	Vested	222,800	6.76
	Forfeited	14,765	8.96
	Nonvested at March 31, 2015	1,048,775	$	7.66

EMPLOYEE_BENEFIT_PLAN

EMPLOYEE BENEFIT PLAN	3 Months Ended
	Mar. 31, 2015
Compensation and Retirement Disclosure [Abstract]
EMPLOYEE BENEFIT PLAN	EMPLOYEE BENEFIT PLANS
	Under the Partnership’s 401(k) Plan, which was instituted in 2009, employees who meet specified service requirements may contribute a percentage of their total compensation, up to a specified maximum, to the 401(k) Plan. The Partnership may match each employee’s contribution, up to a specified maximum, in full or on a partial basis.  The Partnership recognized expense of $0.4 million for each of the three months ended March 31, 2014 and 2015 for discretionary contributions under the 401(k) Plan.
	The Partnership may also make annual lump-sum contributions to the 401(k) Plan irrespective of the employee’s contribution match. The Partnership may make a discretionary annual contribution in the form of profit sharing calculated as a percentage of an employee’s eligible compensation. This contribution is retirement income under the qualified 401(k) Plan. Annual profit sharing contributions to the 401(k) Plan are submitted to and approved by the Board. The Partnership recognized expense of $0.2 million for both the three months ended March 31, 2014 and 2015 for discretionary profit sharing contributions under the 401(k) Plan.
	Under the Partnership’s Unit Purchase Plan, which was instituted in January 2015, employees have the opportunity to acquire or increase their ownership of common units representing limited partner interests in the Partnership. Eligible employees who enroll in the Unit Purchase Plan may elect to have a designated whole percentage, up to a specified maximum, of their eligible compensation for each pay period withheld for the purchase of common units at a discount to the then current market value. A maximum of 1,000,000 common units may be delivered under the Unit Purchase Plan, subject to adjustment for a recapitalization, split, reorganization or similar event pursuant to the terms of the Unit Purchase Plan. The Partnership recognized compensation expense of less than $0.1 million for the three months ended March 31, 2015 in connection with the Unit Purchase Plan.

FAIR_VALUE_MEASUREMENTS

FAIR VALUE MEASUREMENTS	3 Months Ended
	Mar. 31, 2015
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.  In periods in which they occur, the Partnership recognizes transfers into and out of Level 3 as of the end of the reporting period. Transfers out of Level 3 represent existing assets and liabilities that were classified previously as Level 3 for which the observable inputs became a more significant portion of the fair value estimates. Determining the appropriate classification of the Partnership’s fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data.
	The Partnership’s recurring financial assets and liabilities subject to fair value measurements and the necessary disclosures are as follows (in thousands):
		Fair Value Measurements as of December 31, 2014
	Description	Total		Quoted Prices		Significant		Significant
				in Active		Other		Unobservable
				Markets for		Observable		Inputs
				Identical Assets		Inputs		(Level 3)
				(Level 1)		(Level 2)
	Liabilities:
	Interest rate swap liabilities	$	2,634	$	—	$	2,634	$	—
	Total	$	2,634	$	—	$	2,634	$	—
		Fair Value Measurements as of March 31, 2015
	Description	Total		Quoted Prices		Significant		Significant
				in Active		Other		Unobservable
				Markets for		Observable		Inputs
				Identical Assets		Inputs		(Level 3)
				(Level 1)		(Level 2)
	Liabilities:
	Interest rate swap liabilities	$	4,440	$	—	$	4,440	$	—
	Total	$	4,440	$	—	$	4,440	$	—
	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 March 31, 2015, the carrying values on the unaudited condensed consolidated balance sheets for cash and cash equivalents (classified as Level 1), accounts receivable and accounts payable approximate their fair value because of their short term nature.
	Based on the borrowing rates currently available to the Partnership for credit agreement debt with similar terms and maturities and consideration of the Partnership’s non-performance risk, long-term debt associated with the Partnership’s credit agreement at March 31, 2015 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	3 Months Ended
	Mar. 31, 2015
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 the Eagle North System, 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 the Eagle North system.
	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):
			Three Months ended
			March 31,
			2014			2015
	Crude Oil Terminalling and Storage Services
	Service revenue
	Third party revenue		$	2,841		$	2,553
	Related party revenue		4,515			3,077
	Total revenue for reportable segments		7,356			5,630
	Operating expense (excluding depreciation and amortization)		970			1,561
	Operating margin (excluding depreciation and amortization)		6,386			4,069
	Total assets (end of period)		$	67,436		$	68,859
	Crude Oil Pipeline Services
	Service revenue
	Third party revenue		$	3,099		$	4,275
	Related party revenue		1,887			2,383
	Total revenue for reportable segments		4,986			6,658
	Operating expense (excluding depreciation and amortization)		4,381			3,909
	Operating margin (excluding depreciation and amortization)		605			2,749
	Total assets (end of period)		$	164,902		$	184,061
	Crude Oil Trucking and Producer Field Services
	Service revenue
	Third party revenue		$	13,850		$	10,682
	Related party revenue		5,547			4,621
	Total revenue for reportable segments		19,397			15,303
	Operating expense (excluding depreciation and amortization)		16,980			14,118
	Operating margin (excluding depreciation and amortization)		2,417			1,185
	Total assets (end of period)		$	24,877		$	18,002
	Asphalt  Services
	Service revenue
	Third party revenue		$	14,446		$	14,613
	Related party revenue		257			152
	Total revenue for reportable segments		14,703			14,765
	Operating expense (excluding depreciation and amortization)		6,852			6,152
	Operating margin (excluding depreciation and amortization)		7,851			8,613
	Total assets (end of period)		$	97,742		$	90,979
	Total operating margin (excluding depreciation and amortization)(1)		$	17,259		$	16,616
	____________________
	(1)The following table reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes (in thousands):
		Three Months ended March 31,
		2014			2015
	Operating margin (excluding depreciation and amortization)	$	17,259		$	16,616
	Depreciation and amortization	(6,317		)	(6,646		)
	General and administrative expenses	(4,487		)	(4,977		)
	Asset impairment expense	—			—
	Gain on sale of assets	397			304
	Interest expense	(2,655		)	(4,283		)
	Equity earnings (loss) in unconsolidated affiliate	(204		)	656
	Income before income taxes	$	3,993		$	1,670

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	3 Months Ended
	Mar. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
COMMITMENT AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES
	The Partnership is from time to time subject to various legal actions and claims incidental to its business. Management believes that these legal proceedings will not have a material adverse effect on the financial position, results of operations or cash flows of the Partnership. Once management determines that information pertaining to a legal proceeding indicates that it is probable that a liability has been incurred and the amount of such liability can be reasonably estimated, an accrual is established equal to its estimate of the likely exposure.
	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 SemGroup Corporation (“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. The Partnership believes any settlement will not have a material adverse effect on the Partnership's financial condition or results of operations.
	On February 6, 2012, the Partnership filed suit against SemCorp and others in Oklahoma County District Court. 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 allowed for additional discovery to take place and referred all discovery matters to the Special Master, as appropriate, and made other procedural rulings. The Partnership reasserted its fraud claims in accordance with the Court’s directives. Discovery proceedings continue and the Partnership has determined that SemCorp knew of its excess inventory and sold this inventory during the period prior to the Partnership's filing of the lawsuit while denying that the Partnership claims had any validity and failing to disclose the excess to the Partnership. 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.
	On November 1, 2014, a multi-vehicular accident occurred resulting in the death of an employee of the Partnership and allegations of injuries to third parties and injury to property. Litigation has been filed by injured third parties. The matter has been submitted to the Partnership’s insurance carriers and the retentions have been reserved. The ultimate outcome of this matter cannot be determined at this time.
	On February 13, 2015, a multi-vehicular accident occurred resulting in injury to third parties and two employees of the Partnership as well as property damage. Litigation has been filed by injured third parties. The matter has been submitted to the Partnership’s insurance carriers and the retentions have been reserved. The ultimate outcome of this matter cannot be determined at this time.
	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.

INCOME_TAXES

INCOME TAXES	3 Months Ended
	Mar. 31, 2015
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES
	The anticipated after-tax economic benefit of an investment in the Partnership’s 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 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 March 31, 2015 are presented below (dollars in thousands):
	Deferred tax assets
	Difference in bases of property, plant and equipment	$	933
	Deferred tax asset	933
	Less: valuation allowance	(933		)
	Net deferred tax asset	$	—
	The Partnership has considered the taxable income projections in future years, whether the carryforward period is so brief that it would limit realization of tax benefits, whether future revenue and operating cost projections will produce enough taxable income to realize the deferred tax asset based on existing service rates and cost structures, and the Partnership’s earnings history exclusive of the loss that created the future deductible amount for the Partnership’s subsidiary that is taxed as a corporation for purposes of determining the likelihood of realizing the benefits of the deferred tax assets. As a result of the Partnership’s consideration of these factors, the Partnership has provided a full valuation allowance against its deferred tax asset as of March 31, 2015.

RECENTLY_ISSUED_ACCOUNTING_STA

RECENTLY ISSUED ACCOUNTING STANDARDS	3 Months Ended
	Mar. 31, 2015
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
RECENTLY ISSUED ACCOUNTING STANDARDS	RECENTLY ISSUED ACCOUNTING STANDARDS
	In April 2014, the FASB issued ASU 2014-08, “Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity.” The amendments in this update change the criteria for reporting discontinued operations for all public and nonpublic entities. The amendments also require new disclosures about discontinued operations and disposals of components of an entity that do not qualify for discontinued operations reporting. The amendments in this update are effective for fiscal years, and interim periods within those years, beginning after December 15, 2014. The Partnership adopted this update for the period ending March 31, 2015, and there was no impact on the Partnership’s financial position, results of operations or cash flows.
	In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers.” The amendments in this update create Topic 606, Revenue from Contracts with Customers, and supersede the revenue recognition requirements in Topic 605, Revenue Recognition, including most industry-specific revenue recognition guidance throughout the Industry Topics of the Codification. In addition, the amendments supersede the cost guidance in Subtopic 605-35, Revenue Recognition-Construction-Type and Production-Type Contracts, and create new Subtopic 340-40, Other Assets and Deferred Costs-Contracts with Customers. In summary, the core principle of Topic 606 is that an entity recognizes revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The amendments in this update are effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. 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, 2018.
	In August 2014, the FASB issued ASU 2014-15, “Presentation of Financial Statements - Going Concern.” The update provides U.S. GAAP guidance on management’s responsibility in evaluating whether there is substantial doubt about a company’s ability to continue as a going concern and about related footnote disclosures. For each reporting period, management will be required to evaluate whether there are conditions or events that raise substantial doubt about a company’s ability to continue as a going concern within one year from the date the financial statements are issued. The amendments in this update are effective for the annual period ending after December 15, 2016, and for annual periods and interim periods thereafter. The Partnership is evaluating the impact of this guidance, which will be adopted beginning with the Partnership's annual report for the period ending December 31, 2016.
	On April 7, 2015, the FASB issued ASU 2015-03, “Simplifying the Presentation of Debt Issuance Costs”, which requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability. This update is effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. The Partnership is evaluating the impact of this guidance, which will be adopted beginning with the Partnership's quarterly report for the period ending March 31, 2016.

PROPERTY_PLANT_AND_EQUIPMENT_T

PROPERTY, PLANT AND EQUIPMENT (Tables)	3 Months Ended
	Mar. 31, 2015
Property, Plant and Equipment [Abstract]
Schedule of Property, Plant and Equipment
		Estimated Useful Lives (Years)	December 31, 2014			March 31,
						2015
			(dollars in thousands)
	Land	N/A	$	18,292		$	19,287
	Land improvements	20-Oct	6,398			6,398
	Pipelines and facilities	30-May	168,537			175,333
	Storage and terminal facilities	Oct-35	240,004			242,027
	Transportation equipment	10-Mar	13,557			13,219
	Office property and equipment and other	20-Mar	28,958			29,050
	Pipeline linefill and tank bottoms	N/A	10,186			10,186
	Construction-in-progress	N/A	16,671			12,333
	Property, plant and equipment, gross		502,603			507,833
	Accumulated depreciation		(192,440		)	(198,600		)
	Property, plant and equipment, net		$	310,163		$	309,233

NET_INCOME_PER_LIMITED_PARTNER1

NET INCOME PER LIMITED PARTNER UNIT (Tables)	3 Months Ended
	Mar. 31, 2015
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 (loss) per common unit (in thousands, except per unit data):
		Three Months ended
		March 31,
		2014			2015
	Net income	3,892			1,579
	General partner interest in net income	93			103
	Preferred interest in net income	5,391			5,391
	Loss available to limited partners	$	(1,592	)	$	(3,915	)
	Basic and diluted weighted average number of units:
	Common units	22,900			32,894
	Restricted and phantom units	526			562
	Basic and diluted net loss per common unit	$	(0.07	)	$	(0.12	)

LONGTERM_INCENTIVE_PLAN_Tables

LONG-TERM INCENTIVE PLAN (Tables)	3 Months Ended
	Mar. 31, 2015
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, 2014	1,020,264	$	7.46
	Granted	266,076	7.74
	Vested	222,800	6.76
	Forfeited	14,765	8.96
	Nonvested at March 31, 2015	1,048,775	$	7.66

FAIR_VALUE_MEASUREMENTS_Fair_V

FAIR VALUE MEASUREMENTS Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2015
Fair Value Measurements [Abstract]
Fair Value, by Balance Sheet Grouping [Table Text Block]	The Partnership’s recurring financial assets and liabilities subject to fair value measurements and the necessary disclosures are as follows (in thousands):
		Fair Value Measurements as of December 31, 2014
	Description	Total		Quoted Prices		Significant		Significant
				in Active		Other		Unobservable
				Markets for		Observable		Inputs
				Identical Assets		Inputs		(Level 3)
				(Level 1)		(Level 2)
	Liabilities:
	Interest rate swap liabilities	$	2,634	$	—	$	2,634	$	—
	Total	$	2,634	$	—	$	2,634	$	—
		Fair Value Measurements as of March 31, 2015
	Description	Total		Quoted Prices		Significant		Significant
				in Active		Other		Unobservable
				Markets for		Observable		Inputs
				Identical Assets		Inputs		(Level 3)
				(Level 1)		(Level 2)
	Liabilities:
	Interest rate swap liabilities	$	4,440	$	—	$	4,440	$	—
	Total	$	4,440	$	—	$	4,440	$	—

OPERATING_SEGMENTS_Tables

OPERATING SEGMENTS (Tables)	3 Months Ended
	Mar. 31, 2015
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	The following table reflects certain financial data for each segment for the periods indicated (in thousands):
			Three Months ended
			March 31,
			2014			2015
	Crude Oil Terminalling and Storage Services
	Service revenue
	Third party revenue		$	2,841		$	2,553
	Related party revenue		4,515			3,077
	Total revenue for reportable segments		7,356			5,630
	Operating expense (excluding depreciation and amortization)		970			1,561
	Operating margin (excluding depreciation and amortization)		6,386			4,069
	Total assets (end of period)		$	67,436		$	68,859
	Crude Oil Pipeline Services
	Service revenue
	Third party revenue		$	3,099		$	4,275
	Related party revenue		1,887			2,383
	Total revenue for reportable segments		4,986			6,658
	Operating expense (excluding depreciation and amortization)		4,381			3,909
	Operating margin (excluding depreciation and amortization)		605			2,749
	Total assets (end of period)		$	164,902		$	184,061
	Crude Oil Trucking and Producer Field Services
	Service revenue
	Third party revenue		$	13,850		$	10,682
	Related party revenue		5,547			4,621
	Total revenue for reportable segments		19,397			15,303
	Operating expense (excluding depreciation and amortization)		16,980			14,118
	Operating margin (excluding depreciation and amortization)		2,417			1,185
	Total assets (end of period)		$	24,877		$	18,002
	Asphalt  Services
	Service revenue
	Third party revenue		$	14,446		$	14,613
	Related party revenue		257			152
	Total revenue for reportable segments		14,703			14,765
	Operating expense (excluding depreciation and amortization)		6,852			6,152
	Operating margin (excluding depreciation and amortization)		7,851			8,613
	Total assets (end of period)		$	97,742		$	90,979
	Total operating margin (excluding depreciation and amortization)(1)		$	17,259		$	16,616
	____________________
	(1)The following table reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes (in thousands):
		Three Months ended March 31,
		2014			2015
	Operating margin (excluding depreciation and amortization)	$	17,259		$	16,616
	Depreciation and amortization	(6,317		)	(6,646		)
	General and administrative expenses	(4,487		)	(4,977		)
	Asset impairment expense	—			—
	Gain on sale of assets	397			304
	Interest expense	(2,655		)	(4,283		)
	Equity earnings (loss) in unconsolidated affiliate	(204		)	656
	Income before income taxes	$	3,993		$	1,670

INCOME_TAXES_Tables

INCOME TAXES (Tables)	3 Months Ended
	Mar. 31, 2015
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 March 31, 2015 are presented below (dollars in thousands):
	Deferred tax assets
	Difference in bases of property, plant and equipment	$	933
	Deferred tax asset	933
	Less: valuation allowance	(933		)
	Net deferred tax asset	$	—

ORGANIZATION_AND_NATURE_OF_BUS1

ORGANIZATION AND NATURE OF BUSINESS (Narrative) (Details)	3 Months Ended
	Mar. 31, 2015
	Operating-segments
	States
ORGANIZATION AND NATURE OF BUSINESS [Abstract]
Number of states in which entity operates (in states)	22
Number of operating segments (in operating segments)	4

BASIS_OF_CONSOLIDATION_AND_PRE1

BASIS OF CONSOLIDATION AND PRESENTATION SemGroup Settlement (Details) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Nov. 19, 2014
Basis of Consolidation and Presentation [Abstract]
Number of Units Received from Claims Settlement		30,393
Number of Claims Settled	2
Fair Market Value of Units Received From Settlement		$2.50
Trading Securities, Realized Gain (Loss)	$2.30

PROPERTY_PLANT_AND_EQUIPMENT_D

PROPERTY, PLANT AND EQUIPMENT (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$507,833,000		$502,603,000
Accumulated Depreciation and Impairments, property plant and equipment	198,600,000		192,440,000
Property, plant and equipment, net	309,233,000		310,163,000
Depreciation	6,600,000	6,300,000
Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	19,287,000		18,292,000
Land improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	6,398,000		6,398,000
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	175,333,000		168,537,000
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	242,027,000		240,004,000
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	13,219,000		13,557,000
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	29,050,000		28,958,000
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	10,186,000		10,186,000
Construction-in-progress [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$12,333,000		$16,671,000

DEBT_Credit_Agreements_Details

DEBT (Credit Agreements) (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014	Jun. 28, 2013	1-May-15
Debt Instrument [Line Items]
Borrowings under credit facility	$25,000,000	$15,000,000
Repayments of Long-term Debt	17,000,000	7,000,000
Debt issuance costs, net	2,866,000		3,085,000
Debt Instrument, Interest Rate During Period	3.41%	3.44%
Amortization and write-off of debt issuance costs	200,000	200,000
Interest expense for long-term debt	1,900,000	2,400,000
Interest expense	4,283,000	2,655,000
Capitalized interest	100,000	100,000
Derivative, Notional Amount			200,000,000
Interest Expense, Other	600,000	0
Interest rate swaps liability	4,440,000		2,634,000
Blueknight General Partners G. P., L.L.C. [Member]
Debt Instrument [Line Items]
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%
Vitol or Charlesbank [Member]
Debt Instrument [Line Items]
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%
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Revolving credit facility amount				400,000,000
Maximum borrowing capacity including additional lenders	500,000,000
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	3.43
Consolidated interest coverage (as a ratio), actual	7.11
Debt issuance costs	0	0
Weighted average interest rate (as a percent)	3.41%
Revolving Credit Facility [Member] | Minimum [Member]
Debt Instrument [Line Items]
Unused capacity, commitment fee (as a percent)	0.38%
Debt Instrument Covenant, Issued Qualified Senior Notes	200,000,000
Revolving Credit Facility [Member] | Maximum [Member]
Debt Instrument [Line Items]
Unused capacity, commitment fee (as a percent)	0.50%
Revolving Credit Facility [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Revolver borrowings					231,000,000
Unused borrowing capacity					168,100,000
Revolving Credit Facility [Member] | Federal funds rate [Member]
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	0.50%
Revolving Credit Facility [Member] | Eurodollar rate [Member]
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	1.00%
Revolving Credit Facility [Member] | Applicable margin based on ABR [Member] | Minimum [Member]
Debt Instrument [Line Items]
Applicable margin interest rate increase (as a percent)	1.00%
Revolving Credit Facility [Member] | Applicable margin based on ABR [Member] | Maximum [Member]
Debt Instrument [Line Items]
Applicable margin interest rate increase (as a percent)	2.00%
Revolving Credit Facility [Member] | Applicable margin based on Eurodollar rate [Member] | Minimum [Member]
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	2.00%
Revolving Credit Facility [Member] | Applicable margin based on Eurodollar rate [Member] | Maximum [Member]
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	3.00%
Letter of Credit [Member] | Subsequent Event [Member]
Debt Instrument [Line Items]
Letters of credit outstanding, amount					900,000
Interest Rate Swap [Member]
Debt Instrument [Line Items]
Derivative, Notional Amount	100,000,000
Derivative, Fixed Interest Rate	1.45%
Interest Rate Swap Two [Member]
Debt Instrument [Line Items]
Derivative, Notional Amount	100,000,000
Derivative, Fixed Interest Rate	1.97%
Aggregate Principal Above Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument Covenant, Issued Qualified Senior Notes	200,000,000
Aggregate Principal Below Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), Maximum permitted	4.5
Minimum Acquisition Costs	10,000,000
Minimum Percent of Projected Capital Expenditures	50.00%
Minimum Capital Expenditure	15,000,000
Debt Instrument Covenant, Issued Qualified Senior Notes	$200,000,000
Provision Two, Applicable Period Two [Member] | Aggregate Principal Above Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), Maximum permitted	5
Provision Three, Applicable Period One [Member] | Aggregate Principal Below Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), Maximum permitted	5
Provision Two, Applicable Period One [Member] | Aggregate Principal Above Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), Maximum permitted	5.5
Provision Two, Applicable Period One [Member] | Aggregate Principal Below Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), Maximum permitted	5.5
Provision One, Applicable Period Three [Member] | Aggregate Principal Below Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), Maximum permitted	4.5
Provision One, Applicable Period Two [Member] | Aggregate Principal Below Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), Maximum permitted	4.75
Provision One, Applicable Period One [Member] | Aggregate Principal Above Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), Maximum permitted	5
Provision One, Applicable Period One [Member] | Aggregate Principal Below Threshold [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Consolidated total leverage (as a ratio), Maximum permitted	5

NET_INCOME_PER_LIMITED_PARTNER2

NET INCOME PER LIMITED PARTNER UNIT (Details) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Earnings Per Share [Abstract]
Net income	$1,579	$3,892
General partner interest in net income	103	93
Preferred interest in net income	5,391	5,391
Loss available to limited partners	($3,915)	($1,592)
Basic and diluted weighted average number of units:
Common units	32,894	22,900
Weighted Average Limited Partnership Units Outstanding, Diluted	32,894	22,900
Restricted and phantom units	562	526
Basic and diluted net loss per common unit	($0.12)	($0.07)
Diluted net income per common unit	($0.12)	($0.07)

PARTNERS_CAPITAL_AND_DISTRIBUT1

PARTNERS' CAPITAL AND DISTRIBUTIONS (Narrative) (Details) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2015
Distribution Made to Member or Limited Partner, Cash Distributions Declared	$4.60
Phantom Share Units and Restricted Units [Member]
Distribution Made to Member or Limited Partner, Cash Distributions Declared	0.1
Series A Preferred Unitholders [Member]
Distribution Made to Member or Limited Partner, Distributions Declared (in dollars per unit)	$0.18
Distribution Made to Member or Limited Partner, Cash Distributions Declared	5.4
Limited Partner [Member]
Distribution Made to Member or Limited Partner, Distributions Declared (in dollars per unit)	$0.14
Distribution Made to Member or Limited Partner, Distributions Declared, Percentage Increase Over Previous Quarter Distribution	2.20%
Distribution Made to Member or Limited Partner, Cash Distributions Declared	5
General Partner Interest [Member]
Distribution Made to Member or Limited Partner, Cash Distributions Declared	$0.30

PARTNERS_CAPITAL_AND_DISTRIBUT2

PARTNERS' CAPITAL AND DISTRIBUTIONS Issuances Narrative (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Sep. 22, 2014
Capital Unit [Line Items]
Limited Partners' Capital Account, Units Issued		9,775,000
Sale of Stock, Price Per Share		$7.61
Limited Partners' Offering Costs	$3.20
Limited Partner [Member]
Capital Unit [Line Items]
Proceeds from Issuance of Common Limited Partners Units	$71.20

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Related Party Transaction [Line Items]
Related party revenue	$10,233,000	$12,206,000
Receivables from related parties	2,765,000		2,316,000
Vitol [Member]
Related Party Transaction [Line Items]
Related party revenue	9,900,000	12,000,000
Receivables from related parties	2,700,000		2,300,000
Due to Related Parties	900,000		1,000,000
Advantage Pipeline, L.L.C. [Member]
Related Party Transaction [Line Items]
Related party revenue	300,000	200,000
Receivables from related parties	$100,000		$100,000

LONGTERM_INCENTIVE_PLAN_Detail

LONG-TERM INCENTIVE PLAN (Details) (USD $)	3 Months Ended			1 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Jun. 30, 2014	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2013	Sep. 30, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Apr. 28, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity-based incentive compensation expense (in dollars)	$11,000	($53,000)
Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Additional Shares Authorized			1,500,000
Number of units authorized	4,100,000			4,100,000							2,600,000
Number of Units [Roll Forward]
Number of Units, Nonvested, Beginning balance	1,020,264
Number of Units, Granted	266,076
Number of Units, Vested	222,800
Number of Units, Forfeited	14,765
Number of Units, Nonvested, Ending balance	1,048,775			1,048,775
Weighted Average Grant Date Fair Value [Roll Forward]
Weighted Average Grant Date Fair Value, Nonvested, Beginning balance (in dollars per unit)	$7.46
Weighted Average Grant Date Fair Value, Granted (in dollars per unit)	$7.74
Weighted Average Grant Date Fair Value, Vested (in dollars per unit)	$6.76
Weighted Average Grant Date Fair Value, Forfeited (in dollars per unit)	$8.96
Weighted Average Grant Date Fair Value, Nonvested, Ending balance (in dollars per unit)	$7.66			$7.66
Plan [Member] | Phantom common units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Value of award grants (in dollars)				2,100,000	2,500,000	2,200,000
Unrecognized estimated compensation cost (in dollars)	3,800,000			3,800,000
Equity-based incentive compensation expense (in dollars)	500,000	500,000
Weighted Average Grant Date Fair Value [Roll Forward]
Weighted Average Grant Date Fair Value, Granted (in dollars per unit)				$7.74	$9.06	$8.75
Plan [Member] | Phantom common units [Member] | Chief Executive Officer [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period							5 years
Value of award grants (in dollars)							2,800,000
Unrecognized estimated compensation cost (in dollars)	1,400,000			1,400,000
Number of Units [Roll Forward]
Number of Units, Granted							500,000
Weighted Average Grant Date Fair Value [Roll Forward]
Weighted Average Grant Date Fair Value, Granted (in dollars per unit)							$5.62
Plan [Member] | Restricted common units [Member] | Independent Directors [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting rights percentage								33.00%	33.00%	33.00%
Value of award grants (in dollars)								$100,000	$100,000	$49,200
Number of Units [Roll Forward]
Number of Units, Granted								7,500	7,500	7,500
January 2016 Vesting [Member] | Plan [Member] | Phantom common units [Member]
Number of Units [Roll Forward]
Number of Units, Granted						251,106
January 2017 Vesting [Member] | Plan [Member] | Phantom common units [Member]
Number of Units [Roll Forward]
Number of Units, Granted					276,773
January 2018 Vesting [Member] | Plan [Member] | Phantom common units [Member]
Number of Units [Roll Forward]
Number of Units, Granted				266,076

EMPLOYEE_BENEFIT_PLAN_Details

EMPLOYEE BENEFIT PLAN (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Defined Contribution Pension [Member]
Defined Contribution Plans Disclosure [Line Items]
Employer discretionary contribution amount	$0.40	$0.40
Deferred Profit Sharing [Member]
Defined Contribution Plans Disclosure [Line Items]
Employer discretionary contribution amount	$0.20	$0.20

EMPLOYEE_BENEFIT_PLAN_EUPP_Det

EMPLOYEE BENEFIT PLAN EUPP (Details) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015
EUPP [Abstract]
Employee Stock Ownership Plan (ESOP), Shares in ESOP	1,000,000
Employee Stock Ownership Plan (ESOP), Compensation Expense	$0.10

FAIR_VALUE_MEASUREMENTS_Fair_V1

FAIR VALUE MEASUREMENTS Fair Value Measurements (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest rate swaps liability	$4,440	$2,634
Total	4,440	2,634
Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest rate swaps liability	0	0
Total	0	0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest rate swaps liability	4,440	2,634
Total	4,440	2,634
Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Interest rate swaps liability	0	0
Total	$0	$0

OPERATING_SEGMENTS_Details

OPERATING SEGMENTS (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014		Dec. 31, 2014
	Operating-segments
Segment Reporting Information [Line Items]
Number of operating segments (in operating segments)	4
Service revenue
Third party revenue	$32,123		$34,236
Related party revenue	10,233		12,206
Total revenue for reportable segments	42,356		46,442
Operating margin (excluding depreciation and amortization)	16,616	[1]	17,259	[1]
Total assets (end of period)	361,901				364,395
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes
Operating margin (excluding depreciation and amortization)	16,616	[1]	17,259	[1]
Depreciation and amortization on continuing operations	-6,646		-6,317
General and administrative expenses	-4,977		-4,487
Assets Impairment Charges on Continuing Operations	0		0
Gain on sale of assets	304		397
Interest expense	-4,283		-2,655
Equity (earnings) loss in unconsolidated affiliate	656		-204
Income from continuing operations before income taxes	1,670		3,993
Crude Oil Terminalling and Storage Services [Member]
Service revenue
Third party revenue	2,553		2,841
Related party revenue	3,077		4,515
Total revenue for reportable segments	5,630		7,356
Operating expenses (excluding depreciation and amortization)	1,561		970
Operating margin (excluding depreciation and amortization)	4,069		6,386
Total assets (end of period)	68,859		67,436
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes
Operating margin (excluding depreciation and amortization)	4,069		6,386
Crude Oil Pipeline Services [Member]
Segment Reporting Information [Line Items]
Number of pipelines systems owned and operated (in pipeline systems)	3
Service revenue
Third party revenue	4,275		3,099
Related party revenue	2,383		1,887
Total revenue for reportable segments	6,658		4,986
Operating expenses (excluding depreciation and amortization)	3,909		4,381
Operating margin (excluding depreciation and amortization)	2,749		605
Total assets (end of period)	184,061		164,902
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes
Operating margin (excluding depreciation and amortization)	2,749		605
Crude Oil Trucking and Producer Field Services [Member]
Service revenue
Third party revenue	10,682		13,850
Related party revenue	4,621		5,547
Total revenue for reportable segments	15,303		19,397
Operating expenses (excluding depreciation and amortization)	14,118		16,980
Operating margin (excluding depreciation and amortization)	1,185		2,417
Total assets (end of period)	18,002		24,877
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes
Operating margin (excluding depreciation and amortization)	1,185		2,417
Asphalt Services [Member]
Segment Reporting Information [Line Items]
Number of terminalling and storage facilities providing asphalt product and residual fuel terminalling storage and blending services (in terminalling and storage facilities)	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
Service revenue
Third party revenue	14,613		14,446
Related party revenue	152		257
Total revenue for reportable segments	14,765		14,703
Operating expenses (excluding depreciation and amortization)	6,152		6,852
Operating margin (excluding depreciation and amortization)	8,613		7,851
Total assets (end of period)	90,979		97,742
Reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes
Operating margin (excluding depreciation and amortization)	$8,613		$7,851
[1]	The following table reconciles segment operating margin (excluding depreciation and amortization) to income before income taxes (in thousands): Three Months ended March 31, 2014 2015Operating margin (excluding depreciation and amortization)$17,259 $16,616Depreciation and amortization(6,317) (6,646)General and administrative expenses(4,487) (4,977)Asset impairment expense— —Gain on sale of assets397 304Interest expense(2,655) (4,283)Equity earnings (loss) in unconsolidated affiliate(204) 656Income before income taxes$3,993 $1,670

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Narrative) (Details) (Pending Litigation [Member], Physical Management and Control of Crude Oil [Member], USD $)	Jun. 10, 2013	Feb. 06, 2012
	bbl	bbl
Loss Contingencies [Line Items]
Judgement seeking immediate return of crude cil Linefill belonging to company (in BOE)		140,000
Gain Contingency, Partnership's Shortage Found by Special Master	148,000
Gain Contingency, Defendent's Overage Found By Special Master	130,000
Minimum [Member]
Loss Contingencies [Line Items]
Gain contingency, unrecorded amount		75,000

INCOME_TAXES_Details

INCOME TAXES (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015
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	$933
Deferred tax asset	933
Less: valuation allowance	-933
Net deferred tax asset	$0