Martin Midstream Partners (MMLP) 10-Q 29 Jul 15 2015 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2015	Jul. 29, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	MARTIN MIDSTREAM PARTNERS LP
Entity Central Index Key	1,176,334
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		35,456,862

CONSOLIDATED AND CONDENSED BALA

CONSOLIDATED AND CONDENSED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Assets
Cash	$ 24	$ 42
Accounts and other receivables, less allowance for doubtful accounts of $352 and $1,620, respectively	75,175	134,173
Product exchange receivables	294	3,046
Inventories	76,563	88,718
Due from affiliates	10,712	14,512
Other current assets	7,646	6,772
Assets held for sale	0	40,488
Total current assets	170,414	287,751
Property, plant and equipment, at cost	1,374,805	1,343,674
Accumulated depreciation	(377,652)	(345,397)
Property, plant and equipment, net	997,153	998,277
Goodwill	23,802	23,802
Investment in unconsolidated entities	133,495	134,506
Note receivable - Martin Energy Trading LLC	15,000	15,000
Other assets, net	71,646	81,465
Total assets	1,411,510	1,540,801
Liabilities and Partners’ Capital
Trade and other accounts payable	81,950	125,332
Product exchange payables	12,704	10,396
Due to affiliates	4,754	4,872
Income taxes payable	736	1,174
Other accrued liabilities	20,344	21,801
Total current liabilities	120,488	163,575
Long-term debt, net	840,159	888,887
Other long-term obligations	2,274	2,668
Total liabilities	$ 962,921	$ 1,055,130
Commitments and contingencies
Partners’ capital	$ 448,589	$ 485,671
Total liabilities and partners' capital	$ 1,411,510	$ 1,540,801

CONSOLIDATED AND CONDENSED BAL3

CONSOLIDATED AND CONDENSED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Accounts and other receivables, allowance for doubtful accounts	$ 352	$ 1,620

CONSOLIDATED AND CONDENSED STAT

CONSOLIDATED AND CONDENSED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues:
Terminalling and storage	[1]	$ 33,453	$ 34,167	$ 67,250	$ 65,968
Marine transportation	[1]	20,343	22,084	40,979	45,198
Natural gas services		16,564	0	33,051	0
Sulfur services		3,090	3,038	6,180	6,075
Product sales:
Natural gas services	[1]	97,786	232,986	244,089	554,400
Sulfur services	[1]	45,284	59,543	95,331	110,713
Terminalling and storage	[1]	34,579	51,443	69,572	105,716
Total product sales	[1]	177,649	343,972	408,992	770,829
Total revenues		251,099	403,261	556,452	888,070
Cost of products sold: (excluding depreciation and amortization)
Natural gas services	[1]	88,623	223,314	226,330	532,733
Sulfur services	[1]	33,518	45,315	69,541	83,168
Terminalling and storage	[1]	29,658	46,806	59,740	94,835
Total cost of products sold (excluding depreciation and amortization)		151,799	315,435	355,611	710,736
Expenses:
Operating expenses	[1]	47,783	47,111	93,089	90,011
Selling, general and administrative	[1]	9,035	8,605	17,841	17,061
Depreciation and amortization		22,685	14,212	45,402	27,820
Total costs and expenses		231,302	385,363	511,943	845,628
Other operating income (loss)		(167)	99	(177)	54
Operating income		19,630	17,997	44,332	42,496
Other income (expense):
Equity in earnings of unconsolidated entities		1,649	1,938	3,389	1,642
Interest expense, net		(9,925)	(11,441)	(20,471)	(22,892)
Debt prepayment premium		0	(7,767)	0	(7,767)
Other, net		(79)	(49)	358	(117)
Total other expense		(8,355)	(17,319)	(16,724)	(29,134)
Net income before taxes		11,275	678	27,608	13,362
Income tax expense		(314)	(354)	(614)	(654)
Income from continuing operations		10,961	324	26,994	12,708
Income (loss) from discontinued operations, net of income taxes		0	(1,292)	1,215	(1,881)
Net income (loss)		10,961	(968)	28,209	10,827
Less general partner's interest in net (income) loss		(4,113)	19	(8,351)	(217)
Less (income) loss allocable to unvested restricted units		(44)	3	(111)	(29)
Limited partners' interest in net income (loss)		$ 6,804	$ (946)	$ 19,747	$ 10,581
[1]	*Related Party Transactions Shown Below*Related Party Transactions Included Above Three Months Ended Six Months Ended June 30, June 30, 2015 2014 2015 2014Revenues:* Terminalling and storage$23,061 $18,743 $43,535 $36,753Marine transportation6,622 6,415 13,367 12,264Product Sales1,759 3,709 3,348 5,601Costs and expenses:* Cost of products sold: (excluding depreciation and amortization) Natural gas services6,810 10,808 13,728 19,261Sulfur services3,618 4,452 7,242 9,317Terminalling and storage5,632 6,553 11,034 16,397Expenses: Operating expenses18,915 19,248 39,315 37,487Selling, general and administrative5,849 5,489 11,843 10,873See accompanying notes to consolidated and condensed financial statements.

CONSOLIDATED AND CONDENSED STA5

CONSOLIDATED AND CONDENSED STATEMENTS OF OPERATIONS (Allocation of Net Income) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Limited partner interest:
Continuing operations	$ 6,804	$ 316	$ 18,896	$ 12,419
Discontinued operations	0	(1,262)	851	(1,838)
Limited partners' interest in net income (loss)	6,804	(946)	19,747	10,581
General partner interest:
Continuing operations	4,113	8	7,992	255
Discontinued operations	0	(27)	359	(38)
General partners' interest in net income (loss)	$ 4,113	$ (19)	$ 8,351	$ 217
Basic:
Continuing operations	$ 0.19	$ 0.01	$ 0.54	$ 0.45
Discontinued operations	0	(0.04)	0.02	(0.07)
Net income (loss) per unit attributable to limited partners, basic	$ 0.19	$ (0.03)	$ 0.56	$ 0.38
Weighted average limited partner units - basic	35,307,638	28,923,513	35,315,989	27,757,304
Diluted:
Continuing operations	$ 0.19	$ 0.01	$ 0.54	$ 0.45
Discontinued operations	0	(0.04)	0.02	(0.07)
Net income (loss) per unit attributable to limited partners, diluted	$ 0.19	$ (0.03)	$ 0.56	$ 0.38
Weighted average limited partner units - diluted	35,376,000	28,958,000	35,372,000	27,791,000

CONSOLIDATED AND CONDENSED STA6

CONSOLIDATED AND CONDENSED STATEMENTS OF OPERATIONS (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues:
Terminalling and storage	$ 23,061	$ 18,743	$ 43,535	$ 36,753
Marine transportation	6,622	6,415	13,367	12,264
Product Sales	1,759	3,709	3,348	5,601
Cost of products sold: (excluding depreciation and amortization)
Natural gas services	6,810	10,808	13,728	19,261
Sulfur services	3,618	4,452	7,242	9,317
Terminalling and storage			11,034	16,397
Expenses:
Operating expenses	18,915	19,248	39,315	37,487
Selling, general and administrative	$ 5,849	$ 5,489	$ 11,843	$ 10,873

CONSOLIDATED AND CONDENSED STA7

CONSOLIDATED AND CONDENSED STATEMENTS OF CAPITAL - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning Balance	$ 485,671	$ 260,417
Net income	28,209	10,827
Issuance of common units	(269)	160,514
General partner contribution	55	3,407
Cash distributions	(66,577)	(43,145)
Unit-based compensation	750	387
Excess purchase price over carrying value of acquired assets		(5,397)
Purchase of treasury units		(277)
Reimbursement of excess purchase price over carrying value of acquired assets	750
Ending Balance	$ 448,589	$ 386,733
Limited Partner [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning Balance (in units)	35,365,912	26,625,026
Beginning Balance	$ 470,943	$ 254,028
Net income	19,858	$ 10,610
Issuance of common units (in units)		4,017,156
Issuance of common units	$ (269)	$ 160,514
Issuance of restricted units (in units)	91,950	6,900
Forfeiture of restricted units (in units)	(1,000)	(3,250)
Cash distributions	$ (57,612)	$ (42,192)
Unit-based compensation	750	387
Excess purchase price over carrying value of acquired assets		$ (5,397)
Purchase of treasury units (in units)		(6,400)
Purchase of treasury units		$ (277)
Reimbursement of excess purchase price over carrying value of acquired assets	$ 750
Ending Balance (in units)	35,456,862	30,639,432
Ending Balance	$ 434,420	$ 377,673
General Partner [Member]
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning Balance	14,728	6,389
Net income	8,351	217
General partner contribution	55	3,407
Cash distributions	(8,965)	(953)
Ending Balance	$ 14,169	$ 9,060

CONSOLIDATED AND CONDENSED STA8

CONSOLIDATED AND CONDENSED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Cash flows from operating activities:
Net income	$ 28,209	$ 10,827
Less: (Income) loss from discontinued operations, net of income taxes	(1,215)	1,881
Income from continuing operations	26,994	12,708
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	45,402	27,820
Amortization of deferred debt issuance costs	1,742	4,588
Amortization of debt discount	0	1,305
Amortization of premium on notes payable	(164)	(82)
Loss (gain) on sale of property, plant and equipment	165	(54)
Equity in earnings of unconsolidated entities	(3,389)	(1,642)
Non-cash mark-to-market on derivatives	0	547
Unit-based compensation	750	387
Preferred dividends on MET investment	0	1,116
Return on investment	4,400	0
Change in current assets and liabilities, excluding effects of acquisitions and dispositions:
Accounts and other receivables	58,689	16,305
Product exchange receivables	2,752	(1,437)
Inventories	12,204	(15,648)
Due from affiliates	3,800	(9,816)
Other current assets	(711)	(1,430)
Trade and other accounts payable	(46,283)	(23,460)
Product exchange payables	2,308	12,483
Due to affiliates	(118)	3,959
Income taxes payable	(438)	(386)
Other accrued liabilities	(959)	(1,449)
Change in other non-current assets and liabilities	(1,709)	587
Net cash provided by continuing operating activities	105,435	25,307
Net cash used in discontinued operating activities	(1,351)	(4,358)
Net cash provided by operating activities	104,084	20,949
Cash flows from investing activities:
Payments for property, plant and equipment	(28,027)	(41,237)
Acquisitions, less cash acquired	0	(1,991)
Payments for plant turnaround costs	(1,754)	(3,910)
Proceeds from sale of property, plant and equipment	776	702
Proceeds from involuntary conversion of property, plant and equipment	0	2,475
Investment in unconsolidated entities	0	(134,413)
Return of investments from unconsolidated entities	0	2,425
Contributions to unconsolidated entities	0	(3,070)
Net cash used in continuing investing activities	(29,005)	(179,019)
Net cash provided by discontinued investing activities	41,250	0
Net cash provided by (used in) investing activities	12,245	(179,019)
Cash flows from financing activities:
Payments of long-term debt	(151,000)	(885,000)
Proceeds from long-term debt	101,000	917,250
Proceeds from issuance of common units, net of issuance related costs	(269)	160,514
General partner contribution	55	3,407
Purchase of treasury units	0	(277)
Payment of debt issuance costs	(306)	(3,120)
Excess purchase price over carrying value of acquired assets	0	(5,397)
Reimbursement of excess purchase price over carrying value of acquired assets	750	0
Cash distributions paid	(66,577)	(43,145)
Net cash provided by (used in) financing activities	(116,347)	144,232
Net decrease in cash	(18)	(13,838)
Cash at beginning of period	42	16,542
Cash at end of period	24	2,704
Non-cash additions to property, plant and equipment	$ 3,767	$ 3,111

General

General	6 Months Ended
	Jun. 30, 2015
Accounting Policies [Abstract]
General	General Martin Midstream Partners L.P. (the "Partnership") is a publicly traded limited partnership with a diverse set of operations focused primarily in the United States ("U.S.") Gulf Coast region. Its four primary business lines include: terminalling and storage services for petroleum products and by-products including the refining of naphthenic crude oil, blending and packaging of finished lubricants; natural gas services, including liquids transportation and distribution services and natural gas storage; sulfur and sulfur-based products processing, manufacturing, marketing and distribution; and marine transportation services for petroleum products and by-products. The Partnership’s unaudited consolidated and condensed financial statements have been prepared in accordance with the requirements of Form 10-Q and United States Generally Accepted Accounting Principles ("U.S. GAAP") for interim financial reporting. Accordingly, these financial statements have been condensed and do not include all of the information and footnotes required by U.S. GAAP for annual audited financial statements of the type contained in the Partnership’s annual reports on Form 10-K. In the opinion of the management of the Partnership’s general partner, all adjustments and elimination of significant intercompany balances necessary for a fair presentation of the Partnership’s financial position, results of operations, and cash flows for the periods shown have been made. All such adjustments are of a normal recurring nature. Results for such interim periods are not necessarily indicative of the results of operations for the full year. These financial statements should be read in conjunction with the Partnership’s audited 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 2, 2015, as amended by Amendment No. 1 on Form 10-K/A for the year ended December 31, 2014 filed on March 5, 2015. Management has made a number of estimates and assumptions relating to the reporting of assets and liabilities and the disclosure of contingent assets and liabilities to prepare these consolidated and condensed financial statements in conformity with U.S. GAAP. Actual results could differ from those estimates.

New Accounting Pronouncements

New Accounting Pronouncements	6 Months Ended
	Jun. 30, 2015
Accounting Changes and Error Corrections [Abstract]
New Accounting Pronouncements	New Accounting Pronouncements In April 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2015-06, Earnings Per Share (Topic 260): Effects on Historical Earnings per Unit of Master Limited Partnership Dropdown Transactions, which requires a master limited partnership ("MLP") to allocate earnings (losses) of a transferred business entirely to the general partner when computing earnings per unit ("EPU") for periods before the dropdown transaction occurred. The EPU for limited partners that was previously reported would not change as a result of the dropdown transaction. The ASU also requires an MLP to disclose the effects of the dropdown transaction on EPU for the periods before and after the dropdown transaction occurred. This ASU is effective for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. The ASU requires retrospective application and early adoption is permitted. The Partnership is evaluating the effect that ASU 2015-06 will have on its consolidated and condensed financial statements and related disclosures. In April 2015, the FASB issued ASU No. 2015-03, Interest-Imputation of Interest , which simplifies presentation of debt issuance costs. The amended guidance requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Early application is permitted under the retrospective transition method. The Partnership has elected to adopt this guidance effective January 1, 2015. The standard only affects presentation on the Partnership's Consolidated and Condensed Balance Sheets and does not affect any of the Partnership's other financial statements. The amount of debt issuance costs, net of accumulated amortization, from the December 31, 2014 audited balance sheet that were reclassified and shown as a reduction of the related long-term debt balances is $13,118 . In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers , which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The ASU will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective. The new standard is effective for the Partnership on January 1, 2018. The standard permits the use of either the retrospective or cumulative effect transition method. The Partnership is evaluating the effect that ASU 2014-09 will have on its consolidated and condensed financial statements and related disclosures. The Partnership has not yet selected a transition method nor has it determined the effect of the standard on its ongoing financial reporting. In April 2014, the FASB issued No. ASU 2014-08, Presentation of Financial Statements and Property, Plant, and Equipment: Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. The ASU changes the requirements for reporting discontinued operations. A discontinued operation may include a component of an entity or a group of components of an entity, or a business. A disposal of a component of an entity or a group of components of an entity is required to be reported in discontinued operations if the disposal represents a strategic shift that has (or will have) a major effect on an entity’s operations and financial results. Examples include a disposal of a major geographic area, a major line of business or a major equity method investment. Additionally, the update requires expanded disclosures about discontinued operations that will provide financial statement users with more information about the assets, liabilities, income and expenses of discontinued operations. This update has been adopted prospectively for the Partnership's fiscal year beginning January 1, 2015. The adoption did not have a material impact on the Partnership's financial condition, results of operations or cash flows.

Acquisitions

Acquisitions	6 Months Ended
	Jun. 30, 2015
Business Combinations [Abstract]
Acquisitions	Acquisitions Cardinal Gas Storage Partners LLC On August 29, 2014, the Partnership acquired from Energy Capital Partners ("ECP") all of ECP’s approximate 57.8% Category A membership interest in Cardinal Gas Storage Partners LLC ("Cardinal") for cash consideration of approximately $120,973 , subject to certain post-closing adjustments. Prior to the acquisition, the Partnership owned an approximate 42.2% Category A membership interest in Cardinal. Based on the application of purchase accounting, the Partnership reduced the carrying value of its existing investment in Cardinal at the acquisition date by $30,102 , which was recognized in the Partnership's Consolidated and Condensed Statements of Operations in the third quarter of 2014. Concurrent with the closing of the transaction, the Partnership retired all of the project level financing of various Cardinal subsidiaries. The Partnership funded the acquisition and repayment of the project financings with borrowings under its revolving credit facility and the use of restricted cash acquired. The total purchase price is as follows: Cash payment for 57.8% interest in Cardinal $ 120,973 Fair value of the Partnership's previously owned 42.2% interest in Cardinal 87,613 Total $ 208,586 Assets acquired and liabilities assumed were recorded in the Natural Gas Services segment at fair value in the following purchase price allocation which was finalized in the fourth quarter of 2014: Restricted cash $ 17,566 Other current assets 9,385 Property, plant and equipment 390,895 Intangible and other assets 80,135 Project level finance debt (282,087 ) Other current liabilities (6,713 ) Other non-current liabilities (595 ) Total $ 208,586 Intangible assets consist of above-market gas storage customer contracts which are amortized based upon the terms of the individual contracts. At the acquisition date, the weighted average life of these contracts, based upon contracted volumes, is 5.1 years . The Partnership’s results of operations from the Cardinal acquisition include revenues of $16,181 and net income of $3,062 for the three months ended June 30, 2015 and revenues of $32,668 and net income of $6,090 for the six months ended June 30, 2015 . Natural Gas Liquids ("NGL") Storage Assets On May 31, 2014, the Partnership acquired certain NGL storage assets from a subsidiary of Martin Resource Management Corporation ("Martin Resource Management") for $7,388 . This acquisition is considered a transfer of net assets between entities under common control. The acquisition of these assets was recorded at the historical carrying value of the assets at the acquisition date. The Partnership recorded the purchase in the following allocation: Property, plant and equipment $ 2,453 Current liabilities (13 ) $ 2,440 The excess of the purchase price over the carrying value of the assets of $4,948 was recorded as an adjustment to "Partners' capital." This transaction was funded with borrowings under the Partnership's revolving credit facility. As no individual line item of the historical financial statements of the assets was in excess of 3% of the Partnership's relative financial statement captions, the Partnership elected not to retrospectively recast the historical financial information of these assets. West Texas LPG Pipeline Limited Partnership On May 14, 2014, the Partnership acquired from a subsidiary of Atlas Pipeline Partners L.P. ("Atlas"), all of the outstanding membership interests in Atlas Pipeline NGL Holdings, LLC and Atlas Pipeline NGL Holdings II, LLC (collectively, "Atlas Holdings") for cash of approximately $134,400 . The purchase price was subsequently reduced $501 due to a post-closing working capital adjustment. This transaction was recorded in "Investments in unconsolidated entities" in the Partnership's Consolidated and Condensed Balance Sheet through a purchase price allocation. Atlas Holdings owned a 19.8% limited partnership interest and a 0.2% general partnership interest in West Texas LPG Pipeline L.P. ("WTLPG"). At the time of the purchase, WTLPG was operated by Chevron Pipe Line Company. The 80.0% interest was subsequently sold to ONEOK Partners, L.P. who assumed operational responsibility. WTLPG owns an approximate 2,300 mile common-carrier pipeline system that transports NGLs from New Mexico and Texas to Mont Belvieu, Texas for fractionation. This acquisition will enable the Partnership to participate in the transportation of the growing NGL production of West Texas and other basins along the WTLPG pipeline route. This acquisition of the WTLPG business complements the Partnership's existing East Texas NGL pipeline that delivers Y-grade NGLs from East Texas production areas into Beaumont, Texas on a smaller scale. This transaction was funded with borrowings under the Partnership's revolving credit facility. Pro Forma Financial Information for Cardinal and WTLPG The following pro forma consolidated results of operations for the three and six months ended June 30, 2014 have been prepared as if the acquisition of Cardinal and WTLPG occurred at the beginning of fiscal 2014: Three Months Ended June 30, 2014 Six Months Ended June 30, 2014 Revenue: As reported $ 403,261 $ 888,070 Pro forma $ 420,175 $ 923,413 Net income (loss) from continuing operations attributable to limited partners: As reported $ 316 $ 12,419 Pro forma $ (7,098 ) $ (4,216 ) Net loss from discontinued operations attributable to limited partners: As reported $ (1,262 ) $ (1,838 ) Pro forma $ (1,262 ) $ (1,838 ) Net income (loss) from continuing operations per unit attributable to limited partners - basic: As reported $ 0.01 $ 0.45 Pro forma $ (0.25 ) $ (0.15 ) Net loss from discontinued operations per unit attributable to limited partners - basic: As reported $ (0.04 ) $ (0.07 ) Pro forma $ (0.04 ) $ (0.07 ) Net income (loss) from continuing operations per unit attributable to limited partners - diluted: As reported $ 0.01 $ 0.45 Pro forma $ (0.25 ) $ (0.15 ) Net loss from discontinued operations per unit attributable to limited partners - diluted: As reported $ (0.04 ) $ (0.07 ) Pro forma $ (0.04 ) $ (0.07 )

Discontinued operations and div

Discontinued operations and divestitures	6 Months Ended
	Jun. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
Discontinued operations and divestitures	Discontinued operations and divestitures Floating Storage Assets. On February 12, 2015, the Partnership sold all six of its 16,101 barrel liquefied petroleum gas ("LPG") pressure barges, collectively referred to as the "Floating Storage Assets." These assets were acquired on February 28, 2013. On December 19, 2014, the Partnership made the decision to dispose of the Floating Storage Assets. As a result, the Partnership classified the Floating Storage Assets as held for sale at December 31, 2014 and has presented the results of operations and cash flows of the Floating Storage Assets as discontinued operations for the three and six months ended June 30, 2015 and 2014. The Partnership has retrospectively adjusted its prior period consolidated financial statements to comparably classify the amounts related to the operations and cash flows of the Floating Storage Assets as discontinued operations. The Floating Storage Assets were presented as discontinued operations under the guidance prior to the Partnership's adoption of ASU 2014-08 related to discontinued operations. The adoption of the amended guidance was effective for the Partnership January 1, 2015. The Floating Storage Assets’ operating results, which are included in income from discontinued operations, were as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Total revenues from third parties 1 $ — $ 15,683 $ 791 $ 33,175 Total costs and expenses and other, net, excluding depreciation and amortization — 16,592 1,038 34,290 Depreciation and amortization — 383 — 766 Other operating income 2 — — 1,462 — Income (loss) from discontinued operations before income taxes — (1,292 ) 1,215 (1,881 ) Income tax expense — — — — Income (loss) from discontinued operations, net of income taxes $ — $ (1,292 ) $ 1,215 $ (1,881 ) 1 Total revenues from third parties excludes intercompany revenues of $0 and $0 for the three months ended June 30, 2015 and 2014, respectively. Total revenues from third parties excludes intercompany revenues of $0 and $5,273 for the six months ended June 30, 2015 and 2014, respectively. 2 Other operating income represents the gain on the disposition of the Floating Storage Assets.

Inventories

Inventories	6 Months Ended
	Jun. 30, 2015
Inventory Disclosure [Abstract]
Inventories	Inventories Components of inventories at June 30, 2015 and December 31, 2014 were as follows: June 30, 2015 December 31, 2014 Natural gas liquids $ 22,658 $ 27,820 Sulfur 11,817 12,231 Sulfur based products 13,981 16,280 Lubricants 24,923 29,096 Other 3,184 3,291 $ 76,563 $ 88,718

Investments in Unconsolidated E

Investments in Unconsolidated Entities and Joint Ventures	6 Months Ended
	Jun. 30, 2015
Equity Method Investments and Joint Ventures [Abstract]
Investments in Unconsolidated Entities and Joint Ventures	Investments in Unconsolidated Entities and Joint Ventures On August 29, 2014, the Partnership acquired ECP’s approximate 57.8% Category A membership interest in Cardinal. Prior to the acquisition, the Partnership owned an approximate 42.2% Category A membership interest in Cardinal which was accounted for by the equity method. See Note 3 for discussion of the acquisition of the remaining membership interests. On May 14, 2014, the Partnership acquired from a subsidiary of Atlas, all of the outstanding membership interests in Atlas Holdings for cash of approximately $134,400 at closing. The purchase price was subsequently reduced $501 due to a post-closing working capital adjustment. Atlas Holdings owned a 19.8% limited partnership interest and a 0.2% general partnership interest in WTLPG. At the time of the purchase, WTLPG was operated by Chevron Pipe Line Company. The 80% interest was subsequently sold to ONEOK Partners, L.P. who assumed operational responsibility. WTLPG owns an approximate 2,300 mile common-carrier pipeline system that transports NGLs from New Mexico and Texas to Mont Belvieu, Texas for fractionation. The Partnership recognizes its 20% interest in WTLPG as "Investment in unconsolidated entities" on its Consolidated and Condensed Balance Sheets. The Partnership accounts for its ownership interest in WTLPG under the equity method of accounting, with recognition of its ownership interest in the income of WTLPG as "Equity in earnings of unconsolidated entities" on its Consolidated and Condensed Statements of Operations. During March 2013, the Partnership acquired 100% of the preferred interests in Martin Energy Trading LLC ("MET"), a subsidiary of Martin Resource Management, for $15,000 . On August 31, 2014, MET converted its preferred equity to subordinated debt. The resulting $15,000 note receivable from MET bears an annual interest rate of 15% and matures August 31, 2026. MET may prepay any or all of the note balance on or after September 1, 2016. See Note 12. The following tables summarize the components of the investment in unconsolidated entities on the Partnership’s Consolidated and Condensed Balance Sheets and the components of equity in earnings of unconsolidated entities included in the Partnership’s Consolidated and Condensed Statements of Operations: June 30, 2015 December 31, 2014 WTLPG $ 133,495 $ 134,506 Total investment in unconsolidated entities $ 133,495 $ 134,506 Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Equity in earnings of WTLPG $ 1,649 $ 769 $ 3,389 $ 769 Equity in earnings (loss) of Cardinal — 608 — (243 ) Equity in earnings of MET — 561 — 1,116 Equity in earnings of unconsolidated entities $ 1,649 $ 1,938 $ 3,389 $ 1,642 Selected financial information for significant unconsolidated equity-method investees is as follows: As of June 30, Three Months Ended June 30, Six Months Ended June 30, Total Assets Members' Equity Revenues Net Income Revenues Net Income (Loss) 2015 WTLPG $ 825,236 $ 821,140 $ 21,762 $ 8,242 $ 43,916 $ 16,945 As of December 31, 2014 WTLPG $ 827,697 $ 818,546 $ 25,950 $ 10,071 $ 47,914 $ 20,601 Cardinal $ — $ — $ 16,914 $ 2,353 $ 35,343 $ (605 ) As of June 30, 2015 and December 31, 2014 , the Partnership’s interest in cash of the unconsolidated equity-method investee was $2,610 and $10 , respectively.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	6 Months Ended
	Jun. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities The Partnership’s revenues and cost of products sold are materially impacted by changes in crude oil, natural gas and NGL prices. Additionally, the Partnership's results of operations are materially impacted by changes in interest rates. In an effort to manage its exposure to these risks, the Partnership periodically enters into various derivative instruments, including commodity and interest rate hedges. The Partnership is required to recognize all derivative instruments as either assets or liabilities at fair value on the Partnership’s Consolidated and Condensed Balance Sheets and to recognize certain changes in the fair value of derivative instruments on the Partnership’s Consolidated and Condensed Statements of Operations. (a) Commodity Derivative Instruments The Partnership from time to time has used derivatives to manage the risk of commodity price fluctuation. Commodity risk is the adverse effect on the value of a liability or future purchase that results from a change in commodity price. The Partnership has established a hedging policy and monitors and manages the commodity market risk associated with potential commodity risk exposure. In addition, the Partnership has focused on utilizing counterparties for these transactions whose financial condition is appropriate for the credit risk involved in each specific transaction. The Partnership did not have any commodity derivative instruments outstanding during the six months ended June 30, 2015 or 2014 . (b) Interest Rate Derivative Instruments The Partnership is exposed to market risks associated with interest rates. Market risk is the adverse effect on the value of a financial instrument that results from a change in interest rates. We minimize this market risk by establishing and monitoring parameters that limit the types and degree of market risk that may be undertaken. The Partnership enters into interest rate swaps to manage interest rate risk associated with the Partnership’s variable rate credit facility and its fixed rate senior unsecured notes. All derivatives and hedging instruments are included on the balance sheet as an asset or a liability measured at fair value and changes in fair value are recognized currently in earnings. During the six months ended June 30, 2015 , the Partnership entered into contracts which provided the counterparty the option to enter into swap contracts to hedge the Partnership's exposure to changes in the fair value of its senior unsecured notes ("interest rate swaptions") through June 30, 2015. In connection with the interest rate swaption contracts, the Partnership received premiums of $1,120 and $1,745 , which represented their fair value on the date the transactions were initiated and were initially recorded as derivative liabilities on the Partnership's Consolidated and Condensed Balance Sheet, during the three and six months ended June 30, 2015 , respectively. Each of the interest rate swaptions was fully amortized as of June 30, 2015. Interest rate swaption contract premiums received are amortized over the period from initiation of the contract through their termination date. For the three and six months ended June 30, 2015 , the Partnership recognized $1,120 and $1,745 , respectively, of premium in "Interest expense, net" on the Partnership's Consolidated and Condensed Statement of Operations related to the interest rate swaption contracts. For information regarding gains and losses on interest rate derivative instruments, see "Tabular Presentation of Gains and Losses on Derivative Instruments" below. (c) Tabular Presentation of Gains and Losses on Derivative Instruments Effect of Derivative Instruments on the Consolidated and Condensed Statement of Operations For the Three Months Ended June 30, 2015 and 2014 Location of Gain Recognized in Income on Derivatives Amount of Gain Recognized in Income on Derivatives 2015 2014 Derivatives not designated as hedging instruments: Interest rate swaption contracts Interest expense $ 1,120 $ 2,927 Total derivatives not designated as hedging instruments $ 1,120 $ 2,927 Effect of Derivative Instruments on the Consolidated and Condensed Statement of Operations For the Six Months Ended June 30, 2015 and 2014 Location of Gain Recognized in Income on Derivatives Amount of Gain Recognized in Income on Derivatives 2015 2014 Derivatives not designated as hedging instruments: Interest rate swaption contracts Interest expense $ 1,745 $ 2,927 Total derivatives not designated as hedging instruments $ 1,745 $ 2,927

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The Partnership follows the provisions of ASC 820 related to fair value measurements and disclosures, which established a framework for measuring fair value and expanded disclosures about fair value measurements. The adoption of this guidance had no impact on the Partnership’s financial position or results of operations. ASC 820 applies to all assets and liabilities that are being measured and reported on a fair value basis. This statement enables the reader of the financial statements to assess the inputs used to develop those measurements by establishing a hierarchy for ranking the quality and reliability of the information used to determine fair values. ASC 820 establishes a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value of each asset and liability carried at fair value into one of the following categories: Level 1: Quoted market prices in active markets for identical assets or liabilities. Level 2: Observable market based inputs or unobservable inputs that are corroborated by market data. Level 3: Unobservable inputs that are not corroborated by market data. The fair value of the following items are required to be disclosed on a recurring basis subject to the requirements of ASC 820 at June 30, 2015 and December 31, 2014 : Fair Value Measurements at Reporting Date Using Quoted Prices in Active Markets for Identical Assets Significant Other Observable Inputs Significant Unobservable Inputs Description June 30, 2015 (Level 1) (Level 2) (Level 3) Assets Note receivable - Martin Energy Trading $ 15,844 $ — $ — $ 15,844 Total assets $ 15,844 $ — $ — $ 15,844 Liabilities 2021 Senior unsecured notes $ 395,029 $ — $ 395,029 $ — Total liabilities $ 395,029 $ — $ 395,029 $ — Fair Value Measurements at Reporting Date Using Quoted Prices in Active Markets for Identical Assets Significant Other Observable Inputs Significant Unobservable Inputs Description December 31, 2014 (Level 1) (Level 2) (Level 3) Assets Note receivable - Martin Energy Trading $ 15,852 $ — $ — $ 15,852 Total assets $ 15,852 $ — $ — $ 15,852 Liabilities 2021 Senior unsecured notes $ 385,077 $ — $ 385,077 $ — Total liabilities $ 385,077 $ — $ 385,077 $ — FASB ASC 825-10-65, Disclosures about Fair Value of Financial Instruments , requires that the Partnership disclose estimated fair values for its financial instruments. Fair value estimates are set forth below for the Partnership’s financial instruments. The following methods and assumptions were used to estimate the fair value of each class of financial instrument: • Accounts and other receivables, trade and other accounts payable, accrued interest payable, other accrued liabilities, income taxes payable and due from/to affiliates: The carrying amounts approximate fair value due to the short-term maturity and highly liquid nature of these instruments, and as such these have been excluded from the table above. There is negligible credit risk associated with these instruments. • Note receivable and long-term debt including current portion: The carrying amount of the revolving credit facility approximates fair value due to the debt having a variable interest rate and is in Level 2. The Partnership has not had any indicators which represent a change in the market spread associated with its variable interest rate debt. The estimated fair value of the senior unsecured notes is based on market prices of similar debt. The estimated fair value of the note receivable from Martin Energy Trading was determined by calculating the net present value of the interest payments over the life of the note. The note is considered Level 3 due to the lack of observable inputs for similar transactions between related parties.

Supplemental Balance Sheet Info

Supplemental Balance Sheet Information	6 Months Ended
	Jun. 30, 2015
Balance Sheet Related Disclosures [Abstract]
Supplemental Balance Sheet Information	Supplemental Balance Sheet Information Components of "Other assets, net" were as follows: June 30, 2015 December 31, 2014 Customer contracts and relationships, net $ 61,209 $ 72,171 Other intangible assets 2,011 2,215 Other 8,426 7,079 $ 71,646 $ 81,465 Accumulated amortization of intangible assets was $ 23,719 and $ 12,125 at June 30, 2015 and December 31, 2014 , respectively. Components of "Other accrued liabilities" were as follows: June 30, 2015 December 31, 2014 Accrued interest $ 10,995 $ 10,996 Property and other taxes payable 5,727 7,524 Accrued payroll 3,483 3,125 Other 139 156 $ 20,344 $ 21,801

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt At June 30, 2015 and December 31, 2014 , long-term debt consisted of the following: June 30, December 31, $900,000 Revolving credit facility at variable interest rate (2.94% 1 weighted average at June 30, 2015), due March 2018 secured by substantially all of the Partnership’s assets, including, without limitation, inventory, accounts receivable, vessels, equipment, fixed assets and the interests in the Partnership’s operating subsidiaries and equity method investees, net of unamortized debt issuance costs of $7,584 and $8,656, respectively $ 442,416 $ 491,344 $400,000 Senior notes, 7.250% interest, net of unamortized debt issuance costs of $4,098 and $4,462, respectively, including unamortized premium of $1,841 and $2,005, respectively, issued $250,000 February 2013 and $150,000 April 2014, due February 2021, unsecured 397,743 397,543 Total long-term debt, net 840,159 888,887 Less current installments — — Long-term debt, net of current installments $ 840,159 $ 888,887 1 Interest rate fluctuates based on the LIBOR rate plus an applicable margin set on the date of each advance. The margin above LIBOR is set every three months. Indebtedness under the credit facility bears interest at LIBOR plus an applicable margin or the base prime rate plus an applicable margin. The applicable margin for revolving loans that are LIBOR loans ranges from 1.75% to 2.75% and the applicable margin for revolving loans that are base prime rate loans ranges from 0.75% to 1.75% . The applicable margin for existing LIBOR borrowings at June 30, 2015 is 2.75% . The credit facility contains various covenants which limit the Partnership’s ability to make certain investments and acquisitions; enter into certain agreements; incur indebtedness; sell assets; and make certain amendments to the Partnership's omnibus agreement with Martin Resource Management (the "Omnibus Agreement"). The Partnership is permitted to make quarterly distributions so long as no event of default exists. The Partnership paid cash interest, net of proceeds received from interest rate swaptions, in the amount of $3,015 and $6,735 for the three months ended June 30, 2015 and 2014 , respectively. The Partnership paid cash interest, net of proceeds received from interest rate swaptions, in the amount of $21,104 and $18,424 for the six months ended June 30, and 2014 , respectively. Capitalized interest was $570 and $335 for the three months ended June 30, 2015 and 2014 , respectively. Capitalized interest was $1,095 and $723 for the six months ended June 30, 2015 and 2014 , respectively.

Partners' Capital

Partners' Capital	6 Months Ended
	Jun. 30, 2015
Partners' Capital Notes [Abstract]
Partners' Capital	Partners' Capital As of June 30, 2015 , Partners’ capital consisted of 35,456,862 common limited partner units, representing a 98% partnership interest and a 2% general partner interest. Martin Resource Management, through subsidiaries, owned 6,264,532 of the Partnership's common limited partnership units representing approximately 17.7% of the Partnership's outstanding common limited partnership units. Martin Midstream GP LLC ("MMGP"), the Partnership's general partner, owns the 2% general partnership interest. Martin Resource Management controls the Partnership's general partner, by virtue of its 51% voting interest in MMGP Holdings, LLC ("Holdings"), the sole member of the Partnership's general partner. The partnership agreement of the Partnership (the "Partnership Agreement") contains specific provisions for the allocation of net income and losses to each of the partners for purposes of maintaining their respective partner capital accounts. Issuance of Common Units In March 2014, the Partnership entered into an equity distribution agreement with multiple underwriters (the "Sales Agents") for the ongoing distribution of the Partnership's common units. Pursuant to this program, the Partnership offered and sold common unit equity through the Sales Agents for proceeds of $0 and $17,798 during the six months ended June 30, 2015 and 2014, respectively. The Partnership paid $228 and $382 in equity issuance related costs for the six months ended June 30, 2015 and 2014, respectively. Under the the program, the Partnership issued 0 and 417,156 common units during the six months ended June 30, 2015 and 2014, respectively. Common units issued were at market prices prevailing at the time of the sale. Under the program, the Partnership also received capital contributions from the general partner of $0 and $356 during the six months ended June 30, 2015 and 2014, respectively, to maintain its 2% general partner interest in the Partnership. The net proceeds from the common unit issuances were used to pay down outstanding amounts under the Partnership's revolving credit facility. Incentive Distribution Rights MMGP holds a 2% general partner interest and certain incentive distribution rights ("IDRs") in the Partnership. IDRs are a separate class of non-voting limited partner interest that may be transferred or sold by the general partner under the terms of the Partnership Agreement, and represent the right to receive an increasing percentage of cash distributions after the minimum quarterly distribution and any cumulative arrearages on common units once certain target distribution levels have been achieved. The Partnership is required to distribute all of its available cash from operating surplus, as defined in the Partnership Agreement. On October 2, 2012, the Partnership Agreement was amended to provide that the general partner would forego the next $18,000 in incentive distributions that it would otherwise be entitled to receive. Additionally, on May 5, 2014, the owner of our general partner agreed to forego an additional $3,000 in incentive distributions. As of March 31, 2015, all incentive distributions the general partner agreed to forego were satisfied. The general partner received $3,893 and $7,631 in incentive distributions during the three and six months ended June 30, 2015. No incentive distributions were paid to the general partner during the three and six months ended June 30, 2014. The target distribution levels entitle the general partner to receive 2% of quarterly cash distributions up to $0.55 per unit, 15% of quarterly cash distributions in excess of $0.55 per unit until all unitholders have received $0.625 per unit, 25% of quarterly cash distributions in excess of $0.625 per unit until all unitholders have received $0.75 per unit and 50% of quarterly cash distributions in excess of $0.75 per unit. Distributions of Available Cash The Partnership distributes all of its available cash (as defined in the Partnership Agreement) within 45 days after the end of each quarter to unitholders of record and to the general partner. Available cash is generally defined as all cash and cash equivalents of the Partnership on hand at the end of each quarter less the amount of cash reserves its general partner determines in its reasonable discretion is necessary or appropriate to: (i) provide for the proper conduct of the Partnership’s business; (ii) comply with applicable law, any debt instruments or other agreements; or (iii) provide funds for distributions to unitholders and the general partner for any one or more of the next four quarters, plus all cash on the date of determination of available cash for the quarter resulting from working capital borrowings made after the end of the quarter. Net Income per Unit The Partnership follows the provisions of the FASB ASC 260-10 related to earnings per share, which addresses the application of the two-class method in determining income per unit for master limited partnerships having multiple classes of securities that may participate in partnership distributions accounted for as equity distributions. Undistributed earnings are allocated to the general partner and limited partners utilizing the contractual terms of the Partnership Agreement. Distributions to the general partner pursuant to the IDRs are limited to available cash that will be distributed as defined in the Partnership Agreement. Accordingly, the Partnership does not allocate undistributed earnings to the general partner for the IDRs because the general partner's share of available cash is the maximum amount that the general partner would be contractually entitled to receive if all earnings for the period were distributed. When current period distributions are in excess of earnings, the excess distributions for the period are to be allocated to the general partner and limited partners based on their respective sharing of income and losses specified in the Partnership Agreement. Additionally, as required under FASB ASC 260-10-45-61A, unvested share-based payments that entitle employees to receive non-forfeitable distributions are considered participating securities, as defined in FASB ASC 260-10-20, for earnings per unit calculations. For purposes of computing diluted net income per unit, the Partnership uses the more dilutive of the two-class and if-converted methods. Under the if-converted method, the weighted-average number of subordinated units outstanding for the period is added to the weighted-average number of common units outstanding for purposes of computing basic net income per unit and the resulting amount is compared to the diluted net income per unit computed using the two-class method. The following is a reconciliation of net income allocated to the general partner and limited partners for purposes of calculating net income attributable to limited partners per unit: Three Months Ended June 30, Six Months Ended June 30, Continuing operations: 2015 2014 2015 2014 Income from continuing operations $ 10,961 $ 324 $ 26,994 $ 12,708 Less general partner’s interest in net income: Distributions payable on behalf of IDRs 3,893 — 7,452 — Distributions payable on behalf of general partner interest 667 624 1,277 1,120 General partner interest in undistributed earnings (447 ) (616 ) (737 ) (865 ) Less income allocable to unvested restricted units 44 — 106 34 Limited partners’ interest in income from continuing operations $ 6,804 $ 316 $ 18,896 $ 12,419 Three Months Ended June 30, Six Months Ended June 30, Discontinued operations: 2015 2014 2015 2014 Income (loss) from discontinued operations $ — $ (1,292 ) $ 1,215 $ (1,881 ) Less general partner’s interest in net income: Distributions payable on behalf of IDRs — — 335 — Distributions payable on behalf of general partner interest — (142 ) 58 (166 ) General partner interest in undistributed earnings — 115 (34 ) 128 Less income allocable to unvested restricted units — (3 ) 5 (5 ) Limited partners’ interest in income (loss) from discontinued operations $ — $ (1,262 ) $ 851 $ (1,838 ) The weighted average units outstanding for basic net income per unit were 35,307,638 and 35,315,989 for the three and six months ended June 30, 2015 , respectively. The weighted average units outstanding for basic net income per unit were 28,923,513 and 27,757,304 for the three and six months ended June 30, 2014, respectively. All outstanding units were included in the computation of diluted earnings per unit and weighted based on the number of days such units were outstanding during the period presented. For diluted net income per unit, the weighted average units outstanding were increased by 68,499 and 56,115 for the three and six months ended June 30, 2015, respectively, due to the dilutive effect of restricted units granted under the Partnership’s long-term incentive plan. For diluted net income per unit, the weighted average units outstanding were increased by 34,233 and 33,350 for the three and six months ended June 30, 2014, respectively, due to the dilutive effect of restricted units granted under the Partnership’s long-term incentive plan.

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2015
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions As of June 30, 2015 , Martin Resource Management owned 6,264,532 of the Partnership’s common units representing approximately 17.7% of the Partnership’s outstanding limited partnership units. Martin Resource Management controls the Partnership's general partner by virtue of its 51% voting interest in Holdings, the sole member of the Partnership's general partner. The Partnership’s general partner, MMGP, owns a 2% general partner interest in the Partnership and the Partnership’s IDRs. The Partnership’s general partner’s ability, as general partner, to manage and operate the Partnership, and Martin Resource Management’s ownership as of June 30, 2015 , of approximately 17.7% of the Partnership’s outstanding limited partnership units, effectively gives Martin Resource Management the ability to veto some of the Partnership’s actions and to control the Partnership’s management. The following is a description of the Partnership’s material related party agreements and transactions: Omnibus Agreement Omnibus Agreement . The Partnership and its general partner are parties to the Omnibus Agreement dated November 1, 2002, with Martin Resource Management that governs, among other things, potential competition and indemnification obligations among the parties to the agreement, related party transactions, the provision of general administration and support services by Martin Resource Management and the Partnership’s use of certain Martin Resource Management trade names and trademarks. The Omnibus Agreement was amended on November 25, 2009, to include processing crude oil into finished products including naphthenic lubricants, distillates, asphalt and other intermediate cuts. The Omnibus Agreement was amended further on October 1, 2012, to permit the Partnership to provide certain lubricant packaging products and services to Martin Resource Management. Non-Competition Provisions . Martin Resource Management has agreed for so long as it controls the general partner of the Partnership, not to engage in the business of: • providing terminalling and storage services for petroleum products and by-products including the refining, blending and packaging of finished lubricants; • providing marine transportation of petroleum products and by-products; • distributing NGLs; and • manufacturing and selling sulfur-based fertilizer products and other sulfur-related products. This restriction does not apply to: • the ownership and/or operation on the Partnership’s behalf of any asset or group of assets owned by it or its affiliates; • any business operated by Martin Resource Management, including the following: ◦ providing land transportation of various liquids; ◦ distributing fuel oil, ammonia, asphalt, sulfuric acid, marine fuel and other liquids; ◦ providing marine bunkering and other shore-based marine services in Alabama, Florida, Louisiana, Mississippi and Texas; ◦ operating a crude oil gathering business in Stephens, Arkansas; ◦ providing crude oil gathering, refining, and marketing services of base oils, asphalt, and distillate products in Smackover, Arkansas; ◦ providing crude oil marketing and transportation from the well head to the end market; ◦ operating an environmental consulting company; ◦ operating an engineering services company; ◦ supplying employees and services for the operation of the Partnership's business; ◦ operating a natural gas optimization business; and ◦ operating, solely for the Partnership's account, the asphalt facilities in Omaha, Nebraska, Port Neches, Texas and South Houston, Texas. • any business that Martin Resource Management acquires or constructs that has a fair market value of less than $5,000 ; • any business that Martin Resource Management acquires or constructs that has a fair market value of $5,000 or more if the Partnership has been offered the opportunity to purchase the business for fair market value and the Partnership declines to do so with the concurrence of the conflicts committee of the board of directors of the general partner of the Partnership (the "Conflicts Committee"); and • any business that Martin Resource Management acquires or constructs where a portion of such business includes a restricted business and the fair market value of the restricted business is $5,000 or more and represents less than 20% of the aggregate value of the entire business to be acquired or constructed; provided that, following completion of the acquisition or construction, the Partnership will be provided the opportunity to purchase the restricted business. Services. Under the Omnibus Agreement, Martin Resource Management provides the Partnership with corporate staff, support services, and administrative services necessary to operate the Partnership’s business. The Omnibus Agreement requires the Partnership to reimburse Martin Resource Management for all direct expenses it incurs or payments it makes on the Partnership’s behalf or in connection with the operation of the Partnership’s business. There is no monetary limitation on the amount the Partnership is required to reimburse Martin Resource Management for direct expenses. In addition to the direct expenses, under the Omnibus Agreement, the Partnership is required to reimburse Martin Resource Management for indirect general and administrative and corporate overhead expenses. Effective January 1, 2015, through December 31, 2015, the Conflicts Committee approved an annual reimbursement amount for indirect expenses of $13,679 . The Partnership reimbursed Martin Resource Management for $3,419 and $3,134 of indirect expenses for the three months ended June 30, 2015 and 2014 , respectively. The Partnership reimbursed Martin Resource Management for $6,839 and $6,268 of indirect expenses for the six months ended June 30, 2015 and 2014 , respectively. The Conflicts Committee will review and approve future adjustments in the reimbursement amount for indirect expenses, if any, annually. These indirect expenses are intended to cover the centralized corporate functions Martin Resource Management provides for the Partnership, such as accounting, treasury, clerical, engineering, legal, billing, information technology, administration of insurance, general office expenses and employee benefit plans and other general corporate overhead functions the Partnership shares with Martin Resource Management retained businesses. The provisions of the Omnibus Agreement regarding Martin Resource Management’s services will terminate if Martin Resource Management ceases to control the general partner of the Partnership. Related Party Transactions . The Omnibus Agreement prohibits the Partnership from entering into any material agreement with Martin Resource Management without the prior approval of the Conflicts Committee. For purposes of the Omnibus Agreement, the term "material agreements" means any agreement between the Partnership and Martin Resource Management that requires aggregate annual payments in excess of the then-applicable agreed upon reimbursable amount of indirect general and administrative expenses. Please read "Services" above. License Provisions. Under the Omnibus Agreement, Martin Resource Management has granted the Partnership a nontransferable, nonexclusive, royalty-free right and license to use certain of its trade names and marks, as well as the trade names and marks used by some of its affiliates. Amendment and Termination. The Omnibus Agreement may be amended by written agreement of the parties; provided, however, that it may not be amended without the approval of the Conflicts Committee if such amendment would adversely affect the unitholders. The Omnibus Agreement was first amended on November 25, 2009, to permit the Partnership to provide refining services to Martin Resource Management. The Omnibus Agreement was amended further on October 1, 2012, to permit the Partnership to provide certain lubricant packaging products and services to Martin Resource Management. Such amendments were approved by the Conflicts Committee. The Omnibus Agreement, other than the indemnification provisions and the provisions limiting the amount for which the Partnership will reimburse Martin Resource Management for general and administrative services performed on its behalf, will terminate if the Partnership is no longer an affiliate of Martin Resource Management. Motor Carrier Agreement Motor Carrier Agreement. The Partnership is a party to a motor carrier agreement effective January 1, 2006, as amended, with Martin Transport, Inc., a wholly owned subsidiary of Martin Resource Management through which Martin Transport, Inc. operates its land transportation operations. Under the agreement, Martin Transport, Inc. agreed to transport the Partnership's NGLs as well as other liquid products. Term and Pricing. The agreement has an initial term that expired in December 2007 but automatically renews for consecutive one year periods unless either party terminates the agreement by giving written notice to the other party at least 30 days prior to the expiration of the then-applicable term. The Partnership has the right to terminate this agreement at any time by providing 90 days prior notice. These rates are subject to any adjustments which are mutually agreed upon or in accordance with a price index. Additionally, during the term of the agreement, shipping charges are also subject to fuel surcharges determined on a weekly basis in accordance with the U.S. Department of Energy’s national diesel price list. Indemnification. Martin Transport, Inc. has indemnified the Partnership against all claims arising out of the negligence or willful misconduct of Martin Transport, Inc. and its officers, employees, agents, representatives and subcontractors. The Partnership indemnified Martin Transport, Inc. against all claims arising out of the negligence or willful misconduct of the Partnership and its officers, employees, agents, representatives and subcontractors. In the event a claim is the result of the joint negligence or misconduct of Martin Transport, Inc. and the Partnership, indemnification obligations will be shared in proportion to each party’s allocable share of such joint negligence or misconduct. Marine Agreements Marine Transportation Agreement. The Partnership is a party to a marine transportation agreement effective January 1, 2006, as amended, under which the Partnership provides marine transportation services to Martin Resource Management on a spot-contract basis at applicable market rates. Effective each January 1, this agreement automatically renews for consecutive one year periods unless either party terminates the agreement by giving written notice to the other party at least 60 days prior to the expiration of the then applicable term. The fees the Partnership charges Martin Resource Management are based on applicable market rates. Marine Fuel. The Partnership is a party to an agreement with Martin Resource Management dated November 1, 2002, under which Martin Resource Management provides the Partnership with marine fuel from its locations in the Gulf of Mexico at a fixed rate in excess of the Platt’s U.S. Gulf Coast Index for #2 Fuel Oil. Under this agreement, the Partnership agreed to purchase all of its marine fuel requirements that occur in the areas serviced by Martin Resource Management. Terminal Services Agreements Diesel Fuel Terminal Services Agreement. Effective January 1, 2015, the Partnership entered into a new terminalling services agreement under which the Partnership provides terminal services to Martin Resource Management for marine fuel distribution. This agreement replaced the prior agreement that was in place concerning the same services which was dated October 27, 2004 and consolidated it with the (i) terminalling services agreement entered into in connection with the acquisition of Talen's Marine & Fuel, LLC ("Talen's") and (ii) terminalling services agreement entered into in connection with the acquisition of L&L Holdings LLC ("L&L") into a single agreement. The minimum throughput requirements of the three superseded agreements were aggregated in the new agreement. The per gallon throughput fee the Partnership charges under this agreement may be adjusted annually based on a price index. Miscellaneous Terminal Services Agreements. The Partnership is a party to several terminal services agreements and from time to time the Partnership may enter into other terminal service agreements for the purpose of providing terminal services to related parties. Individually, each of these agreements is immaterial but when considered in the aggregate they could be deemed material. These agreements are throughput based with a minimum volume commitment. Generally, the fees due under these agreements are adjusted annually based on a price index. Other Agreements Cross Tolling Agreement. The Partnership is a party to an amended and restated tolling agreement with Cross Oil Refining and Marketing, Inc. ("Cross") dated October 28, 2014, under which the Partnership processes crude oil into finished products, including naphthenic lubricants, distillates, asphalt and other intermediate cuts for Cross. The tolling agreement expires November 25, 2031. Under this tolling agreement, Cross agreed to process a minimum of 6,500 barrels per day of crude oil at the facility at a fixed price per barrel. Any additional barrels are processed at a modified price per barrel. In addition, Cross agreed to pay a monthly reservation fee and a periodic fuel surcharge fee based on certain parameters specified in the tolling agreement. All of these fees (other than the fuel surcharge) are subject to escalation annually based upon the greater of 3% or the increase in the Consumer Price Index for a specified annual period. In addition, on the third, sixth and ninth anniversaries of the agreement, the parties can negotiate an upward or downward adjustment in the fees subject to their mutual agreement. Sulfuric Acid Sales Agency Agreement . The Partnership is party to a second amended and restated sulfuric acid sales agency agreement dated August 5, 2013, under which Martin Resource Management purchases and markets the sulfuric acid produced by the Partnership’s sulfuric acid production plant at Plainview, Texas, that is not consumed by the Partnership’s internal operations. This agreement, as amended, will remain in place until the Partnership terminates it by providing 180 days written notice. Under this agreement, the Partnership sells all of its excess sulfuric acid to Martin Resource Management. Martin Resource Management then markets such acid to third parties and the Partnership shares in the profit of Martin Resource Management’s sales of the excess acid to such third parties. Other Miscellaneous Agreements. From time to time, the Partnership enters into other miscellaneous agreements with Martin Resource Management for the provision of other services or the purchase of other goods. The tables below summarize the related party transactions that are included in the related financial statement captions on the face of the Partnership’s Consolidated and Condensed Statements of Operations. The revenues, costs and expenses reflected in these tables are tabulations of the related party transactions that are recorded in the corresponding captions of the consolidated and condensed financial statements and do not reflect a statement of profits and losses for related party transactions. The impact of related party revenues from sales of products and services is reflected in the consolidated and condensed financial statements as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Revenues: Terminalling and storage $ 23,061 $ 18,743 $ 43,535 $ 36,753 Marine transportation 6,622 6,415 13,367 12,264 Product sales: Natural gas services 286 2,217 300 3,046 Sulfur services 970 1,268 2,044 2,223 Terminalling and storage 503 224 1,004 332 1,759 3,709 3,348 5,601 $ 31,442 $ 28,867 $ 60,250 $ 54,618 The impact of related party cost of products sold is reflected in the consolidated and condensed financial statements as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Cost of products sold: Natural gas services $ 6,810 $ 10,808 $ 13,728 $ 19,261 Sulfur services 3,618 4,452 7,242 9,317 Terminalling and storage 5,632 6,553 11,034 16,397 $ 16,060 $ 21,813 $ 32,004 $ 44,975 The impact of related party operating expenses is reflected in the consolidated and condensed financial statements as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Operating expenses: Marine transportation $ 8,038 $ 8,823 $ 16,598 $ 18,487 Natural gas services 1,992 798 4,155 1,404 Sulfur services 2,036 2,034 3,699 3,520 Terminalling and storage 6,849 7,593 14,863 14,076 $ 18,915 $ 19,248 $ 39,315 $ 37,487 The impact of related party selling, general and administrative expenses is reflected in the consolidated and condensed financial statements as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Selling, general and administrative: Marine transportation $ 8 $ 7 $ 16 $ 15 Natural gas services 1,238 1,146 2,401 2,104 Sulfur services 642 820 1,438 1,663 Terminalling and storage 542 343 1,149 728 Indirect overhead allocation, net of reimbursement 3,419 3,173 6,839 6,363 $ 5,849 $ 5,489 $ 11,843 $ 10,873 Other Related Party Transactions As discussed in Note 6, during March 2013, the Partnership acquired 100% of the preferred interests in MET, a subsidiary of Martin Resource Management, for $15,000 . On August 31, 2014, MET converted its preferred equity to subordinated debt. The resulting $15,000 note receivable from MET bears an annual interest rate of 15% and matures August 31, 2026. MET may prepay any or all of the note balance on or after September 1, 2016. The note is recorded in "Note receivable - Martin Energy Trading LLC" on the Partnership's Consolidated and Condensed Balance Sheet. Interest income for the three and six months ended June 30, 2015 was $561 and $1,116 , respectively, and is included in "Interest expense, net" in the Consolidated and Condensed Statements of Operations.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The operations of the Partnership are generally not subject to income taxes because its income is taxed directly to its partners. The Partnership is subject to the Texas margin tax which is included in income tax expense on the Consolidated and Condensed Statements of Operations. The Texas margin tax restructured the state business tax by replacing the taxable capital and earned surplus components of the existing franchise tax with a new "taxable margin" component. Since the tax base on the Texas margin tax is derived from an income-based measure, the margin tax is construed as an income tax and, therefore, the recognition of deferred taxes applies to the margin tax. The impact on deferred taxes as a result of this provision is immaterial. State income taxes attributable to the Texas margin tax of $314 and $354 were recorded in income tax expense for the three months ended June 30, 2015 and 2014 , respectively. State income taxes attributable to the Texas margin tax of $614 and $654 were recorded in income tax expense for the six months ended June 30, 2015 and 2014 , respectively.

Business Segments

Business Segments	6 Months Ended
	Jun. 30, 2015
Segment Reporting [Abstract]
Business Segments	Business Segments The Partnership has four reportable segments: terminalling and storage, natural gas services, sulfur services and marine transportation. The Partnership’s reportable segments are strategic business units that offer different products and services. The operating income of these segments is reviewed by the chief operating decision maker to assess performance and make business decisions. The accounting policies of the operating segments are the same as those described in Note 2 in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2014 , filed with the SEC on March 2, 2015, as amended, by Amendment No. 1 on Form 10-K/A filed on March 5, 2015. The Partnership evaluates the performance of its reportable segments based on operating income. There is no allocation of administrative expenses or interest expense. Three Months Ended June 30, 2015 Operating Revenues Intersegment Revenues Eliminations Operating Revenues after Eliminations Depreciation and Amortization Operating Income (Loss) after Eliminations Capital Expenditures and Plant Turnaround Costs Terminalling and storage $ 69,287 $ (1,255 ) $ 68,032 $ 9,617 $ 5,298 $ 8,207 Natural gas services 114,350 — 114,350 8,373 9,260 5,395 Sulfur services 48,374 — 48,374 2,105 7,144 147 Marine transportation 20,886 (543 ) 20,343 2,590 2,428 502 Indirect selling, general and administrative — — — — (4,500 ) — Total $ 252,897 $ (1,798 ) $ 251,099 $ 22,685 $ 19,630 $ 14,251 Three Months Ended June 30, 2014 Operating Revenues Intersegment Revenues Eliminations Operating Revenues after Eliminations Depreciation and Amortization Operating Income (Loss) after Eliminations Capital Expenditures and Plant Turnaround Costs Terminalling and storage $ 86,917 $ (1,307 ) $ 85,610 $ 9,415 $ 8,365 $ 15,544 Natural gas services 232,986 — 232,986 293 7,106 74 Sulfur services 62,581 — 62,581 2,031 7,886 1,633 Marine transportation 23,282 (1,198 ) 22,084 2,473 (522 ) 4,258 Indirect selling, general and administrative — — — — (4,838 ) — Total $ 405,766 $ (2,505 ) $ 403,261 $ 14,212 $ 17,997 $ 21,509 Six Months Ended June 30, 2015 Operating Revenues Intersegment Revenues Eliminations Operating Revenues after Eliminations Depreciation and Amortization Operating Income (Loss) after Eliminations Capital Expenditures and Plant Turnaround Costs Terminalling and storage $ 139,321 $ (2,499 ) $ 136,822 $ 19,406 $ 12,985 $ 17,882 Natural gas services 277,140 — 277,140 16,775 18,147 14,109 Sulfur services 101,511 — 101,511 4,231 15,266 361 Marine transportation 42,832 (1,853 ) 40,979 4,990 7,244 1,196 Indirect selling, general and administrative — — — — (9,310 ) — Total $ 560,804 $ (4,352 ) $ 556,452 $ 45,402 $ 44,332 $ 33,548 Six Months Ended June 30, 2014 Operating Revenues Intersegment Revenues Eliminations Operating Revenues after Eliminations Depreciation and Amortization Operating Income (Loss) after Eliminations Capital Expenditures and Plant Turnaround Costs Terminalling and storage $ 174,214 $ (2,530 ) $ 171,684 $ 18,390 $ 16,676 $ 33,306 Natural gas services 554,400 — 554,400 413 17,161 574 Sulfur services 116,788 — 116,788 4,014 15,954 3,081 Marine transportation 47,396 (2,198 ) 45,198 5,003 2,440 8,186 Indirect selling, general and administrative — — — — (9,735 ) — Total $ 892,798 $ (4,728 ) $ 888,070 $ 27,820 $ 42,496 $ 45,147 The Partnership's assets by reportable segment as of June 30, 2015 and December 31, 2014 , are as follows: June 30, 2015 December 31, 2014 Total assets: Terminalling and storage $ 435,347 $ 446,313 Natural gas services 693,187 795,462 Sulfur services 136,537 145,852 Marine transportation 146,439 153,174 Total assets $ 1,411,510 $ 1,540,801

Unit Based Awards

Unit Based Awards	6 Months Ended
	Jun. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Unit Based Awards	Unit Based Awards The Partnership recognizes compensation cost related to unit-based awards to employees in its consolidated financial statements in accordance with certain provisions of ASC 718. The Partnership recognizes compensation costs related to unit-based awards to directors under certain provisions of ASC 505-50-55 related to equity-based payments to non-employees. Amounts recognized in selling, general, and administrative expense in the consolidated and condensed financial statements with respect to these plans are as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Employees $ 341 $ 156 $ 652 $ 284 Non-employee directors 10 52 98 103 Total unit-based compensation expense $ 351 $ 208 $ 750 $ 387 Long-Term Incentive Plans The Partnership's general partner has a long-term incentive plan for employees and directors of the general partner and its affiliates who perform services for the Partnership. The plan consists of two components: restricted units and unit options. The plan currently permits the grant of awards covering an aggregate of 725,000 common units, 241,667 of which may be awarded in the form of restricted units and 483,333 of which may be awarded in the form of unit options. The plan is administered by the compensation committee of the general partner’s board of directors (the "Compensation Committee"). Restricted Units. A restricted unit is a unit that is granted to grantees with certain vesting restrictions. Once these restrictions lapse, the grantee is entitled to full ownership of the unit without restrictions. In addition, the restricted units will vest upon a change of control of the Partnership, the general partner or Martin Resource Management or if the general partner ceases to be an affiliate of Martin Resource Management. The Partnership intends the issuance of the common units upon vesting of the restricted units under the plan to serve as a means of incentive compensation for performance and not primarily as an opportunity to participate in the equity appreciation of the common units. Therefore, plan participants will not pay any consideration for the common units they receive, and the Partnership will receive no remuneration for the units. The restricted units issued to directors generally vest in equal annual installments over a four -year period. Restricted units issued to employees generally cliff vest after three years of service. The restricted units are valued at their fair value at the date of grant which is equal to the market value of common units on such date. A summary of the restricted unit activity for the six months ended June 30, 2015 is provided below: Number of Units Weighted Average Grant-Date Fair Value Per Unit Non-vested, beginning of period 63,824 $ 31.57 Granted 91,950 $ 28.69 Vested (3,550 ) $ 34.56 Forfeited (1,000 ) $ 31.06 Non-Vested, end of period 151,224 $ 29.75 Aggregate intrinsic value, end of period $ 4,620 A summary of the restricted units’ aggregate intrinsic value (market value at vesting date) and fair value of units vested (market value at date of grant) during the six months ended June 30, 2015 and 2014 is provided below: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Aggregate intrinsic value of units vested $ — $ — $ 110 $ 249 Fair value of units vested $ — $ — $ 113 $ 247 As of June 30, 2015 , there was $2,682 of unrecognized compensation cost related to non-vested restricted units. That cost is expected to be recognized over a weighted-average period of 1.87 years. In conjunction with restricted unit issuances during the six months ended June 30, 2015, the Partnership received $55 in capital contributions from its general partner to maintain its 2% general partnership interest in the Partnership. Unit Options. The plan currently permits the grant of options covering common units. As of June 30, 2015 , the Partnership has not granted any common unit options to directors or employees of the Partnership's general partner, or its affiliates. In the future, the Compensation Committee may determine to make grants under the plan to employees and directors containing such terms as the Compensation Committee shall determine. Unit options will have an exercise price that, in the discretion of the Compensation Committee, may not be less than the fair market value of the units on the date of grant. In addition, the unit options will become exercisable upon a change in control of the Partnership's general partner, Martin Resource Management, or if the general partner ceases to be an affiliate of Martin Resource Management or upon the achievement of specified financial objectives.

Condensed Consolidating Financi

Condensed Consolidating Financial Information	6 Months Ended
	Jun. 30, 2015
Consolidating Financial Statements [Abstract]
Condensed Consolidating Financial Information	Condensed Consolidating Financial Information The Partnership's operations are conducted by its operating subsidiaries as it has no independent assets or operations. Martin Operating Partnership L.P. (the "Operating Partnership"), the Partnership’s wholly-owned subsidiary, and the Partnership's other operating subsidiaries have issued in the past, and may issue in the future, unconditional guarantees of senior or subordinated debt securities of the Partnership. The guarantees that have been issued are full, irrevocable and unconditional and joint and several. In addition, the Operating Partnership may also issue senior or subordinated debt securities which, if issued, will be fully, irrevocably and unconditionally guaranteed by the Partnership. Substantially all of the Partnership's operating subsidiaries are subsidiary guarantors of its outstanding senior unsecured notes and any subsidiaries other than the subsidiary guarantors are minor.

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies From time to time, the Partnership is subject to various claims and legal actions arising in the ordinary course of business. In the opinion of management, the ultimate disposition of these matters will not have a material adverse effect on the Partnership. Pursuant to a Purchase Price Reimbursement Agreement between the Partnership and Martin Resource Management related to the Partnership’s acquisition of the Redbird Gas Storage LLC ("Redbird") Class A interests on October 2, 2012, beginning in the second quarter of 2015, Martin Resource Management will reimburse the Partnership $750 each quarter for four consecutive quarters as a reduction in the purchase price of the Redbird Class A interests. These payments are a result of Cardinal not achieving certain financial targets set forth in the Purchase Price Reimbursement Agreement. These payments are considered a reduction of the excess of the purchase price over the carrying value of the assets transferred to the Partnership from Martin Resource Management and will be recorded as an adjustment to "Partners' capital" in each quarter the payments are made. The agreement further provides for purchase price reimbursements of up to $4,500 in 2016 in the event certain financial conditions are not met. Currently, the Partnership has made no determination if the conditions are expected to be met in 2016. For the three and six months ended June 30, 2015, the Partnership received $750 related to the Purchase Price Reimbursement Agreement. The Partnership has been named as a defendant in a case in Cameron Parish, Louisiana that was served on July 17, 2015. The plaintiff alleges that the Partnership has breached a lease agreement with it by failing to perform work to the property as required under the lease agreement. Prior to this litigation, the Partnership planned to spend $1,600 for such work in 2015. The Partnership intends to vigorously defend this matter and at this time is unable to ascertain the damages, if any, that could ultimately be awarded against it.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2015
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events Quarterly Distribution. On July 23, 2015, the Partnership declared a quarterly cash distribution of $0.8125 per common unit for the second quarter of 2015, or $3.25 per common unit on an annualized basis, which will be paid on August 14, 2015 to unitholders of record as of August 7, 2015. Additionally, the Partnership expects to pay a distribution to its general partner in the amount of $4,560 . Of this amount, $667 is related to the base general partner distribution and $3,893 represents incentive distribution rights paid to the general partner. Interest Rate Swaps. The Partnership entered into an interest rate swap agreement effective July 2, 2015 with an aggregate notional amount of $200,000 to hedge its exposure to changes in the fair value of its senior unsecured notes. The termination date of this interest rate swap is July 2, 2020. Under these swap agreements, the Partnership will pay a floating rate of interest and receive a fixed rate based on a three-month U.S. Dollar LIBOR rate to match the fixed rate of the senior unsecured notes. The Partnership will not apply hedge accounting treatment to this instrument. Changes in the fair value of this instrument will be recorded on the Partnership’s Consolidated and Condensed Statements of Operations.

Acquisitions (Tables)

Acquisitions (Tables)	6 Months Ended
	Jun. 30, 2015
Business Combinations [Abstract]
Schedule of Business Acquisitions	The total purchase price is as follows: Cash payment for 57.8% interest in Cardinal $ 120,973 Fair value of the Partnership's previously owned 42.2% interest in Cardinal 87,613 Total $ 208,586
Assets and Liabilities Acquired in Acquisition	Assets acquired and liabilities assumed were recorded in the Natural Gas Services segment at fair value in the following purchase price allocation which was finalized in the fourth quarter of 2014: Restricted cash $ 17,566 Other current assets 9,385 Property, plant and equipment 390,895 Intangible and other assets 80,135 Project level finance debt (282,087 ) Other current liabilities (6,713 ) Other non-current liabilities (595 ) Total $ 208,586 The Partnership recorded the purchase in the following allocation: Property, plant and equipment $ 2,453 Current liabilities (13 ) $ 2,440
Schedule Pro Forma Information	The following pro forma consolidated results of operations for the three and six months ended June 30, 2014 have been prepared as if the acquisition of Cardinal and WTLPG occurred at the beginning of fiscal 2014: Three Months Ended June 30, 2014 Six Months Ended June 30, 2014 Revenue: As reported $ 403,261 $ 888,070 Pro forma $ 420,175 $ 923,413 Net income (loss) from continuing operations attributable to limited partners: As reported $ 316 $ 12,419 Pro forma $ (7,098 ) $ (4,216 ) Net loss from discontinued operations attributable to limited partners: As reported $ (1,262 ) $ (1,838 ) Pro forma $ (1,262 ) $ (1,838 ) Net income (loss) from continuing operations per unit attributable to limited partners - basic: As reported $ 0.01 $ 0.45 Pro forma $ (0.25 ) $ (0.15 ) Net loss from discontinued operations per unit attributable to limited partners - basic: As reported $ (0.04 ) $ (0.07 ) Pro forma $ (0.04 ) $ (0.07 ) Net income (loss) from continuing operations per unit attributable to limited partners - diluted: As reported $ 0.01 $ 0.45 Pro forma $ (0.25 ) $ (0.15 ) Net loss from discontinued operations per unit attributable to limited partners - diluted: As reported $ (0.04 ) $ (0.07 ) Pro forma $ (0.04 ) $ (0.07 )

Discontinued operations and d28

Discontinued operations and divestitures (Tables)	6 Months Ended
	Jun. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
Schedule of operating results from discontinued operations	The Floating Storage Assets’ operating results, which are included in income from discontinued operations, were as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Total revenues from third parties 1 $ — $ 15,683 $ 791 $ 33,175 Total costs and expenses and other, net, excluding depreciation and amortization — 16,592 1,038 34,290 Depreciation and amortization — 383 — 766 Other operating income 2 — — 1,462 — Income (loss) from discontinued operations before income taxes — (1,292 ) 1,215 (1,881 ) Income tax expense — — — — Income (loss) from discontinued operations, net of income taxes $ — $ (1,292 ) $ 1,215 $ (1,881 ) 1 Total revenues from third parties excludes intercompany revenues of $0 and $0 for the three months ended June 30, 2015 and 2014, respectively. Total revenues from third parties excludes intercompany revenues of $0 and $5,273 for the six months ended June 30, 2015 and 2014, respectively. 2 Other operating income represents the gain on the disposition of the Floating Storage Assets.

Inventories (Tables)

Inventories (Tables)	6 Months Ended
	Jun. 30, 2015
Inventory Disclosure [Abstract]
Components of inventory	Components of inventories at June 30, 2015 and December 31, 2014 were as follows: June 30, 2015 December 31, 2014 Natural gas liquids $ 22,658 $ 27,820 Sulfur 11,817 12,231 Sulfur based products 13,981 16,280 Lubricants 24,923 29,096 Other 3,184 3,291 $ 76,563 $ 88,718

Investments in Unconsolidated30

Investments in Unconsolidated Entities and Joint Ventures (Tables)	6 Months Ended
	Jun. 30, 2015
Equity Method Investments and Joint Ventures [Abstract]
Summary of components of investment in unconsolidated entities and components of equity in earnings of unconsolidated entities	The following tables summarize the components of the investment in unconsolidated entities on the Partnership’s Consolidated and Condensed Balance Sheets and the components of equity in earnings of unconsolidated entities included in the Partnership’s Consolidated and Condensed Statements of Operations: June 30, 2015 December 31, 2014 WTLPG $ 133,495 $ 134,506 Total investment in unconsolidated entities $ 133,495 $ 134,506 Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Equity in earnings of WTLPG $ 1,649 $ 769 $ 3,389 $ 769 Equity in earnings (loss) of Cardinal — 608 — (243 ) Equity in earnings of MET — 561 — 1,116 Equity in earnings of unconsolidated entities $ 1,649 $ 1,938 $ 3,389 $ 1,642
Select financial information for significant unconsolidated equity-method investees	Selected financial information for significant unconsolidated equity-method investees is as follows: As of June 30, Three Months Ended June 30, Six Months Ended June 30, Total Assets Members' Equity Revenues Net Income Revenues Net Income (Loss) 2015 WTLPG $ 825,236 $ 821,140 $ 21,762 $ 8,242 $ 43,916 $ 16,945 As of December 31, 2014 WTLPG $ 827,697 $ 818,546 $ 25,950 $ 10,071 $ 47,914 $ 20,601 Cardinal $ — $ — $ 16,914 $ 2,353 $ 35,343 $ (605 )

Derivative Instruments and He31

Derivative Instruments and Hedging Activities (Tables)	6 Months Ended
	Jun. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Effect of derivative instruments on the Consolidated Statement of Operations	Effect of Derivative Instruments on the Consolidated and Condensed Statement of Operations For the Three Months Ended June 30, 2015 and 2014 Location of Gain Recognized in Income on Derivatives Amount of Gain Recognized in Income on Derivatives 2015 2014 Derivatives not designated as hedging instruments: Interest rate swaption contracts Interest expense $ 1,120 $ 2,927 Total derivatives not designated as hedging instruments $ 1,120 $ 2,927 Effect of Derivative Instruments on the Consolidated and Condensed Statement of Operations For the Six Months Ended June 30, 2015 and 2014 Location of Gain Recognized in Income on Derivatives Amount of Gain Recognized in Income on Derivatives 2015 2014 Derivatives not designated as hedging instruments: Interest rate swaption contracts Interest expense $ 1,745 $ 2,927 Total derivatives not designated as hedging instruments $ 1,745 $ 2,927

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The fair value of the following items are required to be disclosed on a recurring basis subject to the requirements of ASC 820 at June 30, 2015 and December 31, 2014 : Fair Value Measurements at Reporting Date Using Quoted Prices in Active Markets for Identical Assets Significant Other Observable Inputs Significant Unobservable Inputs Description June 30, 2015 (Level 1) (Level 2) (Level 3) Assets Note receivable - Martin Energy Trading $ 15,844 $ — $ — $ 15,844 Total assets $ 15,844 $ — $ — $ 15,844 Liabilities 2021 Senior unsecured notes $ 395,029 $ — $ 395,029 $ — Total liabilities $ 395,029 $ — $ 395,029 $ — Fair Value Measurements at Reporting Date Using Quoted Prices in Active Markets for Identical Assets Significant Other Observable Inputs Significant Unobservable Inputs Description December 31, 2014 (Level 1) (Level 2) (Level 3) Assets Note receivable - Martin Energy Trading $ 15,852 $ — $ — $ 15,852 Total assets $ 15,852 $ — $ — $ 15,852 Liabilities 2021 Senior unsecured notes $ 385,077 $ — $ 385,077 $ — Total liabilities $ 385,077 $ — $ 385,077 $ —

Supplemental Balance Sheet In33

Supplemental Balance Sheet Information (Tables)	6 Months Ended
	Jun. 30, 2015
Balance Sheet Related Disclosures [Abstract]
Schedule of Other Assets	Components of "Other assets, net" were as follows: June 30, 2015 December 31, 2014 Customer contracts and relationships, net $ 61,209 $ 72,171 Other intangible assets 2,011 2,215 Other 8,426 7,079 $ 71,646 $ 81,465
Schedule of Other Accrued Liabilities	Components of "Other accrued liabilities" were as follows: June 30, 2015 December 31, 2014 Accrued interest $ 10,995 $ 10,996 Property and other taxes payable 5,727 7,524 Accrued payroll 3,483 3,125 Other 139 156 $ 20,344 $ 21,801

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2015
Debt Disclosure [Abstract]
Schedule of long-term debt	At June 30, 2015 and December 31, 2014 , long-term debt consisted of the following: June 30, December 31, $900,000 Revolving credit facility at variable interest rate (2.94% 1 weighted average at June 30, 2015), due March 2018 secured by substantially all of the Partnership’s assets, including, without limitation, inventory, accounts receivable, vessels, equipment, fixed assets and the interests in the Partnership’s operating subsidiaries and equity method investees, net of unamortized debt issuance costs of $7,584 and $8,656, respectively $ 442,416 $ 491,344 $400,000 Senior notes, 7.250% interest, net of unamortized debt issuance costs of $4,098 and $4,462, respectively, including unamortized premium of $1,841 and $2,005, respectively, issued $250,000 February 2013 and $150,000 April 2014, due February 2021, unsecured 397,743 397,543 Total long-term debt, net 840,159 888,887 Less current installments — — Long-term debt, net of current installments $ 840,159 $ 888,887 1 Interest rate fluctuates based on the LIBOR rate plus an applicable margin set on the date of each advance. The margin above LIBOR is set every three months. Indebtedness under the credit facility bears interest at LIBOR plus an applicable margin or the base prime rate plus an applicable margin. The applicable margin for revolving loans that are LIBOR loans ranges from 1.75% to 2.75% and the applicable margin for revolving loans that are base prime rate loans ranges from 0.75% to 1.75% . The applicable margin for existing LIBOR borrowings at June 30, 2015 is 2.75% . The credit facility contains various covenants which limit the Partnership’s ability to make certain investments and acquisitions; enter into certain agreements; incur indebtedness; sell assets; and make certain amendments to the Partnership's omnibus agreement with Martin Resource Management (the "Omnibus Agreement"). The Partnership is permitted to make quarterly distributions so long as no event of default exists.

Partners' Capital (Tables)

Partners' Capital (Tables)	6 Months Ended
	Jun. 30, 2015
Partners' Capital Notes [Abstract]
Reconciliation of net income to partners interest in net income	The following is a reconciliation of net income allocated to the general partner and limited partners for purposes of calculating net income attributable to limited partners per unit: Three Months Ended June 30, Six Months Ended June 30, Continuing operations: 2015 2014 2015 2014 Income from continuing operations $ 10,961 $ 324 $ 26,994 $ 12,708 Less general partner’s interest in net income: Distributions payable on behalf of IDRs 3,893 — 7,452 — Distributions payable on behalf of general partner interest 667 624 1,277 1,120 General partner interest in undistributed earnings (447 ) (616 ) (737 ) (865 ) Less income allocable to unvested restricted units 44 — 106 34 Limited partners’ interest in income from continuing operations $ 6,804 $ 316 $ 18,896 $ 12,419 Three Months Ended June 30, Six Months Ended June 30, Discontinued operations: 2015 2014 2015 2014 Income (loss) from discontinued operations $ — $ (1,292 ) $ 1,215 $ (1,881 ) Less general partner’s interest in net income: Distributions payable on behalf of IDRs — — 335 — Distributions payable on behalf of general partner interest — (142 ) 58 (166 ) General partner interest in undistributed earnings — 115 (34 ) 128 Less income allocable to unvested restricted units — (3 ) 5 (5 ) Limited partners’ interest in income (loss) from discontinued operations $ — $ (1,262 ) $ 851 $ (1,838 )

Related Party Transactions (Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2015
Related Party Transactions [Abstract]
The impact of Related Party Transactions	The impact of related party revenues from sales of products and services is reflected in the consolidated and condensed financial statements as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Revenues: Terminalling and storage $ 23,061 $ 18,743 $ 43,535 $ 36,753 Marine transportation 6,622 6,415 13,367 12,264 Product sales: Natural gas services 286 2,217 300 3,046 Sulfur services 970 1,268 2,044 2,223 Terminalling and storage 503 224 1,004 332 1,759 3,709 3,348 5,601 $ 31,442 $ 28,867 $ 60,250 $ 54,618 The impact of related party cost of products sold is reflected in the consolidated and condensed financial statements as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Cost of products sold: Natural gas services $ 6,810 $ 10,808 $ 13,728 $ 19,261 Sulfur services 3,618 4,452 7,242 9,317 Terminalling and storage 5,632 6,553 11,034 16,397 $ 16,060 $ 21,813 $ 32,004 $ 44,975 The impact of related party operating expenses is reflected in the consolidated and condensed financial statements as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Operating expenses: Marine transportation $ 8,038 $ 8,823 $ 16,598 $ 18,487 Natural gas services 1,992 798 4,155 1,404 Sulfur services 2,036 2,034 3,699 3,520 Terminalling and storage 6,849 7,593 14,863 14,076 $ 18,915 $ 19,248 $ 39,315 $ 37,487 The impact of related party selling, general and administrative expenses is reflected in the consolidated and condensed financial statements as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Selling, general and administrative: Marine transportation $ 8 $ 7 $ 16 $ 15 Natural gas services 1,238 1,146 2,401 2,104 Sulfur services 642 820 1,438 1,663 Terminalling and storage 542 343 1,149 728 Indirect overhead allocation, net of reimbursement 3,419 3,173 6,839 6,363 $ 5,849 $ 5,489 $ 11,843 $ 10,873

Business Segments (Tables)

Business Segments (Tables)	6 Months Ended
	Jun. 30, 2015
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment [Table Text Block]	Three Months Ended June 30, 2015 Operating Revenues Intersegment Revenues Eliminations Operating Revenues after Eliminations Depreciation and Amortization Operating Income (Loss) after Eliminations Capital Expenditures and Plant Turnaround Costs Terminalling and storage $ 69,287 $ (1,255 ) $ 68,032 $ 9,617 $ 5,298 $ 8,207 Natural gas services 114,350 — 114,350 8,373 9,260 5,395 Sulfur services 48,374 — 48,374 2,105 7,144 147 Marine transportation 20,886 (543 ) 20,343 2,590 2,428 502 Indirect selling, general and administrative — — — — (4,500 ) — Total $ 252,897 $ (1,798 ) $ 251,099 $ 22,685 $ 19,630 $ 14,251 Three Months Ended June 30, 2014 Operating Revenues Intersegment Revenues Eliminations Operating Revenues after Eliminations Depreciation and Amortization Operating Income (Loss) after Eliminations Capital Expenditures and Plant Turnaround Costs Terminalling and storage $ 86,917 $ (1,307 ) $ 85,610 $ 9,415 $ 8,365 $ 15,544 Natural gas services 232,986 — 232,986 293 7,106 74 Sulfur services 62,581 — 62,581 2,031 7,886 1,633 Marine transportation 23,282 (1,198 ) 22,084 2,473 (522 ) 4,258 Indirect selling, general and administrative — — — — (4,838 ) — Total $ 405,766 $ (2,505 ) $ 403,261 $ 14,212 $ 17,997 $ 21,509 Six Months Ended June 30, 2015 Operating Revenues Intersegment Revenues Eliminations Operating Revenues after Eliminations Depreciation and Amortization Operating Income (Loss) after Eliminations Capital Expenditures and Plant Turnaround Costs Terminalling and storage $ 139,321 $ (2,499 ) $ 136,822 $ 19,406 $ 12,985 $ 17,882 Natural gas services 277,140 — 277,140 16,775 18,147 14,109 Sulfur services 101,511 — 101,511 4,231 15,266 361 Marine transportation 42,832 (1,853 ) 40,979 4,990 7,244 1,196 Indirect selling, general and administrative — — — — (9,310 ) — Total $ 560,804 $ (4,352 ) $ 556,452 $ 45,402 $ 44,332 $ 33,548 Six Months Ended June 30, 2014 Operating Revenues Intersegment Revenues Eliminations Operating Revenues after Eliminations Depreciation and Amortization Operating Income (Loss) after Eliminations Capital Expenditures and Plant Turnaround Costs Terminalling and storage $ 174,214 $ (2,530 ) $ 171,684 $ 18,390 $ 16,676 $ 33,306 Natural gas services 554,400 — 554,400 413 17,161 574 Sulfur services 116,788 — 116,788 4,014 15,954 3,081 Marine transportation 47,396 (2,198 ) 45,198 5,003 2,440 8,186 Indirect selling, general and administrative — — — — (9,735 ) — Total $ 892,798 $ (4,728 ) $ 888,070 $ 27,820 $ 42,496 $ 45,147
Assets by segment	The Partnership's assets by reportable segment as of June 30, 2015 and December 31, 2014 , are as follows: June 30, 2015 December 31, 2014 Total assets: Terminalling and storage $ 435,347 $ 446,313 Natural gas services 693,187 795,462 Sulfur services 136,537 145,852 Marine transportation 146,439 153,174 Total assets $ 1,411,510 $ 1,540,801

Unit Based Awards (Tables)

Unit Based Awards (Tables)	6 Months Ended
	Jun. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of compensation costs related to unit based plan	Amounts recognized in selling, general, and administrative expense in the consolidated and condensed financial statements with respect to these plans are as follows: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Employees $ 341 $ 156 $ 652 $ 284 Non-employee directors 10 52 98 103 Total unit-based compensation expense $ 351 $ 208 $ 750 $ 387
Summary of restricted unit activity	A summary of the restricted unit activity for the six months ended June 30, 2015 is provided below: Number of Units Weighted Average Grant-Date Fair Value Per Unit Non-vested, beginning of period 63,824 $ 31.57 Granted 91,950 $ 28.69 Vested (3,550 ) $ 34.56 Forfeited (1,000 ) $ 31.06 Non-Vested, end of period 151,224 $ 29.75 Aggregate intrinsic value, end of period $ 4,620
Summary of aggregate intrinsic value and fair value of units vested	A summary of the restricted units’ aggregate intrinsic value (market value at vesting date) and fair value of units vested (market value at date of grant) during the six months ended June 30, 2015 and 2014 is provided below: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Aggregate intrinsic value of units vested $ — $ — $ 110 $ 249 Fair value of units vested $ — $ — $ 113 $ 247

General (Details)

General (Details)	6 Months Ended
	Jun. 30, 2015segment
Accounting Policies [Abstract]
Number of primary business lines	4

New Accounting Pronouncements (

New Accounting Pronouncements (Details)	Dec. 31, 2014USD ($)
New Accounting Pronouncement, Early Adoption, Effect [Member]
New Accounting Pronouncement, Early Adoption [Line Items]
Deferred financing cost, net	$ 13,118

Acquisitions (Cardinal Gas Stor

Acquisitions (Cardinal Gas Storage Partners LLC) (Details) - USD ($) $ in Thousands	Aug. 29, 2014	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Aug. 28, 2014
Business Acquisition [Line Items]
Revenue		$ 251,099	$ 403,261	$ 556,452	$ 888,070
Net income (loss)		10,961	$ (968)	28,209	$ 10,827
Cardinal Gas Storage Partners LLC [Member]
Business Acquisition [Line Items]
Additional voting interests acquired	57.80%
Cash consideration of acquisition	$ 120,973
Ownership percentage by parent						42.20%
Reduced carrying value of existing investment	$ 30,102
Weighted average useful life	5 years 1 month 12 days
Revenue		16,181		32,668
Net income (loss)		$ 3,062		$ 6,090

Acquisitions (Schedule of Purch

Acquisitions (Schedule of Purchase Price) (Details) - Cardinal Gas Storage Partners LLC [Member] $ in Thousands	Aug. 29, 2014USD ($)
Business Acquisition [Line Items]
Cash payment for 57.8% interest in Cardinal	$ 120,973
Fair value of the Partnership's previously owned 42.2% interest in Cardinal	87,613
Total	$ 208,586

Acquisitions (Schedule of Asset

Acquisitions (Schedule of Assets and Liabilities Assumed) (Details) - USD ($) $ in Thousands	Aug. 29, 2014	May. 31, 2014
Cardinal Gas Storage Partners LLC [Member]
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net [Abstract]
Restricted cash	$ 17,566
Other current assets	9,385
Property, plant and equipment	390,895
Intangible and other assets	80,135
Project level finance debt	(282,087)
Other current liabilities	(6,713)
Other non-current liabilities	(595)
Total	$ 208,586
Martin Resource Management [Member]
Business Combination, Recognized Identifiable Assets Acquired, Goodwill, and Liabilities Assumed, Net [Abstract]
Property, plant and equipment		$ 2,453
Current liabilities		(13)
Total		$ 2,440

Acquisitions (Natural Gas Liqui

Acquisitions (Natural Gas Liquids Storage Assets) (Details) - USD ($) $ in Thousands	May. 31, 2014	Jun. 30, 2015	Jun. 30, 2014
Business Acquisition [Line Items]
Excess of the purchase price over the carrying value of the assets		$ 0	$ 5,397
Martin Resource Management [Member]
Business Acquisition [Line Items]
Purchase price of acquisition	$ 7,388
Partners' Capital [Member] | Martin Resource Management [Member]
Business Acquisition [Line Items]
Excess of the purchase price over the carrying value of the assets	$ 4,948
Excess of the purchase price over the carrying value of the assets, percentage	3.00%

Acquisitions (West Texas LPG Pi

Acquisitions (West Texas LPG Pipeline Limited Partnership) (Details) $ in Thousands	May. 14, 2014USD ($)mi	May. 14, 2014USD ($)mi	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)
Business Acquisition [Line Items]
Payments to acquire unconsolidated entities			$ 0	$ 134,413
West Texas LPG Pipeline L.P. [Member]
Business Acquisition [Line Items]
Ownership percentage	20.00%	20.00%
Length of common-carrier pipeline system | mi	2,300	2,300
West Texas LPG Pipeline L.P. [Member] | Limited Partner [Member]
Business Acquisition [Line Items]
Ownership percentage	19.80%	19.80%
West Texas LPG Pipeline L.P. [Member] | General Partner [Member]
Business Acquisition [Line Items]
Ownership percentage	0.20%	0.20%
West Texas LPG Pipeline L.P. [Member] | ONEOK Partners, L.P. [Member]
Business Acquisition [Line Items]
Ownership percentage by parent	80.00%	80.00%
Atlas Holdings [Member]
Business Acquisition [Line Items]
Payments to acquire unconsolidated entities	$ 134,400	$ 134,400
Post-closing working capital adjustment	$ 501	$ 501

Acquisitions (Schedule of Pro F

Acquisitions (Schedule of Pro Forma Consolidated Results of Operations) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues:
As reported	$ 251,099	$ 403,261	$ 556,452	$ 888,070
Net income (loss) from continuing operations attributable to limited partners:
As reported	6,804	316	18,896	12,419
Net loss from discontinued operations attributable to limited partners:
As reported	$ 0	$ (1,262)	$ 851	$ (1,838)
Net income (loss) from continuing operations per unit attributable to limited partners - basic:
As reported	$ 0.19	$ 0.01	$ 0.54	$ 0.45
Net loss from discontinued operations per unit attributable to limited partners - basic:
As reported	0	(0.04)	0.02	(0.07)
Net income (loss) from continuing operations per unit attributable to limited partners - diluted:
As reported	0.19	0.01	0.54	0.45
Net loss from discontinued operations per unit attributable to limited partners - diluted:
As reported	$ 0	$ (0.04)	$ 0.02	$ (0.07)
Limited Partner [Member] | Cardinal and West Texas Pipeline Limited Partnership [Member]
Revenues:
As reported		$ 403,261		$ 888,070
Pro forma		420,175		923,413
Net income (loss) from continuing operations attributable to limited partners:
As reported		316		12,419
Pro forma		(7,098)		(4,216)
Net loss from discontinued operations attributable to limited partners:
As reported		(1,262)		(1,838)
Pro forma		$ (1,262)		$ (1,838)
Net income (loss) from continuing operations per unit attributable to limited partners - basic:
As reported		$ 0.01		$ 0.45
Pro forma		(0.25)		(0.15)
Net loss from discontinued operations per unit attributable to limited partners - basic:
As reported		(0.04)		(0.07)
Pro forma		(0.04)		(0.07)
Net income (loss) from continuing operations per unit attributable to limited partners - diluted:
As reported		0.01		0.45
Pro forma		(0.25)		(0.15)
Net loss from discontinued operations per unit attributable to limited partners - diluted:
As reported		(0.04)		(0.07)
Pro forma		$ (0.04)		$ (0.07)

Discontinued operations and d47

Discontinued operations and divestitures (Details) - Floating Storage Assets $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Feb. 12, 2015bargebbl
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Number of pressure barges disposed of | barge					6
Volume of pressure barges disposed of | bbl					16,101
Intercompany revenues	$ 0	$ 0	$ 0	$ 5,273

Discontinued operations and d48

Discontinued operations and divestitures (Operating Results) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total costs and expenses and other, net, excluding depreciation and amortization	$ 231,302	$ 385,363	$ 511,943	$ 845,628
Depreciation and amortization	22,685	14,212	45,402	27,820
Other operating loss	(167)	99	(177)	54
Income (loss) from discontinued operations, net of income taxes	0	(1,292)	1,215	(1,881)
Floating Storage Assets
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total revenues from third parties	0	15,683	791	33,175
Total costs and expenses and other, net, excluding depreciation and amortization	0	16,592	1,038	34,290
Depreciation and amortization	0	383	0	766
Other operating loss	0	0	1,462	0
Income (loss) from discontinued operations before income taxes	0	(1,292)	1,215	(1,881)
Income tax expense	0	0	0	0
Income (loss) from discontinued operations, net of income taxes	$ 0	$ (1,292)	$ 1,215	$ (1,881)

Inventories (Details)

Inventories (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Inventory Disclosure [Abstract]
Natural gas liquids	$ 22,658	$ 27,820
Sulfur	11,817	12,231
Sulfur based products	13,981	16,280
Lubricants	24,923	29,096
Other	3,184	3,291
Inventories	$ 76,563	$ 88,718

Investments in Unconsolidated50

Investments in Unconsolidated Entities and Joint Ventures (Details) $ in Thousands	Aug. 31, 2014USD ($)	Aug. 29, 2014	May. 14, 2014USD ($)mi	May. 14, 2014USD ($)mi	Mar. 31, 2013USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Dec. 31, 2014USD ($)	Aug. 28, 2014
Schedule of Equity Method Investments [Line Items]
Amount of cash to acquire outstanding interest						$ 0	$ 134,413
Note receivable						15,000		$ 15,000
Partnership's interest in cash of the unconsolidated equity-method investees						$ 2,610		$ 10
West Texas LPG Pipeline L.P. [Member]
Schedule of Equity Method Investments [Line Items]
Unconsolidated interest ownership			20.00%	20.00%
Length of common-carrier pipeline system | mi			2,300	2,300
Martin Energy Trading LLC [Member]
Schedule of Equity Method Investments [Line Items]
Unconsolidated interest ownership					100.00%
Proceeds from sale of equity method investment					$ 15,000
Annual interest rate of note receivable	15.00%
Limited Partner [Member] | West Texas LPG Pipeline L.P. [Member]
Schedule of Equity Method Investments [Line Items]
Unconsolidated interest ownership			19.80%	19.80%
General Partner [Member] | West Texas LPG Pipeline L.P. [Member]
Schedule of Equity Method Investments [Line Items]
Unconsolidated interest ownership			0.20%	0.20%
Notes Receivable [Member] | Martin Energy Trading LLC [Member]
Schedule of Equity Method Investments [Line Items]
Note receivable	$ 15,000
Atlas Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Amount of cash to acquire outstanding interest			$ 134,400	$ 134,400
Post-closing working capital adjustment			$ 501	$ 501
Cardinal Gas Storage Partners LLC [Member]
Schedule of Equity Method Investments [Line Items]
Additional voting interests acquired		57.80%
Remaining ownership percentage in investment									42.20%
ONEOK Partners, L.P. [Member] | West Texas LPG Pipeline L.P. [Member]
Schedule of Equity Method Investments [Line Items]
Remaining ownership percentage in investment			80.00%	80.00%

Investments in Unconsolidated51

Investments in Unconsolidated Entities and Joint Ventures (Components of Investment in Unconsolidated Entities) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated entities	$ 133,495		$ 133,495		$ 134,506
Equity in earnings of unconsolidated entities	1,649	$ 1,938	3,389	$ 1,642
West Texas LPG Pipeline L.P. [Member]
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated entities	133,495		133,495		$ 134,506
Equity in earnings of unconsolidated entities	1,649	769	3,389	769
Cardinal Gas Storage Partners LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated entities	0	608	0	(243)
Martin Energy Trading LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated entities	$ 0	$ 561	$ 0	$ 1,116

Investments in Unconsolidated52

Investments in Unconsolidated Entities and Joint Ventures (Selected Financial Information for Equity Method Investees) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
West Texas LPG Pipeline L.P. [Member]
Schedule of Equity Method Investments [Line Items]
Total Assets	$ 825,236		$ 825,236		$ 827,697
Members' Equity	821,140		821,140		818,546
Revenues	21,762	$ 25,950	43,916	$ 47,914
Net Income (Loss)	$ 8,242	10,071	$ 16,945	20,601
Cardinal Gas Storage Partners LLC [Member]
Schedule of Equity Method Investments [Line Items]
Total Assets					0
Members' Equity					$ 0
Revenues		16,914		35,343
Net Income (Loss)		$ 2,353		$ (605)

Derivative Instruments and He53

Derivative Instruments and Hedging Activities (Details) - Jun. 30, 2015 - Interest Rate Swap [Member] - USD ($) $ in Thousands	Total	Total
Derivatives, Fair Value [Line Items]
Premiums received	$ 1,120	$ 1,745
Interest Expense [Member]
Derivatives, Fair Value [Line Items]
Premiums received	$ 1,120	$ 1,745

Derivative Instruments and He54

Derivative Instruments and Hedging Activities (Statement of Operations Derivatives) (Details) - Not Designated as Hedging Instrument [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain or (loss) recognized in income on derivatives	$ 1,120	$ 2,927	$ 1,745	$ 2,927
Interest Rate Contract [Member] | Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain or (loss) recognized in income on derivatives	$ 1,120	$ 2,927	$ 1,745	$ 2,927

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Note receivable - Martin Energy Trading	$ 15,844	$ 15,852
Total assets	15,844	15,852
Total liabilities	395,029	385,077
2021 Senior unsecured notes [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Senior unsecured notes	395,029	385,077
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Note receivable - Martin Energy Trading	0	0
Total assets	0	0
Total liabilities	0	0
Level 1 [Member] | 2021 Senior unsecured notes [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Senior unsecured notes	0	0
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Note receivable - Martin Energy Trading	0	0
Total assets	0	0
Total liabilities	395,029	385,077
Level 2 [Member] | 2021 Senior unsecured notes [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Senior unsecured notes	395,029	385,077
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Note receivable - Martin Energy Trading	15,844	15,852
Total assets	15,844	15,852
Total liabilities	0	0
Level 3 [Member] | 2021 Senior unsecured notes [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Senior unsecured notes	$ 0	$ 0

Supplemental Balance Sheet In56

Supplemental Balance Sheet Information (Other Assets) (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Balance Sheet Related Disclosures [Abstract]
Customer contracts and relationships, net	$ 61,209	$ 72,171
Other intangible assets	2,011	2,215
Other	8,426	7,079
Other assets, net	71,646	81,465
Accumulated amortization of intangible assets	$ 23,719	$ 12,125

Supplemental Balance Sheet In57

Supplemental Balance Sheet Information (Other Accrued Liabilities) (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Balance Sheet Related Disclosures [Abstract]
Accrued interest	$ 10,995	$ 10,996
Property and other taxes payable	5,727	7,524
Accrued payroll	3,483	3,125
Other	139	156
Total Other Accrued Liabilities	$ 20,344	$ 21,801

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Apr. 30, 2014	Feb. 28, 2013
Debt Instrument [Line Items]
Total long-term debt, net	$ 840,159,000		$ 840,159,000		$ 888,887,000
Less current installments	0		0		0
Long-term debt, net of current installments	840,159,000		840,159,000		888,887,000
Cash paid for interest	3,015,000	$ 6,735,000	21,104,000	$ 18,424,000
Capitalized interest	570,000	$ 335,000	1,095,000	$ 723,000
Revolving Loan Facility [Member]
Debt Instrument [Line Items]
Total long-term debt, net	442,416,000		442,416,000		491,344,000
Face amount	900,000,000		900,000,000
Unamortized debt issuance costs	$ 7,584,000		$ 7,584,000		8,656,000
Weighted average interest rate	2.94%		2.94%
Revolving Loan Facility [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Applicable margins			2.75%
Revolving Loan Facility [Member] | LIBOR [Member] | Minimum [Member]
Debt Instrument [Line Items]
Applicable margins			1.75%
Revolving Loan Facility [Member] | LIBOR [Member] | Maximum [Member]
Debt Instrument [Line Items]
Applicable margins			2.75%
Revolving Loan Facility [Member] | Prime Rate [Member] | Minimum [Member]
Debt Instrument [Line Items]
Applicable margins			0.75%
Revolving Loan Facility [Member] | Prime Rate [Member] | Maximum [Member]
Debt Instrument [Line Items]
Applicable margins			1.75%
Senior Notes [Member] | Senior Notes 7.250% [Member]
Debt Instrument [Line Items]
Total long-term debt, net	$ 397,743,000		$ 397,743,000		397,543,000
Face amount	$ 400,000,000		$ 400,000,000			$ 150,000,000	$ 250,000,000
Stated interest rate	7.25%		7.25%
Unamortized debt issuance costs	$ 4,098,000		$ 4,098,000		4,462,000
Unamortized premium	$ 1,841,000		$ 1,841,000		$ 2,005,000

Partners' Capital (Details)

Partners' Capital (Details) - shares	1 Months Ended	6 Months Ended
	Mar. 31, 2014	Jun. 30, 2015
Limited Partners' Capital Account [Line Items]
Common limited partner units		35,456,862
Ownership percentage		98.00%
General partner interest percentage	2.00%	2.00%
Martin Resource Management [Member]
Limited Partners' Capital Account [Line Items]
Voting interest		51.00%
Martin Resource Management [Member]
Limited Partners' Capital Account [Line Items]
Common limited partner units		6,264,532
Ownership percentage		17.70%
General partner interest percentage		2.00%
Voting interest		17.70%

Partners' Capital (Issuance of

Partners' Capital (Issuance of Common Units) (Details) - USD ($) $ in Thousands	1 Months Ended	6 Months Ended
	Mar. 31, 2014	Jun. 30, 2015	Jun. 30, 2014
Subsidiary, Sale of Stock [Line Items]
Proceeds from the public offering		$ 0	$ 17,798
Compensation expense		$ 228	$ 382
Common units sold in private equity sale		0	417,156
General partner contribution to maintain GP interest		$ 55	$ 3,407
General partner interest percentage	2.00%	2.00%
General Partner [Member]
Subsidiary, Sale of Stock [Line Items]
General partner contribution to maintain GP interest		$ 0	$ 356

Partners' Capital (Incentive Di

Partners' Capital (Incentive Distribution Rights and Distributions of Available Cash) (Details) - USD ($)	1 Months Ended	3 Months Ended		6 Months Ended
	Mar. 31, 2014	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	May. 05, 2014	Oct. 02, 2012
Limited Partners' Capital Account [Line Items]
General partner interest percentage	2.00%			2.00%
Distribution period				45 days
Martin Midstream GP LLC [Member]
Limited Partners' Capital Account [Line Items]
General partner interest percentage				2.00%
Incentive distribution foregone						$ 3,000,000	$ 18,000,000
Incentive distribution		$ 3,893,000	$ 0	$ 7,631,000	$ 0
Martin Midstream GP LLC [Member] | Target Level 1 [Member]
Limited Partners' Capital Account [Line Items]
Target cash distribution, percent		2.00%		2.00%
Target cash distribution (in dollars per share)		$ 0.55		$ 0.55
Martin Midstream GP LLC [Member] | Target Level 2 [Member]
Limited Partners' Capital Account [Line Items]
Target cash distribution, percent		15.00%		15.00%
Target cash distribution (in dollars per share)		$ 0.625		$ 0.625
Martin Midstream GP LLC [Member] | Target Level 3 [Member]
Limited Partners' Capital Account [Line Items]
Target cash distribution, percent		25.00%		25.00%
Target cash distribution (in dollars per share)		$ 0.75		$ 0.75
Martin Midstream GP LLC [Member] | Target Level 4 [Member]
Limited Partners' Capital Account [Line Items]
Target cash distribution, percent		50.00%		50.00%

Partners' Capital (Reconciliati

Partners' Capital (Reconciliation of Net Income) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Reconciliation of Net Income from Continuing and Discontinued Operations [Line Items]
Income (loss) from operations	$ 10,961	$ (968)	$ 28,209	$ 10,827
Less general partner’s interest in net income:
Less income allocable to unvested restricted units	44	(3)	111	29
Limited partners' interest in net income (loss)	$ 6,804	$ (946)	$ 19,747	$ 10,581
Weighted average limited partner units - basic	35,307,638	28,923,513	35,315,989	27,757,304
Increase in units outstanding due to the dilutive effect of restricted units granted (in units)	68,499	34,233	56,115	33,350
Continuing Operations [Member]
Reconciliation of Net Income from Continuing and Discontinued Operations [Line Items]
Income (loss) from operations	$ 10,961	$ 324	$ 26,994	$ 12,708
Less general partner’s interest in net income:
Distributions payable on behalf of IDRs	3,893	0	7,452	0
Distributions payable on behalf of general partner interest	667	624	1,277	1,120
General partner interest in undistributed earnings	(447)	(616)	(737)	(865)
Less income allocable to unvested restricted units	44	0	106	34
Limited partners' interest in net income (loss)	6,804	316	18,896	12,419
Discontinued Operations [Member]
Reconciliation of Net Income from Continuing and Discontinued Operations [Line Items]
Income (loss) from operations	0	(1,292)	1,215	(1,881)
Less general partner’s interest in net income:
Distributions payable on behalf of IDRs	0	0	335	0
Distributions payable on behalf of general partner interest	0	(142)	58	(166)
General partner interest in undistributed earnings	0	115	(34)	128
Less income allocable to unvested restricted units	0	(3)	5	(5)
Limited partners' interest in net income (loss)	$ 0	$ (1,262)	$ 851	$ (1,838)

Related Party Transactions (Nar

Related Party Transactions (Narrative) (Details) - USD ($) $ in Thousands	Aug. 31, 2014	Mar. 31, 2014	Mar. 31, 2013	Jun. 30, 2015	Jun. 30, 2015	Dec. 31, 2014
Related Party Transaction [Line Items]
General partner interest percentage		2.00%			2.00%
Note receivable				$ 15,000	$ 15,000	$ 15,000
Martin Energy Trading LLC [Member]
Related Party Transaction [Line Items]
Ownership percentage			100.00%
Proceeds from sale of equity method investment			$ 15,000
Annual interest rate of note receivable	15.00%
Notes Receivable [Member] | Martin Energy Trading LLC [Member]
Related Party Transaction [Line Items]
Note receivable	$ 15,000
Interest Expense, Net [Member] | Martin Energy Trading LLC [Member]
Related Party Transaction [Line Items]
Interest income				$ 561	$ 1,116
Martin Resource Management [Member]
Related Party Transaction [Line Items]
Number of shares owned (in units)				6,264,532	6,264,532
Ownership percentage				17.70%	17.70%
General partner interest percentage					2.00%
Martin Resource Management [Member] | MMGP Holdings, LLC [Member]
Related Party Transaction [Line Items]
General partner interest percentage					51.00%

Related Party Transactions (Omn

Related Party Transactions (Omnibus Agreement) (Details) - Omnibus Agreement [Member] - Martin Resource Management [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Related Party Transaction [Line Items]
Noncompete restriction threshold	$ 5,000		$ 5,000
Noncompete restriction ownership option opportunity threshold minimum	5,000		5,000
Noncompete restriction ownership option opportunity threshold minimum with equity limitation	$ 5,000		$ 5,000
Equity limitation on ownership restriction percentage	20.00%		20.00%
Approved annual reimbursements for indirect expenses			$ 13,679
Indirect expenses reimbursed	$ 3,419	$ 3,134	$ 6,839	$ 6,268

Related Party Transactions (Mot

Related Party Transactions (Motor Carrier Agreement) (Details) - Motor Carrier Agreement [Member] - Martin Resource Management [Member]	6 Months Ended
	Jun. 30, 2015
Related Party Transaction [Line Items]
Automatic consecutive term renewal period	1 year
Termination written notice, minimum	30 days
Partnership notice period to terminate agreement	90 days

Related Party Transactions (Mar

Related Party Transactions (Marine Agreements) (Details) - Marine Transportation Agreement [Member] - Martin Resource Management [Member]	6 Months Ended
	Jun. 30, 2015
Related Party Transaction [Line Items]
Automatic consecutive term renewal period	1 year
Termination written notice, minimum	60 days

Related Party Transactions (Oth

Related Party Transactions (Other Agreements) (Details) - Jun. 30, 2015 - Martin Resource Management [Member] - bbl	Total
Cross Tolling Agreement [Member]
Related Party Transaction [Line Items]
Production minimum per day (in bbl)	6,500
Annual escalation benchmark	3.00%
Sulfuric Acid Sales Agency Agreement [Member]
Related Party Transaction [Line Items]
Partnership notice period to terminate agreement	180 days

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues:
Terminalling and storage	$ 23,061	$ 18,743	$ 43,535	$ 36,753
Marine transportation	6,622	6,415	13,367	12,264
Product sales:
Product Sales Related Party	1,759	3,709	3,348	5,601
Cost of products sold:
Natural gas services	6,810	10,808	13,728	19,261
Sulfur services	3,618	4,452	7,242	9,317
Terminalling and storage			11,034	16,397
Cost of products sold	5,632	6,553
Operating expenses:
Operating expenses	18,915	19,248	39,315	37,487
Related Party [Member]
Product sales:
Product Sales Related Party	1,759	3,709	3,348	5,601
Revenue from Related Parties	31,442	28,867	60,250	54,618
Cost of products sold:
Natural gas services	6,810	10,808	13,728	19,261
Sulfur services	3,618	4,452	7,242	9,317
Cost of products sold	16,060	21,813	32,004	44,975
Operating expenses:
Operating expenses	18,915	19,248	39,315	37,487
Selling, general and administrative:
Selling, general and administrative	5,849	5,489	11,843	10,873
Related Party [Member] | Terminalling and storage [Member]
Revenues:
Terminalling and storage	23,061	18,743	43,535	36,753
Product sales:
Product Sales Related Party	503	224	1,004	332
Cost of products sold:
Terminalling and storage	5,632	6,553	11,034	16,397
Operating expenses:
Operating expenses	6,849	7,593	14,863	14,076
Selling, general and administrative:
Selling, general and administrative	542	343	1,149	728
Related Party [Member] | Marine transportation [Member]
Revenues:
Marine transportation	6,622	6,415	13,367	12,264
Operating expenses:
Operating expenses	8,038	8,823	16,598	18,487
Selling, general and administrative:
Selling, general and administrative	8	7	16	15
Related Party [Member] | Natural gas services [Member]
Product sales:
Product Sales Related Party	286	2,217	300	3,046
Operating expenses:
Operating expenses	1,992	798	4,155	1,404
Selling, general and administrative:
Selling, general and administrative	1,238	1,146	2,401	2,104
Related Party [Member] | Sulfur services [Member]
Product sales:
Product Sales Related Party	970	1,268	2,044	2,223
Operating expenses:
Operating expenses	2,036	2,034	3,699	3,520
Selling, general and administrative:
Selling, general and administrative	642	820	1,438	1,663
Related Party [Member] | Indirect overhead allocation, net of reimbursement [Member]
Selling, general and administrative:
Selling, general and administrative	$ 3,419	$ 3,173	$ 6,839	$ 6,363

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
State and Local Jurisdiction [Member] | Texas [Member]
Income Tax Contingency [Line Items]
State income taxes	$ 314	$ 354	$ 614	$ 654

Business Segments (Details)

Business Segments (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)segment	Jun. 30, 2014USD ($)	Dec. 31, 2014USD ($)
Segment Reporting [Abstract]
Number of Reportable Segments | segment			4
Segment Reporting Information [Line Items]
Operating Revenues	$ 252,897	$ 405,766	$ 560,804	$ 892,798
Intersegment Revenues Eliminations	(1,798)	(2,505)	(4,352)	(4,728)
Total revenues	251,099	403,261	556,452	888,070
Depreciation and amortization	22,685	14,212	45,402	27,820
Operating Income (Loss) after Eliminations	19,630	17,997	44,332	42,496
Capital Expenditures and Plant Turnaround Costs	14,251	21,509	33,548	45,147
Total assets:
Total assets	1,411,510		1,411,510		$ 1,540,801
Terminalling and storage [Member]
Segment Reporting Information [Line Items]
Operating Revenues	69,287	86,917	139,321	174,214
Intersegment Revenues Eliminations	(1,255)	(1,307)	(2,499)	(2,530)
Total revenues	68,032	85,610	136,822	171,684
Depreciation and amortization	9,617	9,415	19,406	18,390
Operating Income (Loss) after Eliminations	5,298	8,365	12,985	16,676
Capital Expenditures and Plant Turnaround Costs	8,207	15,544	17,882	33,306
Total assets:
Total assets	435,347		435,347		446,313
Natural gas services [Member]
Segment Reporting Information [Line Items]
Operating Revenues	114,350	232,986	277,140	554,400
Intersegment Revenues Eliminations	0	0	0	0
Total revenues	114,350	232,986	277,140	554,400
Depreciation and amortization	8,373	293	16,775	413
Operating Income (Loss) after Eliminations	9,260	7,106	18,147	17,161
Capital Expenditures and Plant Turnaround Costs	5,395	74	14,109	574
Total assets:
Total assets	693,187		693,187		795,462
Sulfur services [Member]
Segment Reporting Information [Line Items]
Operating Revenues	48,374	62,581	101,511	116,788
Intersegment Revenues Eliminations	0	0	0	0
Total revenues	48,374	62,581	101,511	116,788
Depreciation and amortization	2,105	2,031	4,231	4,014
Operating Income (Loss) after Eliminations	7,144	7,886	15,266	15,954
Capital Expenditures and Plant Turnaround Costs	147	1,633	361	3,081
Total assets:
Total assets	136,537		136,537		145,852
Marine transportation [Member]
Segment Reporting Information [Line Items]
Operating Revenues	20,886	23,282	42,832	47,396
Intersegment Revenues Eliminations	(543)	(1,198)	(1,853)	(2,198)
Total revenues	20,343	22,084	40,979	45,198
Depreciation and amortization	2,590	2,473	4,990	5,003
Operating Income (Loss) after Eliminations	2,428	(522)	7,244	2,440
Capital Expenditures and Plant Turnaround Costs	502	4,258	1,196	8,186
Total assets:
Total assets	146,439		146,439		$ 153,174
Indirect selling, general and administrative [Member]
Segment Reporting Information [Line Items]
Operating Revenues	0	0	0	0
Intersegment Revenues Eliminations	0	0	0	0
Total revenues	0	0	0	0
Depreciation and amortization	0	0	0	0
Operating Income (Loss) after Eliminations	(4,500)	(4,838)	(9,310)	(9,735)
Capital Expenditures and Plant Turnaround Costs	$ 0	$ 0	$ 0	$ 0

Unit Based Awards (Schedule of

Unit Based Awards (Schedule of Compensation Costs) (Details) - Selling, General and Administrative Expenses [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total unit-based compensation expense	$ 351	$ 208	$ 750	$ 387
Employees [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total unit-based compensation expense	341	156	652	284
Non-employee Directors [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total unit-based compensation expense	$ 10	$ 52	$ 98	$ 103

Unit Based Awards (Details)

Unit Based Awards (Details) $ in Thousands	1 Months Ended	6 Months Ended
	Mar. 31, 2014	Jun. 30, 2015USD ($)plan_componentshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of plan components | plan_component		2
Number of shares authorized		725,000
General partner capital contributions | $		$ 55
General partner interest percentage	2.00%	2.00%
Unit Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized		483,333
Restricted Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized		241,667
Unrecognized compensation cost related to non-vested restricted units | $		$ 2,682
Weighted average period for recognition		1 year 10 months 14 days
Restricted Units | Non-employee Directors [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period		4 years
Restricted Units | Employees [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period		3 years

Unit Based Awards (Restricted U

Unit Based Awards (Restricted Unit Activity) (Details) - Jun. 30, 2015 - Restricted Units - $ / shares	Total
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Non-vested, beginning of period, Number of Units	63,824
Granted, Number of Units	91,950
Vested, Number of Units	(3,550)
Forfeited, Number of Units	(1,000)
Non-vested, end of period, Number of Units	151,224
Non-vested, beginning of period, Weighted Average Grant-Date Fair Value Per Unit	$ 31.57
Granted, Weighted Average Grant-Date Fair Value Per Unit	28.69
Vested, Weighted Average Grant-Date Fair Value Per Unit	34.56
Forfeited, Weighted Average Grant-Date Fair Value Per Unit	31.06
Non-vested, end of period, Weighted Average Grant-Date Fair Value Per Unit	29.75
Aggregate intrinsic value, end of period	$ 4,620,000

Unit Based Awards (Intrinsic an

Unit Based Awards (Intrinsic and Fair Value) (Details) - Restricted Units - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Aggregate intrinsic value of units vested	$ 0	$ 0	$ 110	$ 249
Fair value of units vested	$ 0	$ 0	$ 113	$ 247

Commitments and Contingencies (

Commitments and Contingencies (Details) - USD ($) $ in Thousands	Oct. 02, 2012	Jun. 30, 2015	Jun. 30, 2015
Martin Resource Management [Member]
Loss Contingencies [Line Items]
Quarterly purchase price reimbursement for non compliance	$ 750	$ 750	$ 750
Maximum purchase price reimbursement for non compliance			4,500
Property Work Required Under Lease Agreement [Member]
Loss Contingencies [Line Items]
Property work to be completed		$ 1,600	$ 1,600

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Thousands	Jul. 23, 2015	Jun. 30, 2015	Jun. 30, 2014	Jul. 02, 2015
Subsequent Event [Line Items]
Distribution to general partner		$ 66,577	$ 43,145
General Partner [Member]
Subsequent Event [Line Items]
Distribution to general partner		$ 8,965	$ 953
Subsequent Event [Member]
Subsequent Event [Line Items]
Dividends declared	$ 0.8125
Estimated annualized dividends	$ 3.25
Subsequent Event [Member] | General Partner [Member]
Subsequent Event [Line Items]
Distribution to general partner	$ 4,560
Base general partner distribution	667
Incentive distribution	$ 3,893
Interest Rate Swap [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Derivative, notional amount				$ 200,000

Uncategorized Items - mmlp-2015

Label	Element	Value
Income (Loss) from Continuing Operations Attributable to Parent	us-gaap_IncomeLossFromContinuingOperations	$ 10,961
Income (Loss) from Continuing Operations Attributable to Parent	us-gaap_IncomeLossFromContinuingOperations	$ 324