UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549 

FORM 10-Q

☒						QUARTERLY REPORT PURSUANT TO SECTION 13 or 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 For the quarterly period ended September 30, 2021

OR

☐						TRANSITION REPORT PURSUANT TO SECTION 13 or 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 For the transition period from ____________ to ____________

 

Commission File Number

000-50056

MARTIN MIDSTREAM PARTNERS L.P.

(Exact name of registrant as specified in its charter)

Delaware						05-0527861
(State or other jurisdiction of incorporation or organization)						(IRS Employer Identification No.)

4200 Stone Road

Kilgore, Texas 75662

(Address of principal executive offices, zip code)

Registrant’s telephone number, including area code: (903) 983-6200

Securities registered pursuant to Section 12(b) of the Act

Title of each class			Trading Symbol(s)			Name of each exchange on which registered
Common Units representing limited partnership interests			MMLP			The NASDAQ Global Select Market

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes			☒			No			☐

Indicate by check mark whether the registrant has submitted electronically, every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). 

Yes			☒			No			☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See definition of "large accelerated filer," "accelerated filer", "smaller reporting company", and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Large accelerated filer			☐			Accelerated filer			☐
Non-accelerated filer			☒			Smaller reporting company			☐
Emerging growth company			☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.  ☐

Indicated by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). 

Yes			☐			No			☒

 The number of the registrant’s Common Units outstanding at October 25, 2021, was 38,802,750.

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Forward-Looking Statements

This Quarterly Report on Form 10-Q includes "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the "Exchange Act"). Statements included in this quarterly report that are not historical facts (including any statements concerning plans and objectives of management for future operations or economic performance, or assumptions or forecasts related thereto), including, without limitation, the information set forth in Management’s Discussion and Analysis of Financial Condition and Results of Operations, are forward-looking statements. These statements can be identified by the use of forward-looking terminology including "forecast," "may," "believe," "will," "expect," "anticipate," "estimate," "continue," or other similar words. These statements discuss future expectations, contain projections of results of operations or of financial condition or state other "forward-looking" information. We and our representatives may from time to time make other oral or written statements that are also forward-looking statements.

These forward-looking statements are made based upon management’s current plans, expectations, estimates, assumptions and beliefs concerning future events impacting us and therefore involve a number of risks and uncertainties. We caution that forward-looking statements are not guarantees and that actual results could differ materially from those expressed or implied in the forward-looking statements.

Because these forward-looking statements involve risks and uncertainties, actual results could differ materially from those expressed or implied by these forward-looking statements for a number of important reasons, including those discussed under "Item 1A. Risk Factors" of our Annual Report on Form 10-K for the year ended December 31, 2020, filed with the Securities and Exchange Commission (the "SEC") on March 3, 2021, and as may be updated and supplemented from time to time in our future Quarterly Reports on Form 10-Q and Current Reports on Form 8-K.

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			Page
PART I – FINANCIAL INFORMATION			4
Item 1. Financial Statements			4
Consolidated and Condensed Balance Sheets as of September 30, 2021 (unaudited) and December 31, 2020 (audited)			4
Consolidated and Condensed Statements of Operations for the Three and Nine Months Ended September 30, 2021 and 2020 (unaudited)			5
Consolidated and Condensed Statements of Comprehensive Income (Loss) for the Three and Nine Months Ended September 30, 2021 and 2020 (unaudited)			7
Consolidated and Condensed Statements of Capital (Deficit) for the Nine Months Ended September 30, 2021 and 2020 (unaudited)			8
Consolidated and Condensed Statements of Cash Flows for the Nine Months Ended September 30, 2021 and 2020 (unaudited)			9
Notes to Consolidated and Condensed Financial Statements (unaudited)			10
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations			34
Item 3. Quantitative and Qualitative Disclosures About Market Risk			57
Item 4. Controls and Procedures			58
PART II. OTHER INFORMATION			59
Item 1. Legal Proceedings			59
Item 1A. Risk Factors			59
Item 6. Exhibits			59

3

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PART I – FINANCIAL INFORMATION

Item 1.			Financial Statements

MARTIN MIDSTREAM PARTNERS L.P.

CONSOLIDATED AND CONDENSED BALANCE SHEETS

(Dollars in thousands)

			September 30, 2021						December 31, 2020
			(Unaudited)						(Audited)
Assets
Cash			$	6,783					$	4,958
Accounts and other receivables, less allowance for doubtful accounts of $272 and $261, respectively			75,676						52,748
Inventories			98,139						54,122
Due from affiliates			10,133						14,807
Other current assets			10,441						8,991
Total current assets			201,172						135,626
Property, plant and equipment, at cost			894,767						889,108
Accumulated depreciation			(543,309)						(509,237)
Property, plant and equipment, net			351,458						379,871
Goodwill			16,823						16,823
Right-of-use assets			21,267						22,260
Deferred income taxes, net			20,834						22,253
Other assets, net			2,684						2,805
Total assets			$	614,238					$	579,638
Liabilities and Partners’ Capital (Deficit)
Current installments of long-term debt and finance lease obligations			$	240					$	31,497
Trade and other accounts payable			73,273						51,900
Product exchange payables			1,387						373
Due to affiliates			5,469						435
Income taxes payable			401						556
Fair value of derivatives			5,049						207
Other accrued liabilities			21,696						34,407
Total current liabilities			107,515						119,375
Long-term debt, net			547,090						484,597
Finance lease obligations			108						289
Operating lease liabilities			14,960						15,181
Other long-term obligations			8,721						7,067
Total liabilities			678,394						626,509
Commitments and contingencies
Partners’ capital (deficit)			(58,157)						(46,871)
Accumulated other comprehensive loss			(5,999)						—
Total partners’ capital (deficit)			(64,156)						(46,871)
Total liabilities and partners' capital (deficit)			$	614,238					$	579,638

See accompanying notes to consolidated and condensed financial statements.

4

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MARTIN MIDSTREAM PARTNERS L.P.

