Martin Midstream Partners (MMLP) 10-Q 24 Oct 18 2018 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2018	Oct. 24, 2018
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	Accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Document Type	10-Q
Document Period End Date	Sep. 30, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding (in shares)		39,036,237

CONSOLIDATED AND CONDENSED BALA

CONSOLIDATED AND CONDENSED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Assets
Cash	$ 3,186	$ 27
Accounts and other receivables, less allowance for doubtful accounts of $347 and $314, respectively	72,280	107,242
Product exchange receivables	185	29
Inventories (Note 6)	134,059	97,252
Due from affiliates	22,933	23,668
Other current assets	4,921	4,866
Assets held for sale (Note 4)	6,152	9,579
Total current assets	243,716	242,663
Property, plant and equipment, at cost	1,279,365	1,253,065
Accumulated depreciation	(465,079)	(421,137)
Property, plant and equipment, net	814,286	831,928
Goodwill	17,296	17,296
Investment in WTLPG (Note 7)	0	128,810
Other assets, net (Note 9)	25,751	32,801
Total assets	1,101,049	1,253,498
Liabilities and Partners’ Capital
Trade and other accounts payable	71,176	92,567
Product exchange payables	9,647	11,751
Due to affiliates	3,651	3,168
Income taxes payable	448	510
Fair value of derivatives (Note 10)	2,968	72
Other accrued liabilities (Note 9)	18,876	26,340
Total current liabilities	106,766	134,408
Long-term debt, net (Note 8)	698,680	812,632
Other long-term obligations	10,718	8,217
Total liabilities	816,164	955,257
Commitments and contingencies (Note 15)
Partners’ capital (Note 11)	284,885	298,241
Total partners’ capital	284,885	298,241
Total liabilities and partners' capital	$ 1,101,049	$ 1,253,498

CONSOLIDATED AND CONDENSED BA_2

CONSOLIDATED AND CONDENSED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 347	$ 314

CONSOLIDATED AND CONDENSED STAT

CONSOLIDATED AND CONDENSED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenues:
Revenues		$ 219,047	$ 193,128	$ 719,822	$ 640,375
Cost of products sold: (excluding depreciation and amortization)
Cost of products sold		154,510	124,456	503,910	406,549
Expenses:
Operating expenses	[1]	32,628	43,552	95,592	109,478
Selling, general and administrative	[1]	9,257	9,085	27,339	27,816
Depreciation and amortization		18,741	20,286	58,842	65,948
Total costs and expenses		215,136	197,379	685,683	609,791
Other operating loss		(384)	(187)	(876)	(327)
Operating income (loss)		3,527	(4,438)	33,263	30,257
Other income (expense):
Interest expense, net		(13,140)	(12,538)	(39,591)	(34,677)
Other, net		18	55	18	605
Total other expense		(13,122)	(12,483)	(39,573)	(34,072)
Net loss before taxes		(9,595)	(16,921)	(6,310)	(3,815)
Income tax expense		(91)	(108)	(372)	(301)
Loss from continuing operations		(9,686)	(17,029)	(6,682)	(4,116)
Income from discontinued operations, net of income taxes		49,132	743	51,700	2,402
Net income (loss)		39,446	(16,286)	45,018	(1,714)
Less general partner's interest in net (income) loss		(789)	325	(900)	34
Less (income) loss allocable to unvested restricted units		(27)	38	(29)	0
Limited partners' interest in net income (loss)		38,630	(15,923)	44,089	(1,680)
Terminalling and storage
Revenues:
Revenues	[1]	24,354	25,752	72,508	75,105
Marine transportation
Revenues:
Revenues	[1]	12,727	11,407	36,920	36,661
Natural gas services
Revenues:
Revenues	[1]	11,232	14,253	40,392	43,756
Sulfur services
Revenues:
Revenues		2,787	2,850	8,361	8,550
Product sales
Revenues:
Revenues	[1]	167,947	138,866	561,641	476,303
Natural gas services
Revenues:
Revenues	[1]	101,919	83,831	351,725	284,154
Cost of products sold: (excluding depreciation and amortization)
Cost of products sold	[1]	99,346	77,368	329,945	255,745
Sulfur services
Revenues:
Revenues	[1]	27,981	24,174	98,565	95,728
Cost of products sold: (excluding depreciation and amortization)
Cost of products sold	[1]	21,363	19,716	73,998	65,406
Terminalling and storage
Revenues:
Revenues	[1]	38,047	30,861	111,351	96,421
Cost of products sold: (excluding depreciation and amortization)
Cost of products sold	[1]	$ 33,801	$ 27,372	$ 99,967	$ 85,398
[1]	Related Party Transactions Included Above Three Months Ended Nine Months Ended September 30, September 30, 2018 2017 2018 2017 Revenues:* Terminalling and storage $ 19,619 $ 21,910 $ 60,151 $ 61,945 Marine transportation 4,009 4,098 11,727 12,610 Natural gas services — 4 — 122 Product Sales 180 828 1,248 2,982 Costs and expenses:* Cost of products sold: (excluding depreciation and amortization) Natural gas services 2,856 3,033 10,273 14,836 Sulfur services 4,337 3,555 13,208 10,997 Terminalling and storage 7,392 4,817 21,959 14,003 Expenses: Operating expenses 14,051 15,858 41,774 48,686 Selling, general and administrative 6,834 6,495 21,053 20,563

CONSOLIDATED AND CONDENSED ST_2

CONSOLIDATED AND CONDENSED STATEMENTS OF OPERATIONS - Allocation of Net Income (Loss) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Limited partner interest:
Continuing operations	$ (9,486)	$ (16,649)	$ (6,544)	$ (4,034)
Discontinued operations	48,116	726	50,633	2,354
Limited partners’ interest in net income (loss)	38,630	(15,923)	44,089	(1,680)
General partner interest:
Continuing operations	(193)	(340)	(134)	(82)
Discontinued operations	982	15	1,034	48
General partner interest in net income (loss)	$ 789	$ (325)	$ 900	$ (34)
Basic:
Continuing operations (in dollars per share)	$ (0.24)	$ (0.44)	$ (0.17)	$ (0.10)
Discontinued operations (in dollars per share)	1.24	0.02	1.30	0.06
Net income (loss) per unit attributable to limited partners, Basic (in dollars per share)	$ 1	$ (0.42)	$ 1.13	$ (0.04)
Weighted average limited partner units - basic (in shares)	38,711,515	38,357,171	38,876,783	38,015,704
Diluted:
Continuing operations (in dollars per share)	$ (0.24)	$ (0.44)	$ (0.17)	$ (0.10)
Discontinued operations (in dollars per share)	1.24	0.02	1.30	0.06
Net income (loss) per unit attributable to limited partners, Diluted (in dollars per share)	$ 1	$ (0.42)	$ 1.13	$ (0.04)
Weighted average limited partner units - diluted (in shares)	38,738,101	38,357,171	38,889,081	38,015,704

CONSOLIDATED AND CONDENSED ST_3

CONSOLIDATED AND CONDENSED STATEMENTS OF OPERATIONS - Related Party Transactions - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenues:
Revenues		$ 219,047	$ 193,128	$ 719,822	$ 640,375
Cost of products sold: (excluding depreciation and amortization)
Cost of products sold		154,510	124,456	503,910	406,549
Expenses:
Operating expenses	[1]	32,628	43,552	95,592	109,478
Selling, general and administrative	[1]	9,257	9,085	27,339	27,816
Terminalling and storage
Revenues:
Revenues	[1]	24,354	25,752	72,508	75,105
Marine transportation
Revenues:
Revenues	[1]	12,727	11,407	36,920	36,661
Natural gas services
Revenues:
Revenues	[1]	11,232	14,253	40,392	43,756
Product Sales
Revenues:
Revenues	[1]	167,947	138,866	561,641	476,303
Natural gas services
Revenues:
Revenues	[1]	101,919	83,831	351,725	284,154
Cost of products sold: (excluding depreciation and amortization)
Cost of products sold	[1]	99,346	77,368	329,945	255,745
Sulfur services
Revenues:
Revenues	[1]	27,981	24,174	98,565	95,728
Cost of products sold: (excluding depreciation and amortization)
Cost of products sold	[1]	21,363	19,716	73,998	65,406
Terminalling and storage
Revenues:
Revenues	[1]	38,047	30,861	111,351	96,421
Cost of products sold: (excluding depreciation and amortization)
Cost of products sold	[1]	33,801	27,372	99,967	85,398
Related Party
Expenses:
Operating expenses		14,051	15,858	41,774	48,686
Selling, general and administrative		6,834	6,495	21,053	20,563
Related Party | Terminalling and storage
Revenues:
Revenues		19,619	21,910	60,151	61,945
Related Party | Marine transportation
Revenues:
Revenues		4,009	4,098	11,727	12,610
Related Party | Natural gas services
Revenues:
Revenues		0	4	0	122
Related Party | Product Sales
Revenues:
Revenues		180	828	1,248	2,982
Related Party | Natural gas services
Cost of products sold: (excluding depreciation and amortization)
Cost of products sold		2,856	3,033	10,273	14,836
Related Party | Sulfur services
Cost of products sold: (excluding depreciation and amortization)
Cost of products sold		4,337	3,555	13,208	10,997
Related Party | Terminalling and storage
Cost of products sold: (excluding depreciation and amortization)
Cost of products sold		$ 7,392	$ 4,817	$ 21,959	$ 14,003
[1]	Related Party Transactions Included Above Three Months Ended Nine Months Ended September 30, September 30, 2018 2017 2018 2017 Revenues:* Terminalling and storage $ 19,619 $ 21,910 $ 60,151 $ 61,945 Marine transportation 4,009 4,098 11,727 12,610 Natural gas services — 4 — 122 Product Sales 180 828 1,248 2,982 Costs and expenses:* Cost of products sold: (excluding depreciation and amortization) Natural gas services 2,856 3,033 10,273 14,836 Sulfur services 4,337 3,555 13,208 10,997 Terminalling and storage 7,392 4,817 21,959 14,003 Expenses: Operating expenses 14,051 15,858 41,774 48,686 Selling, general and administrative 6,834 6,495 21,053 20,563

CONSOLIDATED AND CONDENSED ST_4

CONSOLIDATED AND CONDENSED STATEMENTS OF CAPITAL - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning balance			$ 298,241	$ 312,006
Net income	$ 39,446	$ (16,286)	45,018	(1,714)
Issuance of common units, net			(118)	51,061
Issuance of restricted units			0	0
Forfeiture of restricted units			0	0
General partner contribution				1,098
Cash distributions			(58,829)	(57,323)
Unit-based compensation			872	518
Purchase of treasury units			(273)	(4)
Excess purchase price over carrying value of acquired assets			(26)	(7,887)
Reimbursement of excess purchase price over carrying value of acquired assets				1,125
Ending balance	$ 284,885	$ 298,880	$ 284,885	$ 298,880
Common Limited
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning balance (in shares)			38,444,612	35,452,062
Beginning balance			$ 290,927	$ 304,594
Net income			$ 44,118	$ (1,680)
Issuance of common units, net (in shares)			0	2,990,000
Issuance of common units, net			$ (118)	$ 51,061
Issuance of restricted units (in shares)			633,425	12,000
Issuance of restricted units			$ 0	$ 0
Forfeiture of restricted units (in shares)			(23,000)	(5,750)
Forfeiture of restricted units			$ 0	$ 0
Cash distributions			(57,653)	(56,177)
Unit-based compensation			$ 872	$ 518
Purchase of treasury units (in shares)			(18,800)	(200)
Purchase of treasury units			$ (273)	$ (4)
Excess purchase price over carrying value of acquired assets			$ (26)	(7,887)
Reimbursement of excess purchase price over carrying value of acquired assets				$ 1,125
Ending balance (in shares)	39,036,237	38,448,112	39,036,237	38,448,112
Ending balance	$ 277,847	$ 291,550	$ 277,847	$ 291,550
General Partner Amount
Increase (Decrease) in Partners' Capital [Roll Forward]
Beginning balance			7,314	7,412
Net income			900	(34)
General partner contribution				1,098
Cash distributions			(1,176)	(1,146)
Ending balance	$ 7,038	$ 7,330	$ 7,038	$ 7,330

CONSOLIDATED AND CONDENSED ST_5

CONSOLIDATED AND CONDENSED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Cash flows from operating activities:
Net income (loss)	$ 45,018	$ (1,714)
Less: Income from discontinued operations, net of income taxes	(51,700)	(2,402)
Net loss from continuing operations	(6,682)	(4,116)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization	58,842	65,948
Amortization of deferred debt issuance costs	2,563	2,170
Amortization of premium on notes payable	(230)	(230)
Loss on sale of property, plant and equipment	876	327
Derivative loss	198	2,392
Net cash received (paid) for commodity derivatives	2,698	(6,429)
Unit-based compensation	872	518
Change in current assets and liabilities, excluding effects of acquisitions and dispositions:
Accounts and other receivables	35,191	16,381
Product exchange receivables	(156)	173
Inventories	(37,147)	(48,022)
Due from affiliates	735	(1,917)
Other current assets	556	(411)
Trade and other accounts payable	(18,230)	2,222
Product exchange payables	(2,104)	1,910
Due to affiliates	483	(5,169)
Income taxes payable	(62)	(420)
Other accrued liabilities	(9,726)	(3,766)
Change in other non-current assets and liabilities	610	1,941
Net cash provided by continuing operating activities	29,287	23,502
Net cash provided by discontinued operating activities	3,254	4,055
Net cash provided by operating activities	32,541	27,557
Cash flows from investing activities:
Payments for property, plant and equipment	(31,497)	(30,014)
Acquisitions	0	(19,533)
Payments for plant turnaround costs	(879)	(1,583)
Proceeds from sale of property, plant and equipment	1,269	1,604
Proceeds from repayment of Note receivable - affiliate	0	15,000
Other	0	(900)
Net cash used in continuing investing activities	(31,107)	(35,426)
Net cash provided by (used in) discontinuing investing activities	177,256	(145)
Net cash provided by (used in) investing activities	146,149	(35,571)
Cash flows from financing activities:
Payments of long-term debt	(460,000)	(242,000)
Proceeds from long-term debt	345,000	262,000
Proceeds from issuance of common units, net of issuance related costs	(118)	51,061
General partner contribution	0	1,098
Purchase of treasury units	(273)	(4)
Payment of debt issuance costs	(1,285)	(56)
Excess purchase price over carrying value of acquired assets	(26)	(7,887)
Reimbursement of excess purchase price over carrying value of acquired assets	0	1,125
Cash distributions paid	(58,829)	(57,323)
Net cash (used in) provided by financing activities	(175,531)	8,014
Net increase in cash	3,159	0
Cash at beginning of period	27	15
Cash at end of period	3,186	15
Non-cash additions to property, plant and equipment	$ 938	$ 1,367

Nature of Operations and Basis

Nature of Operations and Basis of Presentation	9 Months Ended
	Sep. 30, 2018
Accounting Policies [Abstract]
Nature of Operations and Basis of Presentation	NATURE OF OPERATIONS AND BASIS OF PRESENTATION 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: natural gas services, including liquids transportation and distribution services and natural gas storage; terminalling and storage services for petroleum products and by-products including the refining of naphthenic crude oil, blending and packaging of finished lubricants; 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 U.S. 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, 2017, filed with the Securities and Exchange Commission (the "SEC") on February 16, 2018, as amended by Amendment No. 1 on Form 10-K/A for the year ended December 31, 2017 filed on March 29, 2018. 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. Divestiture of WTLPG Partnership Interest. On July 31, 2018, the Partnership completed the sale of its 20 percent non-operating interest in West Texas LPG Pipeline L.P. ("WTLPG") to ONEOK, Inc. (“ONEOK”). WTLPG owns an approximate 2,300 mile common-carrier pipeline system that primarily transports NGLs from New Mexico and Texas to Mont Belvieu, Texas for fractionation. A wholly-owned subsidiary of ONEOK, Inc. is the operator of the assets. The Partnership has concluded the disposition represents a strategic shift and will have a major effect on its financial results going forward. As a result, the Partnership has presented the results of operations and cash flows relating to its equity method investment in WTLPG as discontinued operations for the three and nine months ended September 30, 2018 and 2017. See Note 4 for more information. Correction of Immaterial Error. The third quarter and year to date amounts for 2017 have been revised to reflect a reclassification in the presentation of certain expenses associated with the manufacturing and shipping of product related to a location in the Partnership's Terminalling and Storage operating segment. The reclassification resulted in a decrease in operating expenses from $45,072 to $43,552 and an increase in cost of products sold from $122,936 to $124,456 for the three months ended September 30, 2017 , and a decrease in operating expenses from $114,564 to $109,478 and an increase in cost of products sold from $401,463 to $406,549 for the nine months ended September 30, 2017

New Accounting Pronouncements

New Accounting Pronouncements	9 Months Ended
	Sep. 30, 2018
Accounting Changes and Error Corrections [Abstract]
New Accounting Pronouncements	NEW ACCOUNTING PRONOUNCEMENTS 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 replaced most existing revenue recognition guidance in U.S. GAAP. 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 adopted the new standard utilizing the cumulative effect method which will result in the cumulative effect of the adoption being recorded as of January 1, 2018. The Partnership adopted ASU 2014-09 on January 1, 2018 and did not identify any significant changes in the timing of revenue recognition when considering the amended accounting guidance. Additional disclosures related to revenue recognition appear in "Note 5. Revenue." In February 2016, the FASB issued ASU 2016-02, Leases , which introduces the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under previous guidance. Lessor accounting under the new standard is substantially unchanged and the Partnership believes substantially all of our leases will continue to be classified as operating leases under the new standard. Additional qualitative and quantitative disclosures, including significant judgments made by management, will be required. The update is effective for annual reporting periods beginning after December 15, 2018, including interim periods within those reporting periods, with early adoption permitted. The original guidance required application on a modified retrospective basis with the earliest period presented. In August 2018, the FASB issued ASU 2018-11, Targeted Improvements to ASC 842 , which includes an option to not restate comparative periods in transition and elect to use the effective date of ASC 842, Leases, as the date of initial application of transition. Based on the effective date, this guidance will apply and the Partnership will adopt this ASU beginning on January 1, 2019 and plans to elect the transition option provided under ASU 2018-11. Consequently, financial information will not be updated and the disclosures required under the new standard will not be provided for dates and periods before January 1, 2019. The new standard provides a number of optional practical expedients in transition. The Partnership expects to elect the "package of practical expedients", which permits the Partnership not to reassess under the new standard our prior conclusions about lease identification, lease classification and initial direct costs. The Partnership expects that this standard will have a material impact on its financial statements. While the Partnership continues to assess all of the effects of adoption, including evaluating its population of leases, the Partnership believes the most significant effects relate to (1) the recognition of a material amount of right-of-use ("ROU") assets and lease liabilities on its consolidated balance sheet and (2) providing significant new disclosures about the Partnership’s leasing activities. Refer to Note 9 - Leases of the Annual Report on Form 10-K for the fiscal year ended December 31, 2017 for information about the Partnership's lease obligations.

Acquisitions

Acquisitions	9 Months Ended
	Sep. 30, 2018
Business Combinations [Abstract]
Acquisitions	ACQUISITIONS Acquisition of Terminalling Assets. On February 22, 2017, the Partnership acquired 100% of the membership interests of MEH South Texas Terminals LLC ("MEH"), a subsidiary of Martin Resource Management, for a purchase price of $27,420 (the "Hondo Acquisition"), which was funded with borrowings under the Partnership's revolving credit facility. At the date of acquisition, MEH was in the process of constructing an asphalt terminal facility in Hondo, Texas (the "Hondo Terminal"), to serve the asphalt market in San Antonio, Texas and surrounding areas. 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 excess of the purchase price over the carrying value of the assets of $7,887 was recorded as an adjustment to "Partners' capital" during the nine months ended September 30, 2017 . During 2018, the Partnership paid an additional $26 related to a purchase price true-up, which was recorded as a further adjustment to "Partners' capital" for the nine months ended September 30, 2018 . Original purchase price $ 27,420 Purchase price true-up 26 Historical carrying value of assets allocated to "Property, plant and equipment" 19,533 Excess purchase price over carrying value of acquired assets $ 7,913 As no individual line item of the historical financial statements of the acquired assets was in excess of 3%

Divestitures and Discontinued O

Divestitures and Discontinued Operations	9 Months Ended
	Sep. 30, 2018
Discontinued Operations and Disposal Groups [Abstract]
Divestitures and Discontinued Operations	DIVESTITURES AND DISCONTINUED OPERATIONS Discontinued Operations Divestiture of WTLPG Partnership Interest. On July 31, 2018, the Partnership completed the sale of its 20 percent non-operating interest in WTLPG to ONEOK. WTLPG owns an approximate 2,300 mile common-carrier pipeline system that primarily transports NGLs from New Mexico and Texas to Mont Belvieu, Texas for fractionation. A wholly-owned subsidiary of ONEOK, Inc. is the operator of the assets. In consideration for the sale of these assets, the Partnership received cash proceeds of $193,705 , after transaction fees and expenses. The proceeds from the sale were used to reduce outstanding borrowings under the Partnership's revolving credit facility. The Partnership has concluded the disposition represents a strategic shift and will have a major effect on its financial results going forward. As a result, the Partnership has presented the results of operations and cash flows relating to its equity method investment in WTLPG as discontinued operations for the three and nine months ended September 30, 2018 and 2017. The operating results, which are included in income from discontinued operations, were as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Total costs and expenses and other, net, excluding depreciation and amortization $ (89 ) $ (44 ) $ (247 ) $ (143 ) Other operating income 1 48,564 — 48,564 — Equity in earnings 657 787 3,383 2,545 Income from discontinued operations before income taxes 49,132 743 51,700 2,402 Income tax expense — — — — Income from discontinued operations, net of income taxes $ 49,132 $ 743 $ 51,700 $ 2,402 1 These expenses represent direct operating expenses as a result of the Partnership's ownership interest in WTLPG. 2 Other operating income represents the gain on the disposition of the investment in WTLPG. Long-Lived Assets Held for Sale At September 30, 2018 and December 31, 2017, certain terminalling and storage and marine transportation assets met the criteria to be classified as held for sale in accordance with ASC 360-10 and are presented at the lower of the assets' carrying amount or fair value less cost to sell by segment in current assets as follows: September 30, 2018 December 31, 2017 Terminalling and storage $ 3,552 $ 4,152 Marine transportation 2,600 5,427 Assets held for sale $ 6,152 $ 9,579

Revenue

Revenue	9 Months Ended
	Sep. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenue	REVENUE The following table disaggregates our revenue by major source: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Terminalling and storage segment Lubricant product sales $ 38,047 $ 30,861 $ 111,351 $ 96,421 Throughput and storage 24,354 25,752 72,508 75,105 $ 62,401 $ 56,613 $ 183,859 $ 171,526 Natural gas services segment Natural gas liquids product sales $ 101,919 $ 83,831 $ 351,725 $ 284,154 Natural gas storage 11,232 14,253 40,392 43,756 $ 113,151 $ 98,084 $ 392,117 $ 327,910 Sulfur service segment Sulfur product sales $ 13,932 $ 10,740 $ 36,248 $ 35,013 Fertilizer product sales 14,049 13,434 62,317 60,715 Sulfur services 2,787 2,850 8,361 8,550 $ 30,768 $ 27,024 $ 106,926 $ 104,278 Marine transportation segment Inland transportation $ 11,338 $ 10,208 $ 32,236 $ 32,521 Offshore transportation 1,389 1,199 4,684 4,140 $ 12,727 $ 11,407 $ 36,920 $ 36,661 Revenue is measured based on a consideration specified in a contract with a customer and excludes amounts collected on behalf of third parties where the Partnership is acting as an agent. The Partnership recognizes revenue when the Partnership satisfies a performance obligation, which typically occurs when the Partnership transfers control over a product to a customer or as the Partnership delivers a service. The following is a description of the principal activities - separated by reportable segments - from which the Partnership generates revenue. Terminalling and Storage Segment Revenue is recognized for storage contracts based on the contracted monthly tank fixed fee. For throughput contracts, revenue is recognized based on the volume moved through the Partnership’s terminals at the contracted rate. For the Partnership’s tolling agreement, revenue is recognized based on the contracted monthly reservation fee and throughput volumes moved through the facility. When lubricants and drilling fluids are sold by truck or rail, revenue is recognized when title is transfered, which is either upon delivering product to the customer or when the product leaves the Partnership's facility, depending on the specific terms of the contract. Delivery of product is invoiced as the transaction occurs and is generally paid within a month. Natural Gas Services Segment Natural Gas Liquids ("NGL") distribution revenue is recognized when product is delivered by truck, rail, or pipeline to the Partnership's NGL customers. Revenue is recognized on title transfer of the product to the customer. Delivery of product is invoiced as the transaction occurs and are generally paid within a month. Natural gas storage revenue is recognized when the service is provided to the customer. The performance of the service is invoiced as the transaction occurs and is generally paid within a month. Sulfur Services Segment Revenue from sulfur product sales is recognized when the customer takes title to the product. Delivery of product is invoiced as the transaction occurs and are generally paid within a month. Revenue from sulfur services is recognized as services are performed during each monthly period. The performance of the service is invoiced as the transaction occurs and is generally paid within a month. Marine Transportation Segment Revenue is recognized for time charters based on a per day rate. For contracted trips, revenue is recognized upon completion of the particular trip. The performance of the service is invoiced as the transaction occurs and is generally paid within a month. The table includes estimated minimum revenue expected to be recognized in the future related to performance obligations that are unsatisfied at the end of the reporting period. The Partnership applies the practical expedient in ASC 606-10-50-14(a) and does not disclose information about remaining performance obligations that have original expected durations of one year or less. 2018 2019 2020 2021 2022 Thereafter Total Terminalling and storage Throughput and storage $ 12,569 $ 50,629 $ 49,330 $ 46,022 $ 41,505 $ 393,700 $ 593,755 Natural gas services Natural gas storage 9,483 33,648 28,015 25,389 24,615 10,107 131,257 Sulfur services Sulfur product sales 4,199 16,796 4,898 1,181 295 — 27,369 Marine transportation Offshore transportation 1,564 6,205 6,069 — — — 13,838 Total $ 27,815 $ 107,278 $ 88,312 $ 72,592 $ 66,415 $ 403,807 $ 766,219

Inventories

Inventories	9 Months Ended
	Sep. 30, 2018
Inventory Disclosure [Abstract]
Inventories	INVENTORIES Components of inventories at September 30, 2018 and December 31, 2017 were as follows: September 30, 2018 December 31, 2017 Natural gas liquids $ 88,475 $ 47,462 Sulfur 8,340 8,436 Fertilizer 11,588 18,674 Lubricants 23,140 20,086 Other 2,516 2,594 $ 134,059 $ 97,252

Investment in West Texas LPG Pi

Investment in West Texas LPG Pipeline L.P.	9 Months Ended
	Sep. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Investment in West Texas LPG Pipeline L.P.	INVESTMENT IN WEST TEXAS LPG PIPELINE L.P. As discussed in Note 4, on July 31, 2018, the Partnership completed the sale of its 20 percent non-operating interest in WTLPG. Prior to the sale, the Partnership owned a 19.8% limited partnership and 0.2% general partnership interest in West Texas LPG Pipeline L.P. ("WTLPG"). A wholly-owned subsidiary of ONEOK, Inc. is the operator of the assets. WTLPG owns an approximate 2,300 mile common-carrier pipeline system that primarily transports NGLs from New Mexico and Texas to Mont Belvieu, Texas for fractionation. The Partnership recognized its 20% interest in WTLPG as "Investment in WTLPG" on its Consolidated and Condensed Balance Sheets. The Partnership accounted for its ownership interest in WTLPG under the equity method of accounting. As discussed in Note 4, the Partnership sold its 20% non-operating partnership interest to ONEOK on July 31, 2018. Selected financial information for WTLPG during the period of ownership is as follows: As of July 31, One Month Ended July 31, Seven Months Ended July 31, 2018 Total Assets Long-Term Debt Members' Equity Revenues Net Income Revenues Net Income WTLPG $ 928,349 $ — $ 868,894 $ 9,104 $ 3,283 $ 55,534 $ 16,642 As of December 31, Three Months Ended September 30, Nine Months Ended September 30, 2017 Total Assets Long-Term Debt Members' Equity Revenues Net Income Revenues Net Income WTLPG $ 837,163 $ — $ 787,426 $ 22,009 $ 3,945 $ 63,148 $ 12,734

Long-Term Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Long-Term Debt	LONG-TERM DEBT At September 30, 2018 and December 31, 2017 , long-term debt consisted of the following: September 30, December 31, $664,444 Revolving credit facility at variable interest rate (5.19% 1 weighted average at September 30, 2018), due March 2020 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 $4,221 and $4,986, respectively 2 $ 325,779 $ 440,014 $400,000 Senior notes, 7.25% interest, net of unamortized debt issuance costs of $1,625 and $2,138, respectively, including unamortized premium of $726 and $956, respectively, issued $250,000 February 2013 and $150,000 April 2014, $26,200 repurchased during 2015, due February 2021, unsecured 2,3 372,901 372,618 Total long-term debt, net $ 698,680 $ 812,632 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. All amounts outstanding at September 30, 2018 and December 31, 2017 were at LIBOR plus an applicable margin. The applicable margin for revolving loans that are LIBOR loans ranges from 2.00% to 3.00% and the applicable margin for revolving loans that are base prime rate loans ranges from 1.00% to 2.00% . The applicable margin for existing LIBOR borrowings at September 30, 2018 is 3.00% . 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. 2 The Partnership is in compliance with all debt covenants as of September 30, 2018 and December 31, 2017 , respectively. 3 The 2021 indenture restricts the Partnership’s ability to sell assets; pay distributions or repurchase units or redeem or repurchase subordinated debt; make investments; incur or guarantee additional indebtedness or issue preferred units; and consolidate, merge or transfer all or substantially all of its assets. The Partnership paid cash interest, net of capitalized interest, in the amount of $20,551 and $18,578 for the three months ended September 30, 2018 and 2017 , respectively. The Partnership paid cash interest, net of capitalized interest, in the amount of $45,506 and $41,087 for the nine months ended September 30, 2018 and 2017, respectively. Capitalized interest was $158 and $130 for the three months ended September 30, 2018 and 2017 , respectively. Capitalized interest was $486 and $575 for the nine months ended September 30, 2018

Supplemental Balance Sheet Info

Supplemental Balance Sheet Information	9 Months Ended
	Sep. 30, 2018
Balance Sheet Related Disclosures [Abstract]
Supplemental Balance Sheet Information	SUPPLEMENTAL BALANCE SHEET INFORMATION Components of "Other assets, net" were as follows: September 30, 2018 December 31, 2017 Customer contracts and relationships, net $ 19,976 $ 25,252 Other intangible assets 1,408 1,752 Other 4,367 5,797 $ 25,751 $ 32,801 Accumulated amortization of intangible assets was $ 46,825 and $ 39,462 at September 30, 2018 and December 31, 2017 , respectively. Components of "Other accrued liabilities" were as follows: September 30, 2018 December 31, 2017 Accrued interest $ 3,980 $ 11,726 Asset retirement obligations 3,342 5,429 Property and other taxes payable 7,688 5,638 Accrued payroll 3,840 3,385 Other 26 162 $ 18,876 $ 26,340 The schedule below summarizes the changes in our asset retirement obligations: September 30, 2018 Beginning asset retirement obligations $ 13,512 Revisions to existing liabilities 1 4,756 Accretion expense 375 Liabilities settled (4,921 ) Ending asset retirement obligations 13,722 Current portion of asset retirement obligations 2 (3,342 ) Long-term portion of asset retirement obligations 3 $ 10,380 1 Several factors are considered in the annual review process, including inflation rates, current estimates for removal cost, discount rates, and the estimated remaining useful life of the assets. The 2018 revisions reflect changes in removal cost estimates and the estimated remaining useful life of assets. 2 The current portion of asset retirement obligations is included in "Other current liabilities" on the Partnership's Consolidated and Condensed Balance Sheets. 3

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	9 Months Ended
	Sep. 30, 2018
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 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. All derivatives and hedging instruments are non-hedge derivatives and are included on the balance sheet as an asset or a liability measured at fair value and changes in fair value are recognized as gains and losses in earnings of the periods in which they occur. (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 has entered into hedging transactions as of September 30, 2018 to protect a portion of its commodity price risk exposure. These hedging arrangements are in the form of swaps for NGLs. The Partnership has instruments totaling a gross notional quantity of 485 barrels settling during the period from October 1, 2018 through December 31, 2018. At December 31, 2017, the Partnership had instruments totaling a gross notional quantity of 145 barrels settling during the period from January 31, 2018 through February 28, 2018. These instruments settle against the applicable pricing source for each grade and location. (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. From time to time, 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. At September 30, 2018 and 2017, the Partnership did not have any outstanding interest rate derivative instruments. 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 The following table summarizes the fair value and classification of the Partnership’s derivative instruments in its Consolidated and Condensed Balance Sheets: Fair Values of Derivative Instruments in the Consolidated and Condensed Balance Sheets Derivative Assets Derivative Liabilities Fair Values Fair Values Balance Sheet Location September 30, 2018 December 31, 2017 Balance Sheet Location September 30, 2018 December 31, 2017 Derivatives not designated as hedging instruments: Current: Commodity contracts Fair value of derivatives $ — $ — Fair value of derivatives $ 2,968 $ 72 Total derivatives not designated as hedging instruments $ — $ — $ 2,968 $ 72 Effect of Derivative Instruments on the Consolidated and Condensed Statements of Operations For the Three Months Ended September 30, 2018 and 2017 Location of Gain (Loss) Recognized in Income on Derivatives Amount of Gain (Loss) Recognized in Income on Derivatives 2018 2017 Derivatives not designated as hedging instruments: Commodity contracts Cost of products sold $ (2,267 ) $ — Total effect of derivatives not designated as hedging instruments $ (2,267 ) $ — Effect of Derivative Instruments on the Consolidated and Condensed Statements of Operations For the Nine Months Ended September 30, 2018 and 2017 Location of Gain (Loss) Recognized in Income on Derivatives Amount of Gain (Loss) Recognized in Income on Derivatives 2018 2017 Derivatives not designated as hedging instruments: Commodity contracts Cost of products sold $ (198 ) $ (2,392 ) Total effect of derivatives not designated as hedging instruments $ (198 ) $ (2,392 )

Partners' Capital

Partners' Capital	9 Months Ended
	Sep. 30, 2018
Partners' Capital Notes [Abstract]
Partners' Capital	PARTNERS' CAPITAL As of September 30, 2018 , Partners’ capital consisted of 39,036,237 common limited partner units, representing a 98% partnership interest, and a 2% general partner interest. Martin Resource Management, through subsidiaries, owns 6,114,532 of the Partnership's common limited partner units representing approximately 15.7% of the Partnership's outstanding common limited partner 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 On February 22, 2017, the Partnership completed a public offering of 2,990,000 common units at a price of $18.00 per common unit, before the payment of underwriters' discounts, commissions and offering expenses (per unit value is in dollars, not thousands). Total proceeds from the sale of the 2,990,000 common units, net of underwriters' discounts, commissions and offering expenses, were $51,061 . Additionally, the Partnership's general partner contributed $1,098 in cash to the Partnership in conjunction with the issuance in order to maintain its 2.0% general partner interest in the Partnership. All of the net proceeds 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. The general partner was allocated no incentive distributions during the three or nine months ended September 30, 2018 and 2017. The target distribution levels entitle the general partner to receive 2% of quarterly cash distributions from the minimum of $0.50 per unit 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 from continuing operations and net income from discontinued operations allocated to the general partner and limited partners for purposes of calculating net income attributable to limited partners per unit: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Continuing operations: Loss from continuing operations $ (9,686 ) $ (17,029 ) $ (6,682 ) $ (4,116 ) Less general partner’s interest in net income (loss): Distributions payable on behalf of IDRs — — — — Distributions payable on behalf of general partner interest (96 ) 410 (175 ) 2,825 General partner interest in undistributed loss (97 ) (750 ) 41 (2,907 ) Less income (loss) allocable to unvested restricted units (7 ) (40 ) (4 ) — Limited partners’ interest in net loss $ (9,486 ) $ (16,649 ) $ (6,544 ) $ (4,034 ) Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Discontinued operations: Income from discontinued operations $ 49,132 $ 743 $ 51,700 $ 2,402 Less general partner’s interest in net income (loss): Distributions payable on behalf of IDRs — — — — Distributions payable on behalf of general partner interest 488 (18 ) 1,352 (1,648 ) General partner interest in undistributed loss 494 33 (318 ) 1,696 Less income (loss) allocable to unvested restricted units 34 2 33 — Limited partners’ interest in net income $ 48,116 $ 726 $ 50,633 $ 2,354 The Partnership allocates the general partner's share of earnings between continuing and discontinued operations as a proportion of net income from continuing and discontinued operations to total net income. The following are the unit amounts used to compute the basic and diluted earnings per limited partner unit for the periods presented: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Basic weighted average limited partner units outstanding 38,711,515 38,357,171 38,876,783 38,015,704 Dilutive effect of restricted units issued 26,586 — 12,298 — Total weighted average limited partner diluted units outstanding 38,738,101 38,357,171 38,889,081 38,015,704

Unit Based Awards

Unit Based Awards	9 Months Ended
	Sep. 30, 2018
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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Employees $ 326 $ 85 $ 767 $ 426 Non-employee directors 26 28 105 92 Total unit-based compensation expense $ 352 $ 113 $ 872 $ 518 All of the Partnership's outstanding awards at September 30, 2018 met the criteria to be treated under equity classification. 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. On May 26, 2017, the unitholders of the Partnership approved the Martin Midstream Partners L.P. 2017 Restricted Unit Plan (the "2017 LTIP"). The plan currently permits the grant of awards covering an aggregate of 3,000,000 common units, all of which can be awarded in the form of restricted units. The plan is administered by the compensation committee of the general partner’s board of directors (the "Compensation Committee"). A restricted unit is a unit that is granted to grantees with certain vesting restrictions, which may be time-based and/or performance-based. Once these restrictions lapse, the grantee is entitled to full ownership of the unit without restrictions. The Compensation Committee may determine to make grants under the plan containing such terms as the Compensation Committee shall determine under the plan. With respect to time-based restricted units ("TBRU's"), the Compensation Committee will determine the time period over which restricted units granted to employees and directors will vest. The Compensation Committee may also award a percentage of restricted units with vesting requirements based upon the achievement of specified pre-established performance targets ("Performance Based Restricted Units" or "PBRU's"). The performance targets may include, but are not limited to, the following: revenue and income measures, cash flow measures, net income before interest expense and income tax expense ("EBIT"), net income before interest expense, income tax expense, and depreciation and amortization ("EBITDA"), distribution coverage metrics, expense measures, liquidity measures, market measures, corporate sustainability metrics, and other measures related to acquisitions, dispositions, operational objectives and succession planning objectives. PBRU's are earned only upon our achievement of an objective performance measure for the performance period. PBRU's which vest are payable in common units. Unvested units granted under the 2017 LTIP may or may not participate in cash distributions depending on the terms of each individual award agreement. The restricted units issued to directors generally vest in equal annual installments over a four -year period. Restricted units issued to employees generally vest in equal annual installments over three years of service. On February 20, 2018, the Partnership issued 4,650 TBRU's to each of the Partnership's three independent directors under the 2017 LTIP. These restricted common units vest in equal installments of 1,162.5 units on January 24, 2019, 2020, 2021, and 2022. On March 1, 2018, the Partnership issued 301,550 TBRU's and 317,925 PBRU's to certain employees of Martin Resource Management. The TBRU's vest in equal installments over a three-year service period. The PBRU's will vest at the conclusion of a three-performance period based on certain performance targets. In addition, the PBRU's awarded on March 1, 2018 that are achieved will only vest if the grantee is employed by Martin Resource Management on March 31, 2021. As of September 30, 2018, the Partnership is unable to ascertain if the performance conditions will be achieved and, as such, has not recognized compensation expense for the vesting of the units. The Partnership will record compensation expense for the vested portion of the units once the achievement of the performance condition is deemed probable. 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 nine months ended September 30, 2018 is provided below: Number of Units Weighted Average Grant-Date Fair Value Per Unit Non-vested, beginning of period 98,750 $ 24.80 Granted (TBRU) 315,500 $ 13.89 Granted (PBRU) 317,925 $ 13.89 Vested (80,550 ) $ 27.71 Forfeited (23,000 ) $ 13.90 Non-Vested, end of period 628,625 $ 13.91 Aggregate intrinsic value, end of period $ 7,292 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 nine months ended September 30, 2018 and 2017 is provided below: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Aggregate intrinsic value of units vested $ — $ — $ 1,188 $ 135 Fair value of units vested — — 2,232 190 As of September 30, 2018 , there was $3,519 of unrecognized compensation cost related to non-vested restricted units. That cost is expected to be recognized over a weighted-average period of 2.59

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2018
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS As of September 30, 2018 , Martin Resource Management owns 6,114,532 of the Partnership’s common units representing approximately 15.7% of the Partnership’s outstanding limited partner 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 September 30, 2018 , of approximately 15.7% of the Partnership’s outstanding limited partner 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, marine fuel and other liquids; ◦ providing marine bunkering and other shore-based marine services in Texas, Louisiana, Mississippi, Alabama, and Florida; ◦ 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; and ◦ operating, solely for the Partnership's account, the asphalt facilities in Omaha, Nebraska, Port Neches, Texas, Hondo, 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, 2018, through December 31, 2018, the Conflicts Committee approved an annual reimbursement amount for indirect expenses of $16,416 . The Partnership reimbursed Martin Resource Management for $4,104 and $4,104 of indirect expenses for the three months ended September 30, 2018 and 2017 , respectively. The Partnership reimbursed Martin Resource Management for $12,312 and $12,312 of indirect expenses for the nine months ended September 30, 2018 and 2017 , 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.("MTI"), 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. MTI has indemnified the Partnership against all claims arising out of the negligence or willful misconduct of MTI and its officers, employees, agents, representatives and subcontractors. The Partnership has indemnified MTI 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 MTI 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, 2016, the Partnership entered into a second amended and restated terminalling services agreement under which the Partnership provides terminal services to Martin Resource Management for marine fuel distribution. At such time, the per gallon throughput fee the Partnership charged under this agreement was increased when compared to the previous agreement and may be adjusted annually based on a price index. This agreement was further amended on January 1, 2017 and October 1, 2017 to modify its minimum throughput requirements and throughput fees. This agreement, as amended, continues until September 30, 2018 and thereafter on a month to month basis until terminated by either party by giving 60 days’ written notice. Miscellaneous Terminal Services Agreements. The Partnership is currently 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 was previously a party to a third amended and restated sulfuric acid sales agency agreement dated August 2, 2017 but effective October 1, 2017, under which a successor in interest to the agreement from Martin Resource Management, Saconix LLC ("Saconix"), a limited liability company in which Martin Resource Management held a minority equity interest, purchased and marketed the sulfuric acid produced by the Partnership’s sulfuric acid production plant at Plainview, Texas, that was not consumed by the Partnership’s internal operations. This agreement, as amended, was to remain in place until September 30, 2020 and automatically renew year to year thereafter until either party provided 90 days’ written notice of termination prior to the expiration of the then existing term. Under this agreement, the Partnership sold all of its excess sulfuric acid to Saconix, who then marketed and sold such acid to third-parties. The Partnership shared in the profit of such sales. Effective May 31, 2018, Martin Resource Management no longer holds an equity interest in Saconix. These transactions are reported below as related party transactions during the period the equity interest was held. Transactions subsequent to Martin Resource Management's disposition of the equity interest will be reported as third party transactions. 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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Revenues: Terminalling and storage $ 19,619 $ 21,910 $ 60,151 $ 61,945 Marine transportation 4,009 4,098 11,727 12,610 Natural gas services — 4 — 122 Product sales: Natural gas services — 101 19 1,043 Sulfur services 7 522 619 1,540 Terminalling and storage 173 205 610 399 180 828 1,248 2,982 $ 23,808 $ 26,840 $ 73,126 $ 77,659 The impact of related party cost of products sold is reflected in the consolidated and condensed financial statements as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Cost of products sold: Natural gas services $ 2,856 $ 3,033 $ 10,273 $ 14,836 Sulfur services 4,337 3,555 13,208 10,997 Terminalling and storage 7,392 4,817 21,959 14,003 $ 14,585 $ 11,405 $ 45,440 $ 39,836 The impact of related party operating expenses is reflected in the consolidated and condensed financial statements as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Operating expenses: Marine transportation $ 5,574 $ 5,794 $ 16,895 $ 17,857 Natural gas services 2,202 2,256 6,633 6,724 Sulfur services 1,263 1,391 4,094 4,371 Terminalling and storage 5,012 6,417 14,152 19,734 $ 14,051 $ 15,858 $ 41,774 $ 48,686 The impact of related party selling, general and administrative expenses is reflected in the consolidated and condensed financial statements as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Selling, general and administrative: Marine transportation $ 236 $ 11 $ 251 $ 26 Natural gas services 1,072 1,140 4,351 4,619 Sulfur services 699 648 2,018 1,905 Terminalling and storage 723 592 2,094 1,701 Indirect, including overhead allocation 4,104 4,104 12,339 12,312 $ 6,834 $ 6,495 $ 21,053 $ 20,563 Other Related Party Transactions The Partnership had a $15,000 note receivable from an affiliate of Martin Resource Management which previously bore an annual interest rate of 15% and had a maturity date of August 31, 2026, the balance of which could be prepaid on or after September 1, 2016. On February 14, 2017, the Partnership notified Martin Resource Management that it would be requesting voluntary repayment of the long-term Note Receivable plus accrued interest. During second quarter of 2017, the Note Receivable was fully repaid. The note has historically been recorded in "Note receivable - affiliates" on the Partnership's Consolidated and Condensed Balance Sheets. Interest income for both the three months ended September 30, 2018 and 2017 was $0 . Interest income for the nine months ended September 30, 2018 and 2017 was $0 and $943

Business Segments

Business Segments	9 Months Ended
	Sep. 30, 2018
Segment Reporting [Abstract]
Business Segments	BUSINESS SEGMENTS The Partnership has four reportable segments: natural gas services, terminalling and storage, 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, 2017 , filed with the SEC on February 16, 2018, as amended, by Amendment No. 1 on Form 10-K/A filed on March 29, 2018. 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 September 30, 2018 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 $ 64,002 $ (1,601 ) $ 62,401 $ 9,311 $ 3,734 $ 4,372 Natural gas services 113,151 — 113,151 5,316 289 948 Sulfur services 30,768 — 30,768 2,113 2,130 1,489 Marine transportation 13,570 (843 ) 12,727 2,001 1,762 2,119 Indirect selling, general and administrative — — — — (4,388 ) — Total $ 221,491 $ (2,444 ) $ 219,047 $ 18,741 $ 3,527 $ 8,928 Three Months Ended September 30, 2017 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 $ 57,805 $ (1,192 ) $ 56,613 $ 10,192 $ (7,047 ) $ 8,634 Natural gas services 98,310 (226 ) 98,084 6,274 7,072 4,383 Sulfur services 27,024 — 27,024 2,020 (546 ) 862 Marine transportation 12,400 (993 ) 11,407 1,800 474 1 Indirect selling, general and administrative — — — — (4,391 ) — Total $ 195,539 $ (2,411 ) $ 193,128 $ 20,286 $ (4,438 ) $ 13,880 Nine Months Ended September 30, 2018 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 $ 188,299 $ (4,440 ) $ 183,859 $ 31,160 $ 8,195 $ 8,964 Natural gas services 392,117 — 392,117 15,921 21,585 4,000 Sulfur services 106,926 — 106,926 6,263 12,170 4,003 Marine transportation 38,766 (1,846 ) 36,920 5,498 4,278 12,247 Indirect selling, general and administrative — — — — (12,965 ) — Total $ 726,108 $ (6,286 ) $ 719,822 $ 58,842 $ 33,263 $ 29,214 Nine Months Ended September 30, 2017 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 $ 175,944 $ (4,418 ) $ 171,526 $ 35,996 $ (5,896 ) $ 21,859 Natural gas services 328,136 (226 ) 327,910 18,640 29,868 6,580 Sulfur services 104,278 — 104,278 6,083 16,516 1,593 Marine transportation 38,958 (2,297 ) 36,661 5,229 2,852 1,113 Indirect selling, general and administrative — — — — (13,083 ) — Total $ 647,316 $ (6,941 ) $ 640,375 $ 65,948 $ 30,257 $ 31,145 The Partnership's assets by reportable segment as of September 30, 2018 and December 31, 2017 , are as follows: September 30, 2018 December 31, 2017 Total assets: Terminalling and storage $ 314,124 $ 326,920 Natural gas services 567,912 704,524 Sulfur services 111,689 120,790 Marine transportation 107,324 101,264 Total assets $ 1,101,049 $ 1,253,498

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITTMENTS AND CONTINGENCIES 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 has reimbursed the Partnership $750 per quarter for four consecutive quarters as a reduction in the purchase price of the Redbird Class A interests. These payments were the result of Cardinal Gas Storage Partners LLC ("Cardinal") not achieving certain financial targets set forth in the Purchase Price Reimbursement Agreement. These payments were considered to be 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 were recorded as an adjustment to "Partners' capital" in each quarter in which the payments were made. The agreement further provided for purchase price reimbursements of up to $4,500 in 2016 in the event certain financial conditions were not met. For the nine months ended September 30, 2017, the Partnership received $1,125 , related to the Purchase Price Reimbursement Agreement. The amount received in the first quarter of 2017 represented the final payment under the Purchase Price Reimbursement Agreement. In 2015, the Partnership was named as a defendant in the cause J. A. Davis Properties, LLC v. Martin Operating Partnership L.P., in the 38th Judicial District Court, Cameron Parish, Louisiana. The plaintiff alleged that the Partnership breached a lease agreement by failing to perform work to the plaintiff's property as required under the lease agreement. The plaintiff originally sought to evict the Partnership from the leased property and to recover damages. Prior to trial, this matter was settled for a confidential amount in September of 2017. The Partnership's financial statements reflect the terms of the settlement and all amounts have been accrued as asset retirement obligations. On December 31, 2015, the Partnership received a demand from a customer in its lubricants packaging business for defense and indemnity in connection with lawsuits filed against it in various United States District Courts, which generally allege that the customer engaged in unlawful and deceptive business practices in connection with its marketing and advertising of its private label motor oil. The Partnership disputes that it has any obligation to defend or indemnify the customer for its conduct. Accordingly, on January 7, 2016, the Partnership filed a Complaint for Declaratory Judgment in the Chancery Court of Davidson County, Tennessee requesting a judicial determination that the Partnership does not owe the customer the demanded defense and indemnity obligations. The lawsuits against the customer have been transferred to the United States District Court for the Western District of Missouri for consolidated pretrial proceedings. On March 1, 2017, at the request of the parties, the Chancery Court of Davidson County, Tennessee administratively closed the Partnership's lawsuit pending rulings in the United States District Court for the Western District of Missouri. In the event that either party moves the Chancery Court of Davidson County, Tennessee to reopen the case, we expect the Court would grant such motion and reopen the case. If the case is reopened, we are currently unable to determine the exposure we may have in this matter, if any. Commitments The Partnership has non-cancelable revenue arrangements that are not under the scope of ASC 606 whereby we have committed certain terminalling and storage assets in exchange for a minimum fee. Future minimum revenues the Partnership expects to receive under these non-cancelable arrangements as of September 30, 2018 , are as follows: 2018 - $6,282 ; 2019 - $18,547 ; 2020 - $15,207 ; 2021 - $12,479 ; 2022 - $12,479 ; subsequent years - $71,241

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS The Partnership uses a valuation framework based upon inputs that market participants use in pricing certain assets and liabilities. These inputs are classified into two categories: observable inputs and unobservable inputs. Observable inputs represent market data obtained from independent sources. Unobservable inputs represent the Partnership's own market assumptions. Unobservable inputs are used only if observable inputs are unavailable or not reasonably available without undue cost and effort. The two types of inputs are further prioritized into the following hierarchy: 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 reflect the entity's own assumptions and are not corroborated by market data. Assets and liabilities measured at fair value on a recurring basis are summarized below: Level 2 September 30, 2018 December 31, 2017 Commodity derivative contracts, net $ (2,968 ) $ (72 ) The Partnership is required to disclose estimated fair values for its financial instruments. Fair value estimates are set forth below for these 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 maturity and highly liquid nature of these instruments, and as such these have been excluded from the table below. There is negligible credit risk associated with these instruments. • Note receivable and long-term debt: 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 considered Level 1, as the fair value is based on quoted market prices in active markets. September 30, 2018 December 31, 2017 Carrying Value Fair Value Carrying Value Fair Value 2021 Senior unsecured notes $ 372,901 $ 375,583 $ 372,618 $ 381,657

Condensed Consolidated Financia

Condensed Consolidated Financial Information	9 Months Ended
	Sep. 30, 2018
Consolidating Financial Statements [Abstract]
Condensed Consolidated Financial Information	CONDENSED CONSOLIDATED FINANCIAL INFORMATION

Impairments and Other Charges

Impairments and Other Charges	9 Months Ended
	Sep. 30, 2018
Unusual or Infrequent Items, or Both [Abstract]
Impairments and Other Charges	IMPAIRMENTS AND OTHER CHARGES Hurricane Impact On August 25, 2017, Hurricane Harvey made landfall as a Category 4 hurricane. The storm lingered over Texas and Louisiana for days producing over 50 inches of rain in some areas, resulting in widespread flooding and damage. The Partnership experienced an impact from Hurricane Harvey in its Terminalling and Storage and Sulfur Services segments, where damages were suffered to the Partnership's property, plant, and equipment at its Neches, Stanolind, Galveston, and Harbor Island terminals located along the Texas gulf coast. The damage incurred did not exceed the insurance deductible at these locations and therefore the Partnership does not expect to receive any insurance proceeds resulting from the damages caused by Hurricane Harvey. For the three months ended September 30, 2017, the Partnership recorded $982 related to actual repairs made to assets damaged by Hurricane Harvey. Additionally, the Partnership recorded an accrual for $3,725 in estimated repairs to be made to assets damaged by Hurricane Harvey. As a result of the damage sustained by Hurricane Harvey, the Partnership recorded a write-off in the amount of $186 related to assets damaged. Hurricane Harvey impacted the Partnership's operations in our Terminalling segments, where the Partnership experienced an estimated reduction in net income and cash flow of approximately $1,082

Subsequent Events

Subsequent Events	9 Months Ended
	Sep. 30, 2018
Subsequent Events [Abstract]
Subsequent Events	SUBSEQUENT EVENTS Martin Transport Inc. Stock Purchase Agreement. On October 22, 2018, the Operating Partnership entered into a stock purchase agreement (the “Stock Purchase Agreement”) with Martin Resource Management Corporation (“MRMC”) to acquire all of the issued and outstanding equity of Martin Transport, Inc. (“MTI”), a wholly-owned subsidiary of MRMC which operates a trucking company that transports petroleum products, liquid petroleum gas, chemicals, sulfur and other products for total consideration of $135,000 with a $10,000 earn-out based on certain performance thresholds, subject to certain post-closing adjustments. The transaction is expected to close in January of 2019. The Stock Purchase Agreement contains customary representations and warranties. Quarterly Distribution. On October 18, 2018, the Partnership declared a quarterly cash distribution of $0.50 per common unit for the third quarter of 2018, or $2.00

New Accounting Pronouncements (

New Accounting Pronouncements (Policies)	9 Months Ended
	Sep. 30, 2018
Accounting Changes and Error Corrections [Abstract]
New Accounting Pronouncements	NEW ACCOUNTING PRONOUNCEMENTS 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 replaced most existing revenue recognition guidance in U.S. GAAP. 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 adopted the new standard utilizing the cumulative effect method which will result in the cumulative effect of the adoption being recorded as of January 1, 2018. The Partnership adopted ASU 2014-09 on January 1, 2018 and did not identify any significant changes in the timing of revenue recognition when considering the amended accounting guidance. Additional disclosures related to revenue recognition appear in "Note 5. Revenue." In February 2016, the FASB issued ASU 2016-02, Leases , which introduces the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under previous guidance. Lessor accounting under the new standard is substantially unchanged and the Partnership believes substantially all of our leases will continue to be classified as operating leases under the new standard. Additional qualitative and quantitative disclosures, including significant judgments made by management, will be required. The update is effective for annual reporting periods beginning after December 15, 2018, including interim periods within those reporting periods, with early adoption permitted. The original guidance required application on a modified retrospective basis with the earliest period presented. In August 2018, the FASB issued ASU 2018-11, Targeted Improvements to ASC 842 , which includes an option to not restate comparative periods in transition and elect to use the effective date of ASC 842, Leases, as the date of initial application of transition. Based on the effective date, this guidance will apply and the Partnership will adopt this ASU beginning on January 1, 2019 and plans to elect the transition option provided under ASU 2018-11. Consequently, financial information will not be updated and the disclosures required under the new standard will not be provided for dates and periods before January 1, 2019. The new standard provides a number of optional practical expedients in transition. The Partnership expects to elect the "package of practical expedients", which permits the Partnership not to reassess under the new standard our prior conclusions about lease identification, lease classification and initial direct costs. The Partnership expects that this standard will have a material impact on its financial statements. While the Partnership continues to assess all of the effects of adoption, including evaluating its population of leases, the Partnership believes the most significant effects relate to (1) the recognition of a material amount of right-of-use ("ROU") assets and lease liabilities on its consolidated balance sheet and (2) providing significant new disclosures about the Partnership’s leasing activities. Refer to Note 9 - Leases of the Annual Report on Form 10-K for the fiscal year ended December 31, 2017 for information about the Partnership's lease obligations.
Fair Value Measurements	The Partnership uses a valuation framework based upon inputs that market participants use in pricing certain assets and liabilities. These inputs are classified into two categories: observable inputs and unobservable inputs. Observable inputs represent market data obtained from independent sources. Unobservable inputs represent the Partnership's own market assumptions. Unobservable inputs are used only if observable inputs are unavailable or not reasonably available without undue cost and effort. The two types of inputs are further prioritized into the following hierarchy: 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.
Fair Value of Financial Instruments	The Partnership is required to disclose estimated fair values for its financial instruments. Fair value estimates are set forth below for these 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 maturity and highly liquid nature of these instruments, and as such these have been excluded from the table below. There is negligible credit risk associated with these instruments. •

Acquisitions (Tables)

Acquisitions (Tables)	9 Months Ended
	Sep. 30, 2018
Business Combinations [Abstract]
Schedule of Business Acquisitions, by Acquisition	Original purchase price $ 27,420 Purchase price true-up 26 Historical carrying value of assets allocated to "Property, plant and equipment" 19,533 Excess purchase price over carrying value of acquired assets $ 7,913

Divestitures and Discontinued_2

Divestitures and Discontinued Operations (Tables)	9 Months Ended
	Sep. 30, 2018
Discontinued Operations and Disposal Groups [Abstract]
Disposal Groups, Including Discontinued Operations	The operating results, which are included in income from discontinued operations, were as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Total costs and expenses and other, net, excluding depreciation and amortization $ (89 ) $ (44 ) $ (247 ) $ (143 ) Other operating income 1 48,564 — 48,564 — Equity in earnings 657 787 3,383 2,545 Income from discontinued operations before income taxes 49,132 743 51,700 2,402 Income tax expense — — — — Income from discontinued operations, net of income taxes $ 49,132 $ 743 $ 51,700 $ 2,402 1 These expenses represent direct operating expenses as a result of the Partnership's ownership interest in WTLPG. 2
Disclosure of Long Lived Assets Held-for-sale	At September 30, 2018 and December 31, 2017, certain terminalling and storage and marine transportation assets met the criteria to be classified as held for sale in accordance with ASC 360-10 and are presented at the lower of the assets' carrying amount or fair value less cost to sell by segment in current assets as follows: September 30, 2018 December 31, 2017 Terminalling and storage $ 3,552 $ 4,152 Marine transportation 2,600 5,427 Assets held for sale $ 6,152 $ 9,579

Revenue (Tables)

Revenue (Tables)	9 Months Ended
	Sep. 30, 2018
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table disaggregates our revenue by major source: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Terminalling and storage segment Lubricant product sales $ 38,047 $ 30,861 $ 111,351 $ 96,421 Throughput and storage 24,354 25,752 72,508 75,105 $ 62,401 $ 56,613 $ 183,859 $ 171,526 Natural gas services segment Natural gas liquids product sales $ 101,919 $ 83,831 $ 351,725 $ 284,154 Natural gas storage 11,232 14,253 40,392 43,756 $ 113,151 $ 98,084 $ 392,117 $ 327,910 Sulfur service segment Sulfur product sales $ 13,932 $ 10,740 $ 36,248 $ 35,013 Fertilizer product sales 14,049 13,434 62,317 60,715 Sulfur services 2,787 2,850 8,361 8,550 $ 30,768 $ 27,024 $ 106,926 $ 104,278 Marine transportation segment Inland transportation $ 11,338 $ 10,208 $ 32,236 $ 32,521 Offshore transportation 1,389 1,199 4,684 4,140 $ 12,727 $ 11,407 $ 36,920 $ 36,661
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	The table includes estimated minimum revenue expected to be recognized in the future related to performance obligations that are unsatisfied at the end of the reporting period. The Partnership applies the practical expedient in ASC 606-10-50-14(a) and does not disclose information about remaining performance obligations that have original expected durations of one year or less. 2018 2019 2020 2021 2022 Thereafter Total Terminalling and storage Throughput and storage $ 12,569 $ 50,629 $ 49,330 $ 46,022 $ 41,505 $ 393,700 $ 593,755 Natural gas services Natural gas storage 9,483 33,648 28,015 25,389 24,615 10,107 131,257 Sulfur services Sulfur product sales 4,199 16,796 4,898 1,181 295 — 27,369 Marine transportation Offshore transportation 1,564 6,205 6,069 — — — 13,838 Total $ 27,815 $ 107,278 $ 88,312 $ 72,592 $ 66,415 $ 403,807 $ 766,219

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Sep. 30, 2018
Inventory Disclosure [Abstract]
Components of Inventory	Components of inventories at September 30, 2018 and December 31, 2017 were as follows: September 30, 2018 December 31, 2017 Natural gas liquids $ 88,475 $ 47,462 Sulfur 8,340 8,436 Fertilizer 11,588 18,674 Lubricants 23,140 20,086 Other 2,516 2,594 $ 134,059 $ 97,252

Investment in West Texas LPG _2

Investment in West Texas LPG Pipeline L.P. (Tables)	9 Months Ended
	Sep. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Select Financial Information for Significant Unconsolidated Equity Method Investees	Selected financial information for WTLPG during the period of ownership is as follows: As of July 31, One Month Ended July 31, Seven Months Ended July 31, 2018 Total Assets Long-Term Debt Members' Equity Revenues Net Income Revenues Net Income WTLPG $ 928,349 $ — $ 868,894 $ 9,104 $ 3,283 $ 55,534 $ 16,642 As of December 31, Three Months Ended September 30, Nine Months Ended September 30, 2017 Total Assets Long-Term Debt Members' Equity Revenues Net Income Revenues Net Income WTLPG $ 837,163 $ — $ 787,426 $ 22,009 $ 3,945 $ 63,148 $ 12,734

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Schedule of Long-Term Debt	At September 30, 2018 and December 31, 2017 , long-term debt consisted of the following: September 30, December 31, $664,444 Revolving credit facility at variable interest rate (5.19% 1 weighted average at September 30, 2018), due March 2020 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 $4,221 and $4,986, respectively 2 $ 325,779 $ 440,014 $400,000 Senior notes, 7.25% interest, net of unamortized debt issuance costs of $1,625 and $2,138, respectively, including unamortized premium of $726 and $956, respectively, issued $250,000 February 2013 and $150,000 April 2014, $26,200 repurchased during 2015, due February 2021, unsecured 2,3 372,901 372,618 Total long-term debt, net $ 698,680 $ 812,632 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. All amounts outstanding at September 30, 2018 and December 31, 2017 were at LIBOR plus an applicable margin. The applicable margin for revolving loans that are LIBOR loans ranges from 2.00% to 3.00% and the applicable margin for revolving loans that are base prime rate loans ranges from 1.00% to 2.00% . The applicable margin for existing LIBOR borrowings at September 30, 2018 is 3.00% . 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. 2 The Partnership is in compliance with all debt covenants as of September 30, 2018 and December 31, 2017 , respectively. 3 The 2021 indenture restricts the Partnership’s ability to sell assets; pay distributions or repurchase units or redeem or repurchase subordinated debt; make investments; incur or guarantee additional indebtedness or issue preferred units; and consolidate, merge or transfer all or substantially all of its assets.

Supplemental Balance Sheet In_2

Supplemental Balance Sheet Information (Tables)	9 Months Ended
	Sep. 30, 2018
Balance Sheet Related Disclosures [Abstract]
Schedule of Other Assets	Components of "Other assets, net" were as follows: September 30, 2018 December 31, 2017 Customer contracts and relationships, net $ 19,976 $ 25,252 Other intangible assets 1,408 1,752 Other 4,367 5,797 $ 25,751 $ 32,801
Schedule of Other Accrued Liabilities	Components of "Other accrued liabilities" were as follows: September 30, 2018 December 31, 2017 Accrued interest $ 3,980 $ 11,726 Asset retirement obligations 3,342 5,429 Property and other taxes payable 7,688 5,638 Accrued payroll 3,840 3,385 Other 26 162 $ 18,876 $ 26,340
Schedule of Asset Retirement Obligations	The schedule below summarizes the changes in our asset retirement obligations: September 30, 2018 Beginning asset retirement obligations $ 13,512 Revisions to existing liabilities 1 4,756 Accretion expense 375 Liabilities settled (4,921 ) Ending asset retirement obligations 13,722 Current portion of asset retirement obligations 2 (3,342 ) Long-term portion of asset retirement obligations 3 $ 10,380 1 Several factors are considered in the annual review process, including inflation rates, current estimates for removal cost, discount rates, and the estimated remaining useful life of the assets. The 2018 revisions reflect changes in removal cost estimates and the estimated remaining useful life of assets. 2 The current portion of asset retirement obligations is included in "Other current liabilities" on the Partnership's Consolidated and Condensed Balance Sheets. 3

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
	Sep. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Effect of Derivative Instruments on the Consolidated Balance Sheets	The following table summarizes the fair value and classification of the Partnership’s derivative instruments in its Consolidated and Condensed Balance Sheets: Fair Values of Derivative Instruments in the Consolidated and Condensed Balance Sheets Derivative Assets Derivative Liabilities Fair Values Fair Values Balance Sheet Location September 30, 2018 December 31, 2017 Balance Sheet Location September 30, 2018 December 31, 2017 Derivatives not designated as hedging instruments: Current: Commodity contracts Fair value of derivatives $ — $ — Fair value of derivatives $ 2,968 $ 72 Total derivatives not designated as hedging instruments $ — $ — $ 2,968 $ 72
Effect of Derivative Instruments on the Consolidated Statement of Operations	Effect of Derivative Instruments on the Consolidated and Condensed Statements of Operations For the Three Months Ended September 30, 2018 and 2017 Location of Gain (Loss) Recognized in Income on Derivatives Amount of Gain (Loss) Recognized in Income on Derivatives 2018 2017 Derivatives not designated as hedging instruments: Commodity contracts Cost of products sold $ (2,267 ) $ — Total effect of derivatives not designated as hedging instruments $ (2,267 ) $ — Effect of Derivative Instruments on the Consolidated and Condensed Statements of Operations For the Nine Months Ended September 30, 2018 and 2017 Location of Gain (Loss) Recognized in Income on Derivatives Amount of Gain (Loss) Recognized in Income on Derivatives 2018 2017 Derivatives not designated as hedging instruments: Commodity contracts Cost of products sold $ (198 ) $ (2,392 ) Total effect of derivatives not designated as hedging instruments $ (198 ) $ (2,392 )

Partners' Capital (Tables)

Partners' Capital (Tables)	9 Months Ended
	Sep. 30, 2018
Partners' Capital Notes [Abstract]
Reconciliation of Net Income to Partners Interest in Net Income	The following is a reconciliation of net income from continuing operations and net income from discontinued operations allocated to the general partner and limited partners for purposes of calculating net income attributable to limited partners per unit: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Continuing operations: Loss from continuing operations $ (9,686 ) $ (17,029 ) $ (6,682 ) $ (4,116 ) Less general partner’s interest in net income (loss): Distributions payable on behalf of IDRs — — — — Distributions payable on behalf of general partner interest (96 ) 410 (175 ) 2,825 General partner interest in undistributed loss (97 ) (750 ) 41 (2,907 ) Less income (loss) allocable to unvested restricted units (7 ) (40 ) (4 ) — Limited partners’ interest in net loss $ (9,486 ) $ (16,649 ) $ (6,544 ) $ (4,034 ) Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Discontinued operations: Income from discontinued operations $ 49,132 $ 743 $ 51,700 $ 2,402 Less general partner’s interest in net income (loss): Distributions payable on behalf of IDRs — — — — Distributions payable on behalf of general partner interest 488 (18 ) 1,352 (1,648 ) General partner interest in undistributed loss 494 33 (318 ) 1,696 Less income (loss) allocable to unvested restricted units 34 2 33 — Limited partners’ interest in net income $ 48,116 $ 726 $ 50,633 $ 2,354 The Partnership allocates the general partner's share of earnings between continuing and discontinued operations as a proportion of net income from continuing and discontinued operations to total net income. The following are the unit amounts used to compute the basic and diluted earnings per limited partner unit for the periods presented: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Basic weighted average limited partner units outstanding 38,711,515 38,357,171 38,876,783 38,015,704 Dilutive effect of restricted units issued 26,586 — 12,298 — Total weighted average limited partner diluted units outstanding 38,738,101 38,357,171 38,889,081 38,015,704

Unit Based Awards (Tables)

Unit Based Awards (Tables)	9 Months Ended
	Sep. 30, 2018
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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Employees $ 326 $ 85 $ 767 $ 426 Non-employee directors 26 28 105 92 Total unit-based compensation expense $ 352 $ 113 $ 872 $ 518
Summary of Restricted Unit Activity	A summary of the restricted unit activity for the nine months ended September 30, 2018 is provided below: Number of Units Weighted Average Grant-Date Fair Value Per Unit Non-vested, beginning of period 98,750 $ 24.80 Granted (TBRU) 315,500 $ 13.89 Granted (PBRU) 317,925 $ 13.89 Vested (80,550 ) $ 27.71 Forfeited (23,000 ) $ 13.90 Non-Vested, end of period 628,625 $ 13.91 Aggregate intrinsic value, end of period $ 7,292
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 nine months ended September 30, 2018 and 2017 is provided below: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Aggregate intrinsic value of units vested $ — $ — $ 1,188 $ 135 Fair value of units vested — — 2,232 190

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2018
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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Revenues: Terminalling and storage $ 19,619 $ 21,910 $ 60,151 $ 61,945 Marine transportation 4,009 4,098 11,727 12,610 Natural gas services — 4 — 122 Product sales: Natural gas services — 101 19 1,043 Sulfur services 7 522 619 1,540 Terminalling and storage 173 205 610 399 180 828 1,248 2,982 $ 23,808 $ 26,840 $ 73,126 $ 77,659 The impact of related party cost of products sold is reflected in the consolidated and condensed financial statements as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Cost of products sold: Natural gas services $ 2,856 $ 3,033 $ 10,273 $ 14,836 Sulfur services 4,337 3,555 13,208 10,997 Terminalling and storage 7,392 4,817 21,959 14,003 $ 14,585 $ 11,405 $ 45,440 $ 39,836 The impact of related party operating expenses is reflected in the consolidated and condensed financial statements as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Operating expenses: Marine transportation $ 5,574 $ 5,794 $ 16,895 $ 17,857 Natural gas services 2,202 2,256 6,633 6,724 Sulfur services 1,263 1,391 4,094 4,371 Terminalling and storage 5,012 6,417 14,152 19,734 $ 14,051 $ 15,858 $ 41,774 $ 48,686 The impact of related party selling, general and administrative expenses is reflected in the consolidated and condensed financial statements as follows: Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Selling, general and administrative: Marine transportation $ 236 $ 11 $ 251 $ 26 Natural gas services 1,072 1,140 4,351 4,619 Sulfur services 699 648 2,018 1,905 Terminalling and storage 723 592 2,094 1,701 Indirect, including overhead allocation 4,104 4,104 12,339 12,312 $ 6,834 $ 6,495 $ 21,053 $ 20,563

Business Segments (Tables)

Business Segments (Tables)	9 Months Ended
	Sep. 30, 2018
Segment Reporting [Abstract]
Segment Reporting by Segment	Three Months Ended September 30, 2018 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 $ 64,002 $ (1,601 ) $ 62,401 $ 9,311 $ 3,734 $ 4,372 Natural gas services 113,151 — 113,151 5,316 289 948 Sulfur services 30,768 — 30,768 2,113 2,130 1,489 Marine transportation 13,570 (843 ) 12,727 2,001 1,762 2,119 Indirect selling, general and administrative — — — — (4,388 ) — Total $ 221,491 $ (2,444 ) $ 219,047 $ 18,741 $ 3,527 $ 8,928 Three Months Ended September 30, 2017 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 $ 57,805 $ (1,192 ) $ 56,613 $ 10,192 $ (7,047 ) $ 8,634 Natural gas services 98,310 (226 ) 98,084 6,274 7,072 4,383 Sulfur services 27,024 — 27,024 2,020 (546 ) 862 Marine transportation 12,400 (993 ) 11,407 1,800 474 1 Indirect selling, general and administrative — — — — (4,391 ) — Total $ 195,539 $ (2,411 ) $ 193,128 $ 20,286 $ (4,438 ) $ 13,880 Nine Months Ended September 30, 2018 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 $ 188,299 $ (4,440 ) $ 183,859 $ 31,160 $ 8,195 $ 8,964 Natural gas services 392,117 — 392,117 15,921 21,585 4,000 Sulfur services 106,926 — 106,926 6,263 12,170 4,003 Marine transportation 38,766 (1,846 ) 36,920 5,498 4,278 12,247 Indirect selling, general and administrative — — — — (12,965 ) — Total $ 726,108 $ (6,286 ) $ 719,822 $ 58,842 $ 33,263 $ 29,214 Nine Months Ended September 30, 2017 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 $ 175,944 $ (4,418 ) $ 171,526 $ 35,996 $ (5,896 ) $ 21,859 Natural gas services 328,136 (226 ) 327,910 18,640 29,868 6,580 Sulfur services 104,278 — 104,278 6,083 16,516 1,593 Marine transportation 38,958 (2,297 ) 36,661 5,229 2,852 1,113 Indirect selling, general and administrative — — — — (13,083 ) — Total $ 647,316 $ (6,941 ) $ 640,375 $ 65,948 $ 30,257 $ 31,145
Assets by Segment	The Partnership's assets by reportable segment as of September 30, 2018 and December 31, 2017 , are as follows: September 30, 2018 December 31, 2017 Total assets: Terminalling and storage $ 314,124 $ 326,920 Natural gas services 567,912 704,524 Sulfur services 111,689 120,790 Marine transportation 107,324 101,264 Total assets $ 1,101,049 $ 1,253,498

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	September 30, 2018 December 31, 2017 Carrying Value Fair Value Carrying Value Fair Value 2021 Senior unsecured notes $ 372,901 $ 375,583 $ 372,618 $ 381,657 Level 2 September 30, 2018 December 31, 2017 Commodity derivative contracts, net $ (2,968 ) $ (72 )

Nature of Operations and Basi_2

Nature of Operations and Basis of Presentation (Details) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)segment	Sep. 30, 2017USD ($)	Jul. 31, 2018mi
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Number of primary business lines | segment				4
Operating expenses	[1]	$ 32,628	$ 43,552	$ 95,592	$ 109,478
Cost of products sold		$ 154,510	124,456	$ 503,910	406,549
Reclassification of certain Terminalling and Storage product expenses | Previously Reported
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Operating expenses			45,072		114,564
Cost of products sold			$ 122,936		$ 401,463
Discontinued Operations, Disposed of by Sale | West Texas LPG Pipeline L.P.
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Ownership percentage						20.00%
Length of common-carrier pipeline system (in miles) | mi						2,300
[1]	Related Party Transactions Included Above Three Months Ended Nine Months Ended September 30, September 30, 2018 2017 2018 2017 Revenues:* Terminalling and storage $ 19,619 $ 21,910 $ 60,151 $ 61,945 Marine transportation 4,009 4,098 11,727 12,610 Natural gas services — 4 — 122 Product Sales 180 828 1,248 2,982 Costs and expenses:* Cost of products sold: (excluding depreciation and amortization) Natural gas services 2,856 3,033 10,273 14,836 Sulfur services 4,337 3,555 13,208 10,997 Terminalling and storage 7,392 4,817 21,959 14,003 Expenses: Operating expenses 14,051 15,858 41,774 48,686 Selling, general and administrative 6,834 6,495 21,053 20,563

Acquisitions - Narrative (Detai

Acquisitions - Narrative (Details) - USD ($) $ in Thousands	Feb. 22, 2017	Sep. 30, 2018	Sep. 30, 2017
Business Acquisition [Line Items]
Excess purchase price over carrying value of acquired assets		$ 26	$ 7,887
MEH South Texas Terminals LLC
Business Acquisition [Line Items]
Percentage of voting interests acquired	100.00%
Purchase price	$ 27,420	27,420
Excess purchase price over carrying value of acquired assets	$ 7,887	7,913
Purchase price true-up		$ 26
Excess purchase price over carrying value of acquired assets, percentage	3.00%

Acquisitions - Purchase Price (

Acquisitions - Purchase Price (Details) - USD ($) $ in Thousands	Feb. 22, 2017	Sep. 30, 2018	Sep. 30, 2017
Business Acquisition [Line Items]
Excess purchase price over carrying value of acquired assets		$ 26	$ 7,887
MEH South Texas Terminals LLC
Business Acquisition [Line Items]
Original purchase price	$ 27,420	27,420
Purchase price true-up		26
Historical carrying value of assets allocated to Property, plant and equipment		19,533
Excess purchase price over carrying value of acquired assets	$ 7,887	$ 7,913

Divestitures and Discontinued_3

Divestitures and Discontinued Operations - (Discontinued Operations) (Details) $ in Thousands	Jul. 31, 2018USD ($)mi	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income from discontinued operations, net of income taxes		$ 49,132	$ 743	$ 51,700	$ 2,402
West Texas LPG Pipeline L.P. | Discontinued Operations, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage	20.00%
Length of common-carrier pipeline system (in miles) | mi	2,300
Proceeds from sale of equity method investments	$ 193,705
Total costs and expenses and other, net, excluding depreciation and amortization		(89)	(44)	(247)	(143)
Other operating income		48,564	0	48,564	0
Equity in earnings		657	787	3,383	2,545
Income from discontinued operations before income taxes		49,132	743	51,700	2,402
Income tax expense		0	0	0	0
Income from discontinued operations, net of income taxes		$ 49,132	$ 743	$ 51,700	$ 2,402

Divestitures and Discontinued_4

Divestitures and Discontinued Operations - (Long-Lived Assets Held-for-Sale) (Details) - Disposal Group, Held-for-sale, Not Discontinued Operations - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Assets held for sale	$ 6,152	$ 9,579
Terminalling and storage
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Assets held for sale	3,552	4,152
Marine transportation
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Assets held for sale	$ 2,600	$ 5,427

Revenue - Dissagregation of Rev

Revenue - Dissagregation of Revenue (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Disaggregation of Revenue [Line Items]
Revenues		$ 219,047	$ 193,128	$ 719,822	$ 640,375
Lubricant product sales
Disaggregation of Revenue [Line Items]
Revenues	[1]	38,047	30,861	111,351	96,421
Throughput and storage
Disaggregation of Revenue [Line Items]
Revenues	[1]	24,354	25,752	72,508	75,105
Natural gas liquids product sales
Disaggregation of Revenue [Line Items]
Revenues	[1]	101,919	83,831	351,725	284,154
Natural gas storage
Disaggregation of Revenue [Line Items]
Revenues	[1]	11,232	14,253	40,392	43,756
Sulfur services
Disaggregation of Revenue [Line Items]
Revenues		2,787	2,850	8,361	8,550
Terminalling and storage segment
Disaggregation of Revenue [Line Items]
Revenues		62,401	56,613	183,859	171,526
Terminalling and storage segment | Lubricant product sales
Disaggregation of Revenue [Line Items]
Revenues		38,047	30,861	111,351	96,421
Terminalling and storage segment | Throughput and storage
Disaggregation of Revenue [Line Items]
Revenues		24,354	25,752	72,508	75,105
Natural gas services segment
Disaggregation of Revenue [Line Items]
Revenues		113,151	98,084	392,117	327,910
Natural gas services segment | Natural gas liquids product sales
Disaggregation of Revenue [Line Items]
Revenues		101,919	83,831	351,725	284,154
Natural gas services segment | Natural gas storage
Disaggregation of Revenue [Line Items]
Revenues		11,232	14,253	40,392	43,756
Sulfur service segment
Disaggregation of Revenue [Line Items]
Revenues		30,768	27,024	106,926	104,278
Sulfur service segment | Sulfur product sales
Disaggregation of Revenue [Line Items]
Revenues		13,932	10,740	36,248	35,013
Sulfur service segment | Fertilizer product sales
Disaggregation of Revenue [Line Items]
Revenues		14,049	13,434	62,317	60,715
Sulfur service segment | Sulfur services
Disaggregation of Revenue [Line Items]
Revenues		2,787	2,850	8,361	8,550
Marine transportation segment
Disaggregation of Revenue [Line Items]
Revenues		12,727	11,407	36,920	36,661
Marine transportation segment | Inland transportation
Disaggregation of Revenue [Line Items]
Revenues		11,338	10,208	32,236	32,521
Marine transportation segment | Offshore transportation
Disaggregation of Revenue [Line Items]
Revenues		$ 1,389	$ 1,199	$ 4,684	$ 4,140
[1]	Related Party Transactions Included Above Three Months Ended Nine Months Ended September 30, September 30, 2018 2017 2018 2017 Revenues:* Terminalling and storage $ 19,619 $ 21,910 $ 60,151 $ 61,945 Marine transportation 4,009 4,098 11,727 12,610 Natural gas services — 4 — 122 Product Sales 180 828 1,248 2,982 Costs and expenses:* Cost of products sold: (excluding depreciation and amortization) Natural gas services 2,856 3,033 10,273 14,836 Sulfur services 4,337 3,555 13,208 10,997 Terminalling and storage 7,392 4,817 21,959 14,003 Expenses: Operating expenses 14,051 15,858 41,774 48,686 Selling, general and administrative 6,834 6,495 21,053 20,563

Revenue - Estimated Revenue Exp

Revenue - Estimated Revenue Expected to be Recognized in Future (Details) $ in Thousands	Sep. 30, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 27,815
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-01-01 | Throughput and storage | Terminalling and storage
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 12,569
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-01-01 | Natural gas storage | Natural gas services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 9,483
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-01-01 | Sulfur product sales | Sulfur services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 4,199
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-01-01 | Offshore transportation | Marine transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 1,564
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 107,278
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Throughput and storage | Terminalling and storage
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 50,629
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Natural gas storage | Natural gas services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 33,648
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Sulfur product sales | Sulfur services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 16,796
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Offshore transportation | Marine transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 6,205
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 88,312
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Throughput and storage | Terminalling and storage
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 49,330
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Natural gas storage | Natural gas services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 28,015
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Sulfur product sales | Sulfur services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 4,898
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Offshore transportation | Marine transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 6,069
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 72,592
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Throughput and storage | Terminalling and storage
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 46,022
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Natural gas storage | Natural gas services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 25,389
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Sulfur product sales | Sulfur services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 1,181
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Offshore transportation | Marine transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 66,415
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Throughput and storage | Terminalling and storage
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 41,505
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Natural gas storage | Natural gas services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 24,615
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Sulfur product sales | Sulfur services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 295
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Offshore transportation | Marine transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 403,807
Revenue, remaining performance obligation, expected timing of satisfaction, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Throughput and storage | Terminalling and storage
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 393,700
Revenue, remaining performance obligation, expected timing of satisfaction, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Natural gas storage | Natural gas services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 10,107
Revenue, remaining performance obligation, expected timing of satisfaction, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Sulfur product sales | Sulfur services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Revenue, remaining performance obligation, expected timing of satisfaction, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Offshore transportation | Marine transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Revenue, remaining performance obligation, expected timing of satisfaction, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 766,219
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Throughput and storage | Terminalling and storage
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	593,755
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Natural gas storage | Natural gas services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	131,257
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Sulfur product sales | Sulfur services
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	27,369
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Offshore transportation | Marine transportation
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 13,838

Inventories (Details)

Inventories (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Inventory Disclosure [Abstract]
Natural gas liquids	$ 88,475	$ 47,462
Sulfur	8,340	8,436
Fertilizer	11,588	18,674
Lubricants	23,140	20,086
Other	2,516	2,594
Inventories	$ 134,059	$ 97,252

Investment in West Texas LPG _3

Investment in West Texas LPG Pipeline L.P. - Narrative (Details) - mi	Jul. 31, 2018	Jul. 30, 2018
West Texas LPG Pipeline L.P.
Schedule of Equity Method Investments [Line Items]
Ownership percentage		20.00%
Length of common-carrier pipeline system (in miles)		2,300
West Texas LPG Pipeline L.P. | Common Limited
Schedule of Equity Method Investments [Line Items]
Ownership percentage		19.80%
West Texas LPG Pipeline L.P. | General Partner
Schedule of Equity Method Investments [Line Items]
Ownership percentage		0.20%
West Texas LPG Pipeline L.P. | Discontinued Operations, Disposed of by Sale
Schedule of Equity Method Investments [Line Items]
Ownership percentage	20.00%
Length of common-carrier pipeline system (in miles)	2,300

Investment in West Texas LPG _4

Investment in West Texas LPG Pipeline L.P. - Selected Financial Information for Equity Method Investees (Details) - West Texas LPG Pipeline L.P. - USD ($) $ in Thousands	1 Months Ended	3 Months Ended	7 Months Ended	9 Months Ended
	Jul. 31, 2018	Sep. 30, 2017	Jul. 31, 2018	Sep. 30, 2017	Dec. 31, 2017
Schedule of Equity Method Investments [Line Items]
Total Assets	$ 928,349		$ 928,349		$ 837,163
Long-Term Debt	0		0		0
Members' Equity	868,894		868,894		$ 787,426
Revenues	9,104	$ 22,009	55,534	$ 63,148
Net Income	$ 3,283	$ 3,945	$ 16,642	$ 12,734

Long-Term Debt (Details)

Long-Term Debt (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017	Dec. 31, 2015	Apr. 30, 2014	Feb. 28, 2013
Debt Instrument [Line Items]
Total long-term debt, net	$ 698,680,000		$ 698,680,000		$ 812,632,000
Cash paid for interest	20,551,000	$ 18,578,000	45,506,000	$ 41,087,000
Capitalized interest	158,000	$ 130,000	486,000	$ 575,000
Revolving Loan Facility
Debt Instrument [Line Items]
Total long-term debt, net	325,779,000		325,779,000		440,014,000
Face amount	$ 664,444,000		$ 664,444,000
Weighted average interest rate	5.19%		5.19%
Unamortized debt issuance costs	$ 4,221,000		$ 4,221,000		4,986,000
Revolving Loan Facility | LIBOR
Debt Instrument [Line Items]
Applicable margins			3.00%
Revolving Loan Facility | LIBOR | Minimum
Debt Instrument [Line Items]
Applicable margins			2.00%
Revolving Loan Facility | LIBOR | Maximum
Debt Instrument [Line Items]
Applicable margins			3.00%
Revolving Loan Facility | Prime Rate | Minimum
Debt Instrument [Line Items]
Applicable margins			1.00%
Revolving Loan Facility | Prime Rate | Maximum
Debt Instrument [Line Items]
Applicable margins			2.00%
Senior Notes | Senior Notes 7.25%
Debt Instrument [Line Items]
Total long-term debt, net	372,901,000		$ 372,901,000		372,618,000
Face amount	400,000,000		400,000,000				$ 150,000,000	$ 250,000,000
Unamortized debt issuance costs	$ 1,625,000		$ 1,625,000		2,138,000
Stated interest rate	7.25%		7.25%
Unamortized premium	$ 726,000		$ 726,000		$ 956,000
Repurchase amount						$ 26,200,000

Supplemental Balance Sheet In_3

Supplemental Balance Sheet Information - Other Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Balance Sheet Related Disclosures [Abstract]
Customer contracts and relationships, net	$ 19,976	$ 25,252
Other intangible assets	1,408	1,752
Other	4,367	5,797
Other assets, net	25,751	32,801
Accumulated amortization of intangible assets	$ 46,825	$ 39,462

Supplemental Balance Sheet In_4

Supplemental Balance Sheet Information - Other Accrued Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Balance Sheet Related Disclosures [Abstract]
Accrued interest	$ 3,980	$ 11,726
Asset retirement obligations	3,342	5,429
Property and other taxes payable	7,688	5,638
Accrued payroll	3,840	3,385
Other	26	162
Total other accrued liabilities	$ 18,876	$ 26,340

Supplemental Balance Sheet In_5

Supplemental Balance Sheet Information - Asset Retirement Obligations (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning asset retirement obligations	$ 13,512
Revisions to existing liabilities	4,756
Accretion expense	375
Liabilities settled	(4,921)
Ending asset retirement obligations	13,722
Current portion of asset retirement obligations	(3,342)	$ (5,429)
Long-term portion of asset retirement obligations	$ 10,380

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities - Narrative (Details) - bbl	9 Months Ended	12 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Commodity contracts
Derivatives, Fair Value [Line Items]
Notional quantity (in bbl)	485	145

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Balance Sheet Derivatives (Details) - Derivatives not designated as hedging instruments - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Derivatives, Fair Value [Line Items]
Derivative Assets	$ 0	$ 0
Derivative Liabilities	2,968	72
Commodity contracts | Fair value of derivatives
Derivatives, Fair Value [Line Items]
Derivative Assets	0	0
Derivative Liabilities	$ 2,968	$ 72

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Statement of Operations Derivatives (Details) - Derivatives not designated as hedging instruments - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	$ (2,267)	$ 0	$ (198)	$ (2,392)
Commodity contracts | Cost of products sold
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	$ (2,267)	$ 0	$ (198)	$ (2,392)

Partners' Capital - Narrative (

Partners' Capital - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands	Feb. 22, 2017	Sep. 30, 2018	Sep. 30, 2017
Limited Partners' Capital Account [Line Items]
Common limited partner units (in shares)		39,036,237
Ownership percentage		98.00%
General partner interest percentage		2.00%
Common units sold in public offering (in shares)	2,990,000
Share price (USD per share)	$ 18
Proceeds from the sale of common units, net of offering costs	$ 51,061
General partner contribution	$ 1,098	$ 0	$ 1,098
Martin Resource Management
Limited Partners' Capital Account [Line Items]
Voting interest percentage		51.00%
Martin Resource Management
Limited Partners' Capital Account [Line Items]
Common limited partner units (in shares)		6,114,532
Ownership percentage		15.70%
General partner interest percentage		2.00%
Voting interest percentage		15.70%

Partners' Capital - Incentive D

Partners' Capital - Incentive Distribution Rights and Distributions of Available Cash (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Limited Partners' Capital Account [Line Items]
General partner interest percentage			2.00%
Distribution period			45 days
Martin Midstream GP LLC
Limited Partners' Capital Account [Line Items]
General partner interest percentage			2.00%
Incentive distribution	$ 0	$ 0	$ 0	$ 0
Martin Midstream GP LLC | Target Level 1
Limited Partners' Capital Account [Line Items]
Target cash distribution, percent	2.00%		2.00%
Target cash distribution (USD per share)	$ 0.55		$ 0.55
Martin Midstream GP LLC | Target Level 2
Limited Partners' Capital Account [Line Items]
Target cash distribution, percent	15.00%		15.00%
Target cash distribution (USD per share)	$ 0.625		$ 0.625
Martin Midstream GP LLC | Target Level 3
Limited Partners' Capital Account [Line Items]
Target cash distribution, percent	25.00%		25.00%
Target cash distribution (USD per share)	$ 0.75		$ 0.75
Martin Midstream GP LLC | Target Level 4
Limited Partners' Capital Account [Line Items]
Target cash distribution, percent	50.00%		50.00%
Minimum | Martin Midstream GP LLC | Target Level 1
Limited Partners' Capital Account [Line Items]
Target cash distribution (USD per share)	$ 0.50		$ 0.50
Maximum | Martin Midstream GP LLC | Target Level 1
Limited Partners' Capital Account [Line Items]
Target cash distribution (USD per share)	$ 0.55		$ 0.55

Partners' Capital - Net Income

Partners' Capital - Net Income Per Unit (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Schedule of Reconciliation of Net Income from Continuing and Discontinuing Operations [Line Items]
Loss from continuing operations	$ (9,686)	$ (17,029)	$ (6,682)	$ (4,116)
Income from discontinued operations	49,132	743	51,700	2,402
Less general partner’s interest in net income (loss):
Less income (loss) allocable to unvested restricted units	(27)	38	(29)	0
Limited partners’ interest in net income (loss)	$ 38,630	$ (15,923)	$ 44,089	$ (1,680)
Basic weighted average limited partner units outstanding (in shares)	38,711,515	38,357,171	38,876,783	38,015,704
Dilutive effect of restricted units issued (in shares)	26,586	0	12,298	0
Total weighted average limited partner diluted units outstanding (in shares)	38,738,101	38,357,171	38,889,081	38,015,704
Continuing operations
Less general partner’s interest in net income (loss):
Distributions payable on behalf of IDRs	$ 0	$ 0	$ 0	$ 0
Distributions payable on behalf of general partner interest	(96)	410	(175)	2,825
General partner interest in undistributed loss	(97)	(750)	41	(2,907)
Less income (loss) allocable to unvested restricted units	(7)	(40)	(4)	0
Limited partners’ interest in net income (loss)	(9,486)	(16,649)	(6,544)	(4,034)
Discontinued operations
Less general partner’s interest in net income (loss):
Distributions payable on behalf of IDRs	0	0	0	0
Distributions payable on behalf of general partner interest	488	(18)	1,352	(1,648)
General partner interest in undistributed loss	494	33	(318)	1,696
Less income (loss) allocable to unvested restricted units	34	2	33	0
Limited partners’ interest in net income (loss)	$ 48,116	$ 726	$ 50,633	$ 2,354

Unit Based Awards - Schedule of

Unit Based Awards - Schedule of Compensation Costs (Details) - Selling, General and Administrative Expenses - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total unit-based compensation expense	$ 352	$ 113	$ 872	$ 518
Employees
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total unit-based compensation expense	326	85	767	426
Non-employee directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total unit-based compensation expense	$ 26	$ 28	$ 105	$ 92

Unit Based Awards - Narrative (

Unit Based Awards - Narrative (Details) $ in Thousands	Jan. 24, 2022shares	Jan. 24, 2021shares	Jan. 24, 2020shares	Jan. 24, 2019shares	Mar. 01, 2018shares	Feb. 20, 2018directorshares	Sep. 30, 2018USD ($)shares	May 26, 2017shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized (in shares)								3,000,000
Restricted Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vested, number of units (in shares)							80,550
Unrecognized compensation cost related to non-vested restricted units | $							$ 3,519
Weighted average period for recognition (in years)							2 years 7 months 2 days
Restricted Units | Employees
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)							3 years
Restricted Units | Non-employee directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)							4 years
Time Based Restricted Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)							3 years
Granted, number of units (in shares)							315,500
Number of independent directors receiving grants | director						3
Time Based Restricted Units | Employees
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted, number of units (in shares)					301,550
Time Based Restricted Units | Non-employee directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted, number of units (in shares)						4,650
Performance Based Restricted Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period (in years)							3 years
Granted, number of units (in shares)							317,925
Performance Based Restricted Units | Employees
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted, number of units (in shares)					317,925
Scenario, Forecast | Time Based Restricted Units | Non-employee directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vested, number of units (in shares)	1,162.5	1,162.5	1,162.5	1,162.5

Unit Based Awards - Restricted

Unit Based Awards - Restricted Unit Activity (Details) $ / shares in Units, $ in Thousands	9 Months Ended
	Sep. 30, 2018USD ($)$ / sharesshares
Restricted Units
Number of Units
Non-vested, beginning of period, number of units (in shares) | shares	98,750
Vested, number of units (in shares) | shares	(80,550)
Forfeited, number of units (in shares) | shares	(23,000)
Non-vested, end of period, number of units (in shares) | shares	628,625
Weighted Average Grant-Date Fair Value Per Unit
Non-vested, beginning of period, weighted average grant-date fair value per unit (USD per share) | $ / shares	$ 24.80
Vested, weighted average grant-date fair value per unit (USD per share) | $ / shares	27.71
Forfeited, weighted average grant-date fair value per unit (USD per share) | $ / shares	13.90
Non-vested, end of period, weighted average grant-date fair value per unit (USD per share) | $ / shares	$ 13.91
Aggregate intrinsic value, end of period | $	$ 7,292
Time Based Restricted Units
Number of Units
Granted, number of units (in shares) | shares	315,500
Weighted Average Grant-Date Fair Value Per Unit
Granted, weighted average grant-date fair value per unit (USD per share) | $ / shares	$ 13.89
Performance Based Restricted Units
Number of Units
Granted, number of units (in shares) | shares	317,925
Weighted Average Grant-Date Fair Value Per Unit
Granted, weighted average grant-date fair value per unit (USD per share) | $ / shares	$ 13.89

Unit Based Awards - Intrinsic a

Unit Based Awards - Intrinsic and Fair Value (Details) - Restricted Units - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Aggregate intrinsic value of units vested	$ 0	$ 0	$ 1,188	$ 135
Fair value of units vested	$ 0	$ 0	$ 2,232	$ 190

Related Party Transactions - Na

Related Party Transactions - Narrative (Details)	9 Months Ended
	Sep. 30, 2018shares
Related Party Transaction [Line Items]
General partner interest percentage	2.00%
Martin Resource Management
Related Party Transaction [Line Items]
Number of shares owned (in shares)	6,114,532
Ownership percentage	15.70%
General partner interest percentage	2.00%
MMGP Holdings, LLC | Martin Resource Management
Related Party Transaction [Line Items]
General partner interest percentage	51.00%

Related Party Transactions - Om

Related Party Transactions - Omnibus Agreement (Details) - Omnibus Agreement - Martin Resource Management - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Related Party Transaction [Line Items]
Noncompete restriction threshold	$ 5,000,000		$ 5,000,000
Noncompete restriction ownership option opportunity threshold minimum	5,000,000		5,000,000
Noncompete restriction ownership option opportunity threshold minimum with equity limitation	$ 5,000,000		$ 5,000,000
Equity limitation on ownership restriction percentage	20.00%		20.00%
Approved annual reimbursements for indirect expenses	$ 16,416,000		$ 16,416,000
Indirect expenses reimbursed	$ 4,104,000	$ 4,104,000	$ 12,312,000	$ 12,312,000

Related Party Transactions - Mo

Related Party Transactions - Motor Carrier Agreement (Details) - Motor Carrier Agreement - Martin Resource Management	9 Months Ended
	Sep. 30, 2018
Related Party Transaction [Line Items]
Automatic consecutive term renewal period (in years)	1 year
Termination written notice, minimum (in days)	30 days
Partnership notice period to terminate agreement (in days)	90 days

Related Party Transactions - Ma

Related Party Transactions - Marine Agreements (Details) - Marine Transportation Agreement - Martin Resource Management	9 Months Ended
	Sep. 30, 2018
Related Party Transaction [Line Items]
Automatic consecutive term renewal period (in years)	1 year
Termination written notice, minimum (in days)	60 days

Related Party Transactions - Te

Related Party Transactions - Terminal Services Agreements (Details)	9 Months Ended
	Sep. 30, 2018
Martin Resource Management
Related Party Transaction [Line Items]
Termination written notice, minimum (in days)	60 days

Related Party Transactions - Ot

Related Party Transactions - Other Agreements (Details) - Martin Resource Management	9 Months Ended
	Sep. 30, 2018bbl
Cross Tolling Agreement
Related Party Transaction [Line Items]
Production minimum per day (in bbl)	6,500
Annual escalation benchmark percentage	3.00%
Sulfuric Acid Sales Agency Agreement
Related Party Transaction [Line Items]
Partnership notice period to terminate agreement (in days)	90 days

Related Party Transactions - Sc

Related Party Transactions - Schedule of the Impact of Related Party Transactions (Details) - Related Party - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenues:
Revenue from related parties	$ 23,808	$ 26,840	$ 73,126	$ 77,659
Cost of products sold:
Cost of products sold	14,585	11,405	45,440	39,836
Operating expenses:
Operating expenses	14,051	15,858	41,774	48,686
Selling, general and administrative:
Selling, general and administrative	6,834	6,495	21,053	20,563
Terminalling and storage
Operating expenses:
Operating expenses	5,012	6,417	14,152	19,734
Marine transportation
Operating expenses:
Operating expenses	5,574	5,794	16,895	17,857
Natural gas services
Operating expenses:
Operating expenses	2,202	2,256	6,633	6,724
Sulfur services
Operating expenses:
Operating expenses	1,263	1,391	4,094	4,371
Operating segments | Terminalling and storage
Selling, general and administrative:
Selling, general and administrative	723	592	2,094	1,701
Operating segments | Marine transportation
Selling, general and administrative:
Selling, general and administrative	236	11	251	26
Operating segments | Natural gas services
Selling, general and administrative:
Selling, general and administrative	1,072	1,140	4,351	4,619
Operating segments | Sulfur services
Selling, general and administrative:
Selling, general and administrative	699	648	2,018	1,905
Indirect, including overhead allocation
Selling, general and administrative:
Selling, general and administrative	4,104	4,104	12,339	12,312
Terminalling and storage | Terminalling and storage
Revenues:
Revenue from related parties	19,619	21,910	60,151	61,945
Marine transportation | Marine transportation
Revenues:
Revenue from related parties	4,009	4,098	11,727	12,610
Natural gas services | Natural gas services
Revenues:
Revenue from related parties	0	4	0	122
Product sales
Revenues:
Revenue from related parties	180	828	1,248	2,982
Natural gas services | Natural gas services
Revenues:
Revenue from related parties	0	101	19	1,043
Cost of products sold:
Cost of products sold	2,856	3,033	10,273	14,836
Sulfur services | Sulfur services
Revenues:
Revenue from related parties	7	522	619	1,540
Cost of products sold:
Cost of products sold	4,337	3,555	13,208	10,997
Terminalling and storage | Terminalling and storage
Revenues:
Revenue from related parties	173	205	610	399
Cost of products sold:
Cost of products sold	$ 7,392	$ 4,817	$ 21,959	$ 14,003

Related Party Transactions - _2

Related Party Transactions - Other Related Party Transactions (Details) - Martin Energy Trading LLC - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Related Party Transaction [Line Items]
Due from related parties, annual interest rate			15.00%
Interest expense
Related Party Transaction [Line Items]
Interest income, related party	$ 0	$ 0	$ 0	$ 943
Notes Receivable
Related Party Transaction [Line Items]
Note receivable - affiliate	$ 15,000		$ 15,000

Business Segments (Details)

Business Segments (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018USD ($)	Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)segment	Sep. 30, 2017USD ($)	Dec. 31, 2017USD ($)
Segment Reporting [Abstract]
Number of reportable segments | segment			4
Segment Reporting Information [Line Items]
Total revenue	$ 219,047	$ 193,128	$ 719,822	$ 640,375
Depreciation and amortization	18,741	20,286	58,842	65,948
Operating Income (Loss) after Eliminations	3,527	(4,438)	33,263	30,257
Capital Expenditures and Plant Turnaround Costs	8,928	13,880	29,214	31,145
Total assets:
Total assets	1,101,049		1,101,049		$ 1,253,498
Terminalling and storage
Segment Reporting Information [Line Items]
Total revenue	62,401	56,613	183,859	171,526
Depreciation and amortization	9,311	10,192	31,160	35,996
Operating Income (Loss) after Eliminations	3,734	(7,047)	8,195	(5,896)
Capital Expenditures and Plant Turnaround Costs	4,372	8,634	8,964	21,859
Total assets:
Total assets	314,124		314,124		326,920
Natural gas services
Segment Reporting Information [Line Items]
Total revenue	113,151	98,084	392,117	327,910
Depreciation and amortization	5,316	6,274	15,921	18,640
Operating Income (Loss) after Eliminations	289	7,072	21,585	29,868
Capital Expenditures and Plant Turnaround Costs	948	4,383	4,000	6,580
Total assets:
Total assets	567,912		567,912		704,524
Sulfur services
Segment Reporting Information [Line Items]
Total revenue	30,768	27,024	106,926	104,278
Depreciation and amortization	2,113	2,020	6,263	6,083
Operating Income (Loss) after Eliminations	2,130	(546)	12,170	16,516
Capital Expenditures and Plant Turnaround Costs	1,489	862	4,003	1,593
Total assets:
Total assets	111,689		111,689		120,790
Marine transportation
Segment Reporting Information [Line Items]
Total revenue	12,727	11,407	36,920	36,661
Depreciation and amortization	2,001	1,800	5,498	5,229
Operating Income (Loss) after Eliminations	1,762	474	4,278	2,852
Capital Expenditures and Plant Turnaround Costs	2,119	1	12,247	1,113
Total assets:
Total assets	107,324		107,324		$ 101,264
Operating Revenues
Segment Reporting Information [Line Items]
Total revenue	221,491	195,539	726,108	647,316
Operating Revenues | Terminalling and storage
Segment Reporting Information [Line Items]
Total revenue	64,002	57,805	188,299	175,944
Operating Revenues | Natural gas services
Segment Reporting Information [Line Items]
Total revenue	113,151	98,310	392,117	328,136
Operating Revenues | Sulfur services
Segment Reporting Information [Line Items]
Total revenue	30,768	27,024	106,926	104,278
Operating Revenues | Marine transportation
Segment Reporting Information [Line Items]
Total revenue	13,570	12,400	38,766	38,958
Intersegment Revenues Eliminations
Segment Reporting Information [Line Items]
Total revenue	(2,444)	(2,411)	(6,286)	(6,941)
Intersegment Revenues Eliminations | Terminalling and storage
Segment Reporting Information [Line Items]
Total revenue	(1,601)	(1,192)	(4,440)	(4,418)
Intersegment Revenues Eliminations | Natural gas services
Segment Reporting Information [Line Items]
Total revenue	0	(226)	0	(226)
Intersegment Revenues Eliminations | Sulfur services
Segment Reporting Information [Line Items]
Total revenue	0	0	0	0
Intersegment Revenues Eliminations | Marine transportation
Segment Reporting Information [Line Items]
Total revenue	(843)	(993)	(1,846)	(2,297)
Indirect selling, general and administrative
Segment Reporting Information [Line Items]
Depreciation and amortization	0	0	0	0
Operating Income (Loss) after Eliminations	(4,388)	(4,391)	(12,965)	(13,083)
Capital Expenditures and Plant Turnaround Costs	$ 0	$ 0	$ 0	$ 0

Commitments and Contingencies (

Commitments and Contingencies (Details) - USD ($) $ in Thousands	Oct. 02, 2012	Sep. 30, 2017	Dec. 31, 2016	Sep. 30, 2018
Loss Contingencies [Line Items]
Non-cancelable revenue arrangements, future minimum revenues, 2018				$ 6,282
Non-cancelable revenue arrangements, future minimum revenues, 2019				18,547
Non-cancelable revenue arrangements, future minimum revenues, 2020				15,207
Non-cancelable revenue arrangements, future minimum revenues, 2021				12,479
Non-cancelable revenue arrangements, future minimum revenues, 2022				12,479
Non-cancelable revenue arrangements, future minimum revenues, subsequent years				$ 71,241
Martin Resource Management
Loss Contingencies [Line Items]
Quarterly purchase price reimbursement for non compliance	$ 750	$ 1,125
Maximum purchase price reimbursement for non compliance			$ 4,500

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Recurring | Level 2 | Commodity contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative contracts, net	$ (2,968)	$ (72)
Nonrecurring | 2021 Senior unsecured notes | Carrying Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
2021 Senior unsecured notes	372,901	372,618
Nonrecurring | 2021 Senior unsecured notes | Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
2021 Senior unsecured notes	$ 375,583	$ 381,657

Impairments and Other Charges (

Impairments and Other Charges (Details) - Hurricane Harvey $ in Thousands	Aug. 25, 2017Inch	Sep. 30, 2017USD ($)
Unusual or Infrequent Item, or Both [Line Items]
Inches of rain produced (over) | Inch	50
Repairs on assets damaged		$ 982
Accrual for estimated asset repairs		3,725
Write-off on assets damaged		186
Estimated reduction in net income and cash flow		$ 1,082

Subsequent Events (Details)

Subsequent Events (Details) - Subsequent Event - USD ($) $ / shares in Units, $ in Millions	Oct. 18, 2018	Jan. 31, 2019
Subsequent Event [Line Items]
Dividends declared (USD per share)	$ 0.50
Estimated annualized dividends (USD per share)	$ 2
Martin Transport Inc. Stock Purchase Agreement | Scenario, Forecast
Subsequent Event [Line Items]
Purchase price		$ 135
Earn-out based on performance thresholds		$ 10