CONSOLIDATED AND CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)

(Dollars and units in thousands, except per unit amounts)

			Three Months Ended												Nine Months Ended
			September 30,												September 30,
			2021						2020						2021						2020
Revenues:
Terminalling and storage  *			$	18,980					$	20,706					$	56,060					$	61,088
Transportation  *			39,079						31,938						103,820						102,364
Sulfur services			2,950						2,915						8,849						8,744
Product sales: *
Natural gas liquids			91,764						52,350						257,081						164,860
Sulfur services			27,887						18,965						95,109						74,879
Terminalling and storage			30,598						25,659						75,606						80,119
			150,249						96,974						427,796						319,858
Total revenues			211,258						152,533						596,525						492,054
Costs and expenses:
Cost of products sold: (excluding depreciation and amortization)
Natural gas liquids *			85,137						44,908						225,862						139,036
Sulfur services *			20,266						13,313						65,657						46,167
Terminalling and storage *			24,167						19,124						58,895						64,242
			129,570						77,345						350,414						249,445
Expenses:
Operating expenses  *			50,098						43,105						142,045						138,589
Selling, general and administrative  *			9,739						10,339						29,308						30,659
Depreciation and amortization			13,945						15,276						42,862						45,858
Total costs and expenses			203,352						146,065						564,629						464,551
Other operating income (loss), net			61						23						(610)						2,548
Gain on involuntary conversion of property, plant and equipment			186						4,522						186						4,522
Operating income			8,153						11,013						31,472						34,573
Other income (expense):
Interest expense, net			(14,110)						(12,943)						(40,372)						(32,245)
Gain on retirement of senior unsecured notes			—						—						—						3,484
Loss on exchange of senior unsecured notes			—						(8,516)						—						(8,516)
Other, net			—						—						(1)						7
Total other expense			(14,110)						(21,459)						(40,373)						(37,270)
Net loss before taxes			(5,957)						(10,446)						(8,901)						(2,697)
Income tax expense			(954)						(373)						(2,111)						(1,510)
Net loss			(6,911)						(10,819)						(11,012)						(4,207)
Less general partner's interest in net loss			138						216						220						84
Less loss allocable to unvested restricted units			20						53						30						8
Limited partners' interest in net loss			$	(6,753)					$	(10,550)					$	(10,762)					$	(4,115)
Net loss per unit attributable to limited partners - basic			$	(0.17)					$	(0.27)					$	(0.28)					$	(0.11)
Net loss per unit attributable to limited partners - diluted			$	(0.17)					$	(0.27)					$	(0.28)					$	(0.11)
Weighted average limited partner units - basic			38,687,874						38,661,852						38,689,434						38,654,891
Weighted average limited partner units - diluted			38,687,874						38,661,852						38,689,434						38,654,891

See accompanying notes to consolidated and condensed financial statements.

*Related Party Transactions Shown Below

5

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MARTIN MIDSTREAM PARTNERS L.P.

CONSOLIDATED AND CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)

(Dollars and units in thousands, except per unit amounts)

*Related Party Transactions Included Above

			Three Months Ended												Nine Months Ended
			September 30,												September 30,
			2021						2020						2021						2020
Revenues:*
Terminalling and storage			$	15,866					$	15,902					$	46,741					$	47,718
Transportation			5,564						5,514						14,463						16,801
Product Sales			68						69						253						199
Costs and expenses:*
Cost of products sold: (excluding depreciation and amortization)
Sulfur services			2,441						2,512						7,379						7,833
Terminalling and storage			7,259						4,303						18,863						14,329
Expenses:
Operating expenses			20,088						18,915						58,046						60,126
Selling, general and administrative			7,659						8,356						23,624						24,723

See accompanying notes to consolidated and condensed financial statements.

6

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MARTIN MIDSTREAM PARTNERS L.P.

CONSOLIDATED AND CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(Unaudited)

(Dollars and units in thousands, except per unit amounts)

			Three Months Ended												Nine Months Ended
			September 30,												September 30,
			2021						2020						2021						2020
Net loss			$	(6,911)					$	(10,819)					$	(11,012)					$	(4,207)
Changes in fair values of commodity cash flow hedges			(5,999)						—						(5,999)						—
Comprehensive loss			$	(12,910)					$	(10,819)					$	(17,011)					$	(4,207)

See accompanying notes to consolidated and condensed financial statements.

7

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MARTIN MIDSTREAM PARTNERS L.P.

CONSOLIDATED AND CONDENSED STATEMENTS OF CAPITAL (DEFICIT)

(Unaudited)

(Dollars in thousands)

									Partners’ Capital (Deficit)
									Common Limited												General Partner Amount						Accumulated Other Comprehensive Income (Loss)
						Units						Amount																		Total
Balances - January 1, 2020									38,863,389						$	(38,342)					$	2,146					$	—					$	(36,196)
Net loss									—						(4,123)						(84)						—						(4,207)
Issuance of restricted units									81,000						—						—						—						—
Forfeiture of restricted units									(84,134)						—						—						—						—
Cash distributions									—						(5,019)						(102)						—						(5,121)
Unit-based compensation									—						1,070						—						—						1,070
Purchase of treasury units									(7,748)						(9)						—						—						(9)
Balances - September 30, 2020									38,852,507						$	(46,423)					$	1,960					$	—					$	(44,463)
Balances - January 1, 2021									38,851,174						$	(48,776)					$	1,905					$	—					$	(46,871)
Net loss									—						(10,792)						(220)						—						(11,012)
Issuance of restricted units									42,168						—						—						—						—
Forfeiture of restricted units									(83,436)						—						—						—						—
Cash distributions									—						(581)						(12)						—						(593)
Unit-based compensation									—						336						—						—						336
Changes in fair values of commodity cash flow hedges									—						—						—						(5,999)						(5,999)
Purchase of treasury units									(7,156)						(17)						—						—						(17)
Balances - September 30, 2021									38,802,750						$	(59,830)					$	1,673					$	(5,999)					$	(64,156)

 

See accompanying notes to consolidated and condensed financial statements.

8

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MARTIN MIDSTREAM PARTNERS L.P.

CONSOLIDATED AND CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

(Dollars in thousands)

			Nine Months Ended
			September 30,
			2021						2020
Cash flows from operating activities:
Net loss			$	(11,012)					$	(4,207)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Depreciation and amortization			42,862						45,858
Amortization of deferred debt issuance costs			2,585						2,674
Amortization of premium on notes payable			—						(191)
Deferred income tax expense			1,419						1,202
Loss on sale of property, plant and equipment, net			610						153
Gain on involuntary conversion of property, plant and equipment			(186)						(4,522)
Non-cash impact related to exchange of senior unsecured notes			—						(749)
Gain on retirement of senior unsecured notes			—						(3,484)
Derivative (income) loss			1,825						(815)
Net cash received (paid) for commodity derivatives			(2,982)						539
Non cash unit-based compensation			336						1,070
Change in current assets and liabilities, excluding effects of acquisitions and dispositions:
Accounts and other receivables			(22,924)						30,012
Product exchange receivables			—						(212)
Inventories			(44,353)						(15,184)
Due from affiliates			4,674						(1,103)
Other current assets			(1,912)						(6,130)
Trade and other accounts payable			21,092						(17,117)
Product exchange payables			1,014						(1,278)
Due to affiliates			5,034						(1,003)
Income taxes payable			(155)						(137)
Other accrued liabilities			(10,536)						(5,534)
Change in other non-current assets and liabilities			203						(692)
Net cash provided by (used in) operating activities			(12,406)						19,150
Cash flows from investing activities:
Payments for property, plant and equipment			(11,449)						(23,705)
Payments for plant turnaround costs			(2,679)						(637)
Proceeds from involuntary conversion of property, plant and equipment			274						7,203
Proceeds from sale of property, plant and equipment			225						4,392
Net cash used in investing activities			(13,629)						(12,747)
Cash flows from financing activities:
Payments of long-term debt			(211,790)						(253,637)
Payments under finance lease obligations			(2,648)						(4,021)
Proceeds from long-term debt			243,500						259,019
Purchase of treasury units			(17)						(9)
Payment of debt issuance costs			(592)						(3,628)
Cash distributions paid			(593)						(5,121)
Net cash provided by (used in) financing activities			27,860						(7,397)
Net increase (decrease) in cash			1,825						(994)
Cash at beginning of period			4,958						2,856
Cash at end of period			$	6,783					$	1,862
Non-cash additions to property, plant and equipment			$	749					$	1,432

See accompanying notes to consolidated and condensed financial statements.

9

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

NOTE 1. 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:   (1) terminalling, processing, storage and packaging services for petroleum products and by-products including the refining of naphthenic crude oil; (2) land and marine transportation services for petroleum products and by-products, chemicals, and specialty products; (3) sulfur and sulfur-based products processing, manufacturing, marketing and distribution; and (4) natural gas liquids marketing, distribution, and transportation services.

 

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, 2020, filed with the SEC on March 3, 2021.

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.

NOTE 2. NEW ACCOUNTING PRONOUNCEMENTS

On January 1, 2021, the Partnership adopted Financial Accounting Standards Board ("FASB") Accounting Standards Update ("ASU") 2019-12, Income Taxes (Accounting Standards Codification ("ASC") Topic 740): Simplifying the Accounting for Income Taxes, which removes certain exceptions to general principles in ASC 740 and clarifies and amends existing guidance within U.S. GAAP. Adoption of the new standard did not have a material impact on the Partnership’s consolidated financial statements.

10

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

NOTE 3. REVENUE

    The following table disaggregates our revenue by major source:

			Three Months Ended September 30,												Nine Months Ended September 30,
			2021						2020						2021						2020
Terminalling and storage segment
Lubricant product sales			$	30,598					$	25,659					$	75,606					$	80,119
Throughput and storage			18,980						20,706						56,060						61,088
			$	49,578					$	46,365					$	131,666					$	141,207
Natural gas liquids segment
Natural gas liquids product sales			$	91,764					$	52,350					$	257,081					$	164,860
			$	91,764					$	52,350					$	257,081					$	164,860
Sulfur services segment
Sulfur product sales			$	7,768					$	6,161					$	22,222					$	19,010
Fertilizer product sales			20,119						12,804						72,887						55,869
Sulfur services			2,950						2,915						8,849						8,744
			$	30,837					$	21,880					$	103,958					$	83,623
Transportation segment
Land transportation			$	30,273					$	21,879					$	80,715					$	65,986
Inland transportation			7,465						9,294						20,822						33,611
Offshore transportation			1,341						765						2,283						2,767
			$	39,079					$	31,938					$	103,820					$	102,364

    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 transferred, 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. Throughput and storage revenue in the table above includes non-cancelable revenue arrangements that are under the scope of ASC 842, whereby the Partnership has committed certain Terminalling and Storage assets in exchange for a minimum fee.

Natural Gas Liquids Segment

    Natural Gas Liquids ("NGL") 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 is generally paid within a month.

11

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

Sulfur Services Segment

    Revenue from sulfur and fertilizer product sales is recognized when the customer takes title to the product.  Delivery of product is invoiced as the transaction occurs and is 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.

Transportation Segment

    Revenue related to land transportation is recognized for line hauls based on a mileage 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.

    Revenue related to marine transportation 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 below 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.

			2021						2022						2023						2024						2025						Thereafter						Total
Terminalling and storage
Throughput and storage			$	9,843					$	40,394					$	41,605					$	42,910					$	44,197					$	294,205					$	473,154
Natural Gas Services
Natural Gas Liquids			1,644						6,048						5,391						5,405						5,391						3,131						27,010
Sulfur services
Sulfur product sales			4,291						17,165						16,415						2,156						2,156						1,477						43,660
Total			$	15,778					$	63,607					$	63,411					$	50,471					$	51,744					$	298,813					$	543,824

NOTE 4. INVENTORIES

Components of inventories at September 30, 2021 and December 31, 2020 were as follows: 

			September 30, 2021						December 31, 2020
Natural gas liquids			$	65,136					$	27,878
Sulfur			49						24
Fertilizer			8,799						10,854
Lubricants			19,670						11,002
Other			4,485						4,364
			$	98,139					$	54,122

12

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

NOTE 5. DEBT

At September 30, 2021 and December 31, 2020, long-term debt consisted of the following:

			September 30, 2021						December 31, 2020
$275,000 Revolving credit facility at variable interest rate (5.00%1 weighted average at September 30, 2021), due August 2023 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, net of unamortized debt issuance costs of $3,004 and $3,826, respectively 2			$	205,496					$	144,174
$400,000 Senior notes, 7.25% interest, net of unamortized debt issuance costs of $— and $—, respectively, including unamortized premium of $— and $—, respectively, issued $250,000 February 2013 and $150,000 April 2014, $26,200 repurchased during 2015, $9,344 repurchased during 2020, $335,666 refinanced as part of the August 2020 Exchange offer, $28,790 repaid at maturity in February 2021, unsecured 2,3,4			—						28,790
$53,750 Senior notes due February 2024, 10.0% interest, net of unamortized debt issuance costs of $2,719 and $3,577, respectively, secured 2,3			51,031						50,173
$291,970 Senior notes due February 2025, 11.5% interest, net of unamortized debt issuance costs of $1,407 and $1,720, respectively, secured 2,3			290,563						290,250
Total			547,090						513,387
Less: current portion			—						(28,790)
Total long-term debt, net of current portion			$	547,090					$	484,597
Current installments of finance lease obligations			$	240					$	2,707
Finance lease obligations			108						289
Total finance lease obligations			$	348					$	2,996

     

    1 Interest rate fluctuates based on LIBOR (set on the date of each advance) or the base prime rate plus an applicable margin. The margin is set every three months. All amounts outstanding at December 31, 2020 and September 30, 2021 were at LIBOR plus an applicable margin with LIBOR having a floor of 1.00% per annum. The applicable margin for revolving loans that are LIBOR loans currently ranges from 2.75% to 4.00%, and the applicable margin for revolving loans that are base prime rate loans currently ranges from 1.75% to 3.00%.  The applicable margin for LIBOR borrowings at September 30, 2021 is 4.00%. The credit facility contains various covenants that limit the Partnership’s ability to make distributions; 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 Corporation (the "Omnibus Agreement"). The credit facility was amended on July 16, 2021 to, among other things, reduce the commitments thereunder from $300,000 to $275,000.

    2 The Partnership was in compliance with all debt covenants as of September 30, 2021 and December 31, 2020, respectively.

    3 The indentures for each of the outstanding series of senior notes restrict 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.

4 On February 15, 2021, the 2021 Notes matured and the Partnership retired the outstanding balance of $28,790 using funds borrowed under its revolving credit facility.

    The Partnership paid cash interest, net of capitalized interest, in the amount of $22,635 and $15,698 for the three months ended September 30, 2021 and 2020, respectively. The Partnership paid cash interest, net of capitalized interest, in the amount of $48,630 and $34,811 for the nine months ended September 30, 2021 and 2020, respectively.  Capitalized interest was $0 and $16 for the three months ended September 30, 2021 and 2020, respectively. Capitalized interest was $0 and $26 for the nine months ended September 30, 2021 and 2020, respectively.

13

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

NOTE 6. LEASES

    

    The Partnership has numerous operating leases primarily for terminal facilities and transportation and other equipment. The leases generally provide that all expenses related to the equipment are to be paid by the lessee.

    Operating lease Right-of-Use assets and operating lease liabilities are recognized based on the present value of lease payments over the lease term at commencement date. Because most of the Partnership's leases do not provide an implicit rate of return, the Partnership uses its imputed collateralized rate based on the information available at commencement date in determining the present value of lease payments. The estimated rate is based on a risk-free rate plus a risk-adjusted margin.

Our leases have remaining lease terms of 1 year to 15 years, some of which include options to extend the leases for up to 5 years, and some of which include options to terminate the leases within 1 year. The Partnership includes extension periods and excludes termination periods from its lease term if, at commencement, it is reasonably likely that the Partnership will exercise the option.

    

    The components of lease expense for the three and nine months ended September 30, 2021 and 2020 were as follows:

			Three Months Ended September 30,												Nine Months Ended September 30,
			2021						2020						2021						2020
Operating lease cost			$	2,485					$	2,572					$	6,987					$	8,182
Finance lease cost:
Amortization of right-of-use assets			$	25					390						$	140					1,505
Interest on lease liabilities			$	5					62						$	21					258
Short-term lease cost			$	2,324					3,138						$	7,905					10,054
Variable lease cost			$	28					$	33					$	87					$	83
Total lease cost			$	4,867					$	6,195					$	15,140					$	20,082

    

Supplemental balance sheet information related to leases at September 30, 2021 and December 31, 2020 was as follows:

			September 30, 2021						December 31, 2020
Operating Leases
Operating lease right-of-use assets			$	21,267					$	22,260
Current portion of operating lease liabilities included in "Other accrued liabilities"			$	6,746					$	7,529
Operating lease liabilities			$	14,960					15,181
Total operating lease liabilities			$	21,706					$	22,710
Finance Leases
Property, plant and equipment, at cost			$	1,071					$	10,352
Accumulated depreciation			$	(339)					(3,703)
Property, plant and equipment, net			$	732					$	6,649
Current installments of finance lease obligations			$	240					$	2,707
Finance lease obligations			$	108					289
Total finance lease obligations			$	348					$	2,996

14

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

    The Partnership’s future minimum lease obligations as of September 30, 2021 consist of the following:

			Operating Leases						Finance Leases
Year 1			$	7,801					$	252
Year 2			5,102						109
Year 3			2,923						—
Year 4			2,220						—
Year 5			1,494						—
Thereafter			7,120						—
Total			$	26,660					$	361
Less amounts representing interest costs			(4,954)						(13)
Total lease liability			$	21,706					$	348

    The Partnership has non-cancelable revenue arrangements that are under the scope of ASC 842 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, 2021 are as follows: 2021 - $6,139; 2022 - $14,924; 2023 - $14,364; 2024 - $14,364; 2025 - $13,798; subsequent years - $38,539.

15

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

NOTE 7. SUPPLEMENTAL BALANCE SHEET INFORMATION

    

    Components of "Other accrued liabilities" were as follows:

			September 30, 2021						December 31, 2020
Accrued interest			$	5,261					$	16,104
Asset retirement obligations			300						1,692
Property and other taxes payable			4,546						4,869
Accrued payroll			4,425						3,244
Operating lease liabilities			6,746						7,529
Other			418						969
			$	21,696					$	34,407

The schedule below summarizes the changes in our asset retirement obligations:

			September 30, 2021
Beginning asset retirement obligations			$	8,759
Additions to asset retirement obligations			—
Accretion expense			284
Liabilities settled			(22)
Ending asset retirement obligations			9,021
Current portion of asset retirement obligations1			(300)
Long-term portion of asset retirement obligations2			$	8,721

1The current portion of asset retirement obligations is included in "Other accrued liabilities" on the Partnership's Consolidated and Condensed Balance Sheets.

2The non-current portion of asset retirement obligations is included in "Other long-term obligations" on the Partnership's Consolidated and Condensed Balance Sheets.

16

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

NOTE 8. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES

The Partnership’s results of operations could be materially impacted by changes in commodity prices and 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. At the time derivative contracts are entered into, the Partnership assesses whether the nature of the instrument qualifies for hedge accounting treatment according to the requirements of ASC 815 – Derivatives and Hedging. For those transactions designated as hedging instruments for accounting purposes, the Partnership documents all relationships between hedging instruments and hedged items, as well as our risk-management objective and strategy for undertaking the various hedge transactions. The Partnership also assesses, both at the hedge’s inception and on an ongoing basis, whether the derivatives used in hedging transactions are highly effective in offsetting changes in cash flows or fair value of hedged items. All derivatives and hedging instruments are included on the balance sheet as an asset or a liability measured at fair value. Changes in fair value for hedging instruments are recognized on the balance sheet through Accumulated Other Comprehensive Income ("AOCI"). Settlements related to effective hedging relationships will be reclassified from AOCI to earnings during the term at which the hedged transactions are reflected on the income statement.

From time to time, derivatives designated for hedge accounting may be closed prior to contract expiration. The accounting treatment of closed positions depends on whether the closure occurred due to the hedged transaction occurring early or if the hedged transaction is still expected to occur as originally forecasted. For hedged transactions that occur early, the closure results in the realized gain or loss from closure being recognized in the same period the accelerated hedged transaction affects earnings. For hedged transactions that are still expected to occur as originally forecasted, the closure results in the realized gain or loss being deferred until the hedged transaction affects earnings.

If it is determined that hedged transactions associated with cash flow hedges are no longer probable of occurring, the gain or loss associated with the instrument is recognized immediately into earnings.

From time to time, we may have derivative financial instruments for which we do not elect hedge accounting. Changes in fair value for derivatives not designated as hedges are recognized as gains and losses in the 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, 2021, to protect a portion of its commodity price risk exposure. These hedging arrangements are in the form of swaps for NGLs. At September 30, 2021, the Partnership had instruments totaling a gross notional quantity of 400,000 barrels settling during the period from October 31, 2021 through December 31, 2021. At December 31, 2020, the Partnership had instruments totaling a gross notional quantity of 137,000 barrels settling during the period from January 31, 2021 through February 28, 2021. These instruments settle against the applicable pricing source for each grade and location.

    For information regarding gains and losses on commodity derivative instruments, see "Tabular Presentation of Gains and Losses on Derivative Instruments" below.

(b)    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:

17

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

			Derivative Assets												Derivative Liabilities
						Fair Values												Fair Values
			Balance Sheet Location			September 30, 2021						December 31, 2020			Balance Sheet Location			September 30, 2021						December 31, 2020
Derivatives designated as hedging instruments:			Current:
Commodity contracts			Fair value of derivatives			$	—					$	—		Fair value of derivatives			$	5,049					$	—
Derivatives not designated as hedging instruments:			Current:
Commodity contracts			Fair value of derivatives			$	—					$	—		Fair value of derivatives			$	—					$	207

The following table summarizes the loss recognized in AOCI at September 30, 2021 and the gain (loss) reclassified from accumulated other comprehensive loss into earnings during the three months ended September 30, 2021 for derivative financial instruments designated as cash flow hedges:

			Amount of Gain (Loss) Recognized in AOCI									Location of Gain (Loss) Reclassified from AOCI into Income			Amount of Gain (Loss) Reclassified from AOCI into Income
			2021						2020						2021						2020
Commodity contracts			$	(5,999)					$	—		Cost of products sold			$	—					$	—
Total			$	(5,999)					$	—					$	—					$	—

The following table summarizes the loss recognized in AOCI at September 30, 2021 and the gain (loss) reclassified from accumulated other comprehensive loss into earnings during the nine months ended September 30, 2021 for derivative financial instruments designated as cash flow hedges:

			Amount of Gain (Loss) Recognized in AOCI									Location of Gain (Loss) Reclassified from AOCI into Income			Amount of Gain (Loss) Reclassified from AOCI into Income
			2021						2020						2021						2020
Commodity contracts			$	(5,999)					$	—		Cost of products sold			$	—					$	—
Total			$	(5,999)					$	—					$	—					$	—

18

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

The following tables summarize the loss recognized in earnings for derivative instruments not designated as hedging instruments during the three months ended September 30, 2021:

			Location of Gain (Loss) Recognized in Income on  Derivatives			Amount of Gain (Loss) Recognized in Income on Derivatives
						2021						2020
Derivatives not designated as hedging instruments:
Commodity contracts			Cost of products sold			$	(941)					$	(134)
Total effect of derivatives not designated as hedging instruments						$	(941)					$	(134)

The following tables summarize the loss recognized in earnings for derivative instruments not designated as hedging instruments during the nine months ended September 30, 2021:

			Location of Gain (Loss) Recognized in Income on  Derivatives			Amount of Gain (Loss) Recognized in Income on Derivatives
						2021						2020
Derivatives not designated as hedging instruments:
Commodity contracts			Cost of products sold			$	(1,825)					$	(263)
Total effect of derivatives not designated as hedging instruments						$	(1,825)					$	(263)

NOTE 9. PARTNERS' CAPITAL

As of September 30, 2021, Partners’ capital consisted of 38,802,750 common limited partner units, representing a 98% partnership interest, and a 2% general partner interest. Martin Resource Management Corporation, through subsidiaries, owns 6,114,532 of the Partnership's common limited partner units representing approximately 15.8% 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 Corporation 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.

Impact on Partners' Capital (Deficit) Related to Transactions Between Entities Under Common Control

Under ASC 805, assets and liabilities transferred between entities under common control are accounted for at the historical cost of those entities' ultimate parent, in a manner similar to a pooling of interests. Any difference in the amount paid by the transferee versus the historical cost of the assets transferred is recorded as an adjustment to equity (contribution or distribution) by the transferee. This is in contrast with a business combination between unrelated parties, where assets and liabilities are recorded at their fair values at the acquisition date, with any excess of amounts paid over the fair value representing goodwill. From time to time, the most recent being in 2019, the Partnership has entered into common control acquisitions from Martin Resource Management Corporation. The consideration transferred totaling $550,773 exceeds the historical cost of the net assets received. This excess of the purchase price over the historical cost of the net assets received has resulted in cumulative distributions of $287,734 reflected as reductions to Partners' capital.

19

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

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 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.

The general partner was allocated no incentive distributions during the nine months ended September 30, 2021 and 2020.

 

Distributions of Available Cash

The Partnership distributes all of its available cash (as defined in the Partnership Agreement) within 45 days after the end of each quarter to unitholders of record and to the general partner. Available cash is generally defined as all cash and cash equivalents of the Partnership on hand at the end of each quarter less the amount of cash reserves its general partner determines in its reasonable discretion is necessary or appropriate to: (i) provide for the proper conduct of the Partnership’s business; (ii) comply with applicable law, any debt instruments or other agreements; or (iii) provide funds for distributions to unitholders and the general partner for any one or more of the next four quarters, plus all cash on the date of determination of available cash for the quarter resulting from working capital borrowings made after the end of the quarter.

Net Income per Unit

The Partnership follows the provisions of the FASB ASC 260-10 related to earnings per share, which addresses the application of the two-class method in determining income per unit for master limited partnerships having multiple classes of securities that may participate in partnership distributions accounted for as equity distributions. Undistributed earnings are allocated to the general partner and limited partners utilizing the contractual terms of the Partnership Agreement. Distributions to the general partner pursuant to the IDRs are limited to available cash that will be distributed as defined in the Partnership Agreement. Accordingly, the Partnership does not allocate undistributed earnings to the general partner for the IDRs because the general partner's share of available cash is the maximum amount that the general partner would be contractually entitled to receive if all earnings for the period were distributed. When current period distributions are in excess of earnings, the excess distributions for the period are to be allocated to the general partner and limited partners based on their respective sharing of income and losses specified in the Partnership Agreement. Additionally, as required under FASB ASC 260-10-45-61A, unvested share-based payments that entitle employees to receive non-forfeitable distributions are considered participating securities, as defined in FASB ASC 260-10-20, for earnings per unit calculations.

For purposes of computing diluted net income per unit, the Partnership uses the more dilutive of the two-class and if-converted methods. Under the if-converted method, the weighted-average number of subordinated units outstanding for the period is added to the weighted-average number of common units outstanding for purposes of computing basic net income per unit and the resulting amount is compared to the diluted net income per unit computed using the two-class method. The following is a reconciliation of net income allocated to the general partner and limited partners for purposes of calculating net income attributable to limited partners per unit:

20

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

			Three Months Ended September 30,												Nine Months Ended September 30,
			2021						2020						2021						2020
Net loss			$	(6,911)					$	(10,819)					$	(11,012)					$	(4,207)
Less general partner’s interest in net loss:
Distributions payable on behalf of general partner interest			4						4						12						57
General partner interest in undistributed loss			(142)						(220)						(232)						(141)
Less loss allocable to unvested restricted units			(20)						(53)						(30)						(8)
Limited partners’ interest in net loss			$	(6,753)					$	(10,550)					$	(10,762)					$	(4,115)

    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,
			2021						2020						2021						2020
Basic weighted average limited partner units outstanding			38,687,874						38,661,852						38,689,434						38,654,891
Dilutive effect of restricted units issued			—						—						—						—
Total weighted average limited partner diluted units outstanding			38,687,874						38,661,852						38,689,434						38,654,891

    All outstanding units were included in the computation of diluted earnings per unit and weighted based on the number of days such units were outstanding during the periods presented. All common unit equivalents were antidilutive for the three and nine months ended September 30, 2021 and 2020 because the limited partners were allocated a net loss in this period.

NOTE 10. UNIT BASED AWARDS

The Partnership recognizes compensation cost related to unit-based awards to both employees and non-employees in its consolidated and condensed financial statements in accordance with certain provisions of ASC 718. Amounts recognized in operating expense and 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,
			2021						2020						2021						2020
Restricted unit Awards
Employees			$	—					$	305					$	194					$	907
Non-employee directors			48						56						142						163
Phantom unit Awards
Employees			181						—						181						—
Non-employee directors			—						—						—						—
Total unit-based compensation expense			$	229					$	361					$	517					$	1,070

21

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

Long-Term Incentive Plans

    

      The Partnership's general partner has long-term incentive plans for employees and directors of the general partner and its affiliates who perform services for the Partnership.

Phantom Unit Plan

On July 21, 2021, the board of directors of the general partner of the Partnership and the Compensation Committee approved the Martin Midstream Partners L.P. 2021 Phantom Unit Plan (the “Plan”), effective as of the same date. The Plan permits the awards of phantom units and phantom unit appreciation rights (collectively, "phantom unit awards") to any employee or non-employee director of the Partnership, including its executive officers. The awards may be time-based or performance-based and will be paid, if at all, in cash.

The award of a phantom unit entitles the participant to a cash payment equal to the value of the phantom unit on the vesting date or dates, which value is the fair market value of a common unit of the Partnership (a “Unit”) on such vesting date or dates. The award of a phantom unit appreciation right entitles the recipient to a cash payment equal to the difference between the value of a phantom unit on the vesting date or dates in excess of the value assigned by the Compensation Committee to the phantom unit as of the grant date. Phantom units and phantom unit appreciation rights granted to participants do not confer upon participants any right to a Unit.

On July 21, 2021, the Compensation Committee approved forms of time-based award agreements for phantom units and phantom unit appreciation rights, both of which awards vest in full on the third anniversary of the grant date. The grant date value of a phantom unit under a phantom unit appreciation right award is equal to the average of the closing price for a Unit during the 20 trading days immediately preceding the grant date of the award.

Generally, vesting of an award is subject to a participant remaining continuously employed with the Partnership through the vesting date. However, if prior to the vesting date (i) a participant is terminated without cause (as defined in the award agreement) or terminates employment after the participant has attained both the age of 65 and ten years of employment (“retirement-eligible”), a prorated portion of the award will vest and be paid in cash no later than the 30th day following such termination date (subject to a six-month delay in payment for certain retirement-eligible participants) or (ii) there is a change in control of the Partnership (as defined in the Plan), the award will vest in full and be paid in cash no later than the 30th day following the date of the change of control; provided, that the participant has been in continuous employment through the termination or change in control date, as applicable.

On July 21, 2021, 620,000 phantom units and 1,245,000 phantom unit appreciation rights were granted to employees of the general partner and its affiliates who perform services for the Partnership.

Phantom unit awards are recorded in operating expense and selling, general and administrative expense based on the fair value of the vested portion of the awards on the balance sheet date. The fair value of these awards is updated at each balance sheet date and changes in the fair value of the vested portions of the awards are recorded as increases or decreases to compensation expense within operating expense and selling, general and administrative expense in the Consolidated and Condensed Statements of Operations. All of the Partnership's outstanding phantom unit awards at September 30, 2021 met the criteria to be treated under liability classification in accordance with ASC 718, given that these awards will settle in cash on the vesting date.

Compensation expense for the phantom awards is based on the fair value of the units as of the balance sheet date as further discussed below, and such costs are recognized ratably over the service period of the awards. As the fair value of liability awards is required to be re-measured each period end, stock compensation expense amounts recognized in future periods for these awards will vary. The estimated future cash payments of these awards are presented as liabilities within "Other current liabilities" and "Other long-term obligations" in the Consolidated and Condensed Balance Sheets.As of September 30, 2021, there was a total of $2,021 of unrecognized compensation costs related to non-vested phantom unit awards. These costs are expected to be recognized over a remaining life of 2.81 years.

22

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

The fair value of the phantom unit awards was estimated using a Monte Carlo valuation model as of the balance sheet date. The Monte Carlo valuation model is based on random projections of stock price paths and must be repeated numerous times to achieve a probabilistic assessment. Expected volatility was calculated based on the historical volatility of the Partnership’s common units as well as set of peer companies.

Restricted Unit Plan    

On May 26, 2017, the unitholders of the Partnership approved the Martin Midstream Partners L.P. 2017 Restricted Unit Plan (the "2017 LTIP"). The 2017 LTIP 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 2017 LTIP 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 ("TBRUs"), 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 "PBRUs"). 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. PBRUs are earned only upon our achievement of an objective performance measure for the performance period. PBRUs 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 performance conditions related to the PBRUs awarded on March 1, 2018 were not achieved and the Partnership treated these units as forfeited at expiration on March 31, 2021. As such, the Partnership did not recognize compensation expense related to these units.

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. All of the Partnership's outstanding restricted unit awards at September 30, 2021 met the criteria to be treated under equity classification.

In February 2021, the Partnership issued 14,056 TBRUs to each of the Partnership's three independent directors under the 2017 LTIP.  These restricted common units vest in equal installments of 3,514 units on January 24, 2022, 2023, 2024, and 2025.

23

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

    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, 2021 is provided below:

			Number of Units						Weighted Average Grant-Date Fair Value Per Unit
Non-vested, beginning of period			273,424						$	10.52
Granted (TBRU)			42,168						$	2.49
Vested			(117,280)						$	11.96
Forfeited			(83,436)						$	13.90
Non-Vested, end of period			114,876						$	3.65
Aggregate intrinsic value, end of period			$	368

    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 three and nine months ended September 30, 2021 and 2020 is provided below:

			Three Months Ended September 30,												Nine Months Ended September 30,
			2021						2020						2021						2020
Aggregate intrinsic value of units vested			$	—					$	—					$	257					$	151
Fair value of units vested			—						—						1,418						1,427

    As of September 30, 2021, there was $296 of unrecognized compensation cost related to non-vested restricted units. That cost is expected to be recognized over a weighted-average period of 2.69 years.

NOTE 11. RELATED PARTY TRANSACTIONS

As of September 30, 2021, Martin Resource Management Corporation owns 6,114,532 of the Partnership’s common units representing approximately 15.8% of the Partnership’s outstanding limited partner units.  Martin Resource Management Corporation 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 Corporation’s ownership as of September 30, 2021, effectively gives Martin Resource Management Corporation 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 Corporation 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 Corporation and the Partnership’s use of certain Martin Resource Management Corporation 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 Corporation.

24

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

    Non-Competition Provisions. Martin Resource Management Corporation 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 land and marine transportation of petroleum products, by-products, and chemicals;

•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 Corporation, including the following:

◦distributing asphalt, marine fuel and other liquids;

◦providing shore-based marine services in Texas, Louisiana, Mississippi, and Alabama;

◦operating a crude oil gathering business in Stephens, Arkansas;

◦providing crude oil gathering 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;

◦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, and South Houston, Texas.

•any business that Martin Resource Management Corporation acquires or constructs that has a fair market value of less than $5,000;

•any business that Martin Resource Management Corporation 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 Corporation 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 Corporation 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 Corporation 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

25

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

monetary limitation on the amount the Partnership is required to reimburse Martin Resource Management Corporation for direct expenses.  In addition to the direct expenses, under the Omnibus Agreement, the Partnership is required to reimburse Martin Resource Management Corporation for indirect general and administrative and corporate overhead expenses.

    Effective January 1, 2021, through December 31, 2021, the Conflicts Committee approved an annual reimbursement amount for indirect expenses of $14,386. The Partnership reimbursed Martin Resource Management Corporation for $3,597 and $4,103 of indirect expenses for the three months ended September 30, 2021 and 2020, respectively.  The Partnership reimbursed Martin Resource Management Corporation for $10,790 and $12,364 of indirect expenses for the nine months ended September 30, 2021 and 2020, 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 Corporation provides to 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 Corporation retained businesses. The provisions of the Omnibus Agreement regarding Martin Resource Management Corporation’s services will terminate if Martin Resource Management Corporation 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 Corporation 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 Corporation 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 Corporation 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 Corporation.  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 Corporation.  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 Corporation for general and administrative services performed on its behalf, will terminate if the Partnership is no longer an affiliate of Martin Resource Management Corporation.

Master Transportation Services Agreement

    Master Transportation Agreement.  Martin Transport, Inc. ("MTI"), a wholly owned subsidiary of the Partnership, is a party to a master transportation services agreement effective January 1, 2019, with certain wholly owned subsidiaries of Martin Resource Management Corporation. Under the agreement, MTI agreed to transport Martin Resource Management Corporation's petroleum products and by-products.

    Term and Pricing. The agreement will continue unless either party terminates the agreement by giving at least 30 days' written notice to the other party.  The rates under the agreement are subject to any adjustments which are mutually agreed upon or in accordance with a price index. Additionally, 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 agreed to indemnify Martin Resource Management Corporation against all claims arising out of the negligence or willful misconduct of MTI and its officers, employees, agents, representatives and subcontractors. Martin Resource Management Corporation has agreed to indemnify MTI against all claims arising out of the negligence or willful misconduct of Martin Resource Management Corporation and its officers, employees, agents, representatives and

26

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

subcontractors. In the event a claim is the result of the joint negligence or misconduct of MTI and Martin Resource Management Corporation, 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 Corporation 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 Corporation are based on applicable market rates.

    Marine Fuel.  The Partnership is a party to an agreement with Martin Resource Management Corporation dated November 1, 2002, under which Martin Resource Management Corporation 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 Corporation.

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 Corporation 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, October 1, 2017, April 1, 2019, and January 1, 2020 to modify its minimum throughput requirements and throughput fees. The term of this agreement is currently evergreen and it will continue 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.   Further, certain capital improvements, to the extent requested by Cross, are reimbursed through a capital recovery fee.  As of December 31, 2019, the annual capital recovery fee reimbursement of $2,088 expired. An additional $2,586 of capital recovery fee reimbursement expired on December 31, 2020.  All of these fees (other than the fuel surcharge and capital recovery fee) are subject to escalation annually based upon the greater of 3% or the increase in the Consumer Price Index for a specified annual period. Also, the Partnership renegotiated a crude transportation contract set to expire in the first half of 2022, resulting in a reduction in revenue of $2,145 annually beginning January 1, 2020.

East Texas Mack Leases. MTI leases equipment, including tractors and trailers, from East Texas Mack Sales ("East Texas Mack"). Certain of our directors or officers are owners of East Texas Mack, including entities affiliated with Ruben Martin, who owns approximately 46% of the issued and outstanding stock of East Texas Mack. Amounts paid to East Texas Mack for tractor and trailer lease payments and lease residuals for the three months ended September 30, 2021 and 2020 were

27

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

$283 and $173, respectively. Amounts paid to East Texas Mack for tractor and trailer lease payments and lease residuals for the nine months ended September 30, 2021 and 2020 were $801 and $432, respectively.

    Other Miscellaneous Agreements. From time to time the Partnership enters into other miscellaneous agreements with Martin Resource Management Corporation 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,
			2021						2020						2021						2020
Revenues:
Terminalling and storage			$	15,866					$	15,902					$	46,741					$	47,718
Transportation			5,564						5,514						14,463						16,801
Product sales:
Sulfur services			28						5						87						33
Terminalling and storage			40						64						166						166
			68						69						253						199
			$	21,498					$	21,485					$	61,457					$	64,718

    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,
			2021						2020						2021						2020
Cost of products sold:
Sulfur services			$	2,441					$	2,512					$	7,379					$	7,833
Terminalling and storage			7,259						4,303						18,863						14,329
			$	9,700					$	6,815					$	26,242					$	22,162

    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,
			2021						2020						2021						2020
Operating expenses:
Transportation			$	13,949					$	13,009					$	40,652					$	41,950
Natural gas liquids			534						486						1,511						1,481
Sulfur services			1,321						1,120						3,370						3,403
Terminalling and storage			4,284						4,300						12,513						13,292
			$	20,088					$	18,915					$	58,046					$	60,126

28

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

    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,
			2021						2020						2021						2020
Selling, general and administrative:
Transportation			$	1,732					$	1,803					$	5,103					$	5,459
Natural gas liquids			576						772						2,660						2,009
Sulfur services			813						765						2,320						2,254
Terminalling and storage			878						863						2,530						2,536
Indirect, including overhead allocation			3,660						4,153						11,011						12,465
			$	7,659					$	8,356					$	23,624					$	24,723

NOTE 12. BUSINESS SEGMENTS

    The Partnership has four reportable segments: (1) terminalling and storage, (2) transportation, (3) sulfur services and (4) natural gas liquids. 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, 2020, filed with the SEC on March 3, 2021. The Partnership evaluates the performance of its reportable segments based on operating income. There is no allocation of interest expense.

Three Months Ended September 30, 2021			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			51,226						(1,648)						49,578						7,049						3,269						2,087
Transportation			42,568						(3,489)						39,079						3,710						430						1,086
Sulfur services			30,837						—						30,837						2,594						4,534						1,104
Natural gas liquids			91,764						—						91,764						592						3,994						20
Indirect selling, general and administrative			—						—						—						—						(4,074)						—
Total			$	216,395					$	(5,137)					$	211,258					$	13,945					$	8,153					$	4,297

Three Months Ended September 30, 2020			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			48,188						(1,823)						46,365						7,294						6,426						1,863
Transportation			35,712						(3,774)						31,938						4,412						(2,673)						1,785
Sulfur services			21,880						—						21,880						2,953						7,115						1,393
Natural gas liquids			52,350						—						52,350						617						4,668						173
Indirect selling, general and administrative			—						—						—						—						(4,523)						—
Total			$	158,130					$	(5,597)					$	152,533					$	15,276					$	11,013					$	5,214

    

29

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

Nine Months Ended September 30, 2021			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			$	136,584					$	(4,918)					$	131,666					$	21,150					$	8,153					$	6,258
Transportation			114,886						(11,066)						103,820						12,039						(7,782)						2,702
Sulfur services			103,958						—						103,958						7,882						21,136						4,968
Natural gas liquids			257,081						—						257,081						1,791						21,738						481
Indirect selling, general and administrative			—						—						—						—						(11,773)						—
Total			$	612,509					$	(15,984)					$	596,525					$	42,862					$	31,472					$	14,409

Nine Months Ended September 30, 2020			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			$	146,298					$	(5,091)					$	141,207					$	22,022					$	10,153					$	8,885
Transportation			116,145						(13,781)						102,364						13,020						(9,772)						6,483
Sulfur services			83,636						(13)						83,623						8,978						29,787						6,267
Natural gas liquids			164,865						(5)						164,860						1,838						17,661						348
Indirect selling, general and administrative			—						—						—						—						(13,256)						—
Total			$	510,944					$	(18,890)					$	492,054					$	45,858					$	34,573					$	21,983

    The Partnership's assets by reportable segment as of September 30, 2021 and December 31, 2020, are as follows:

			September 30, 2021						December 31, 2020
Total assets:
Terminalling and storage			$	249,723					$	252,794
Transportation			142,767						151,953
Sulfur services			97,986						94,154
Natural gas liquids			123,762						80,737
Total assets			$	614,238					$	579,638

NOTE 13. COMMITMENTS 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.

    

    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

30

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

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.  Further, the same customer has made a claim under the Partnership’s insurance policy.  The insurer has denied the claim.  However, in the event that the customer is successful in pursuing the claim, such action would negatively impact the Partnership because the Partnership may have certain reimbursement obligations it would owe the insurance company.  If the case is reopened or the insurance claim by the customer is successful, we are currently unable to determine the exposure we may have in this matter, if any.

NOTE 14. 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, 2021						December 31, 2020
Commodity derivative contracts, net			$	(5,049)					$	(207)

    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.

•Current and non-current portion of 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 estimated fair value of the 2021 Notes, 2024 Notes, and 2025 Notes (collectively, the "Senior Notes") is considered Level 1, as the fair value is based on quoted market prices in active markets.

			September 30, 2021												December 31, 2020
			Carrying Value						Fair Value						Carrying Value						Fair Value
2021 Notes			$	—					$	—					$	28,790					$	28,581
2024 Notes			$	51,031					$	55,126					$	50,173					$	55,214
2025 Notes			$	290,563					$	302,797					$	290,250					$	288,692
Total			$	341,594					$	357,923					$	369,213					$	372,487

NOTE 15. CONDENSED CONSOLIDATED FINANCIAL INFORMATION

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

    The Partnership's operations are conducted by its operating subsidiaries as it has no independent assets or operations. Martin Operating Partnership L.P. (the "Operating Partnership"), the Partnership’s wholly-owned subsidiary, and the Partnership's other operating subsidiaries have issued in the past, and may issue in the future, unconditional guarantees of senior or subordinated debt securities of the Partnership. The guarantees that have been issued are full, irrevocable and unconditional and joint and several. In addition, the Operating Partnership may also issue senior or subordinated debt securities which, if issued, will be fully, irrevocably and unconditionally guaranteed by the Partnership. Substantially all of the Partnership's operating subsidiaries are subsidiary guarantors of its Senior Notes and any subsidiaries other than the subsidiary guarantors are minor.

    

NOTE 16. INCOME TAXES

			Three Months Ended September 30,												Nine Months Ended September 30,
			2021						2020						2021						2020
Provision for income taxes			$	954					$	373					$	2,111					$	1,510

The operations of a partnership are generally not subject to income taxes, except for Texas margin tax, because its income is taxed directly to its partners. MTI, a wholly owned subsidiary of the Partnership, is subject to income taxes due to its corporate structure (the "Taxable Subsidiary"). Total income tax expense of $895 and $225, related to the operation of the Taxable Subsidiary, for the three months ended September 30, 2021 and 2020, resulted in an effective income tax rate ("ETR") of 23.42% and 45.72%, respectively. Total income tax expense of $1,871 and $1,162, related to the operation of the Taxable Subsidiary, for the nine months ended September 30, 2021 and 2020, resulted in an ETR of 29.51% and 80.42%, respectively.

The decrease in the ETR for the income taxes during the three and nine months ended September 30, 2021, was primarily due to significantly larger pretax income recorded for both the three and nine months ended September 30, 2021 compared to the similar periods in 2020. The increase in the provision for income taxes for the three and nine months ended September 30, 2021, compared to similar periods in 2020, was primarily due to an increase in income before income taxes in the current period.

    A current federal income tax expense (benefit) of $153 and $0, related to the operation of the Taxable Subsidiary, was recorded for the three months ended September 30, 2021 and 2020, respectively. A current federal income tax expense (benefit) of $276 and $(174), related to the operation of the Taxable Subsidiary, was recorded for the nine months ended September 30, 2021 and 2020, respectively. A current state income tax expense of $81 and $41, related to the operation of the Taxable Subsidiary, was recorded for the three months ended September 30, 2021 and 2020, respectively. A current state income tax expense of $177 and $134, related to the operation of the Taxable Subsidiary, was recorded for the nine months ended September 30, 2021 and 2020, respectively.

With respect to MTI, income taxes are accounted for under the asset and liability method pursuant to the provisions of ASC 740 related to income taxes. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.

    A deferred tax expense related to the MTI temporary differences of $661 and $183 was recorded for the three months ended September 30, 2021 and 2020, respectively. A deferred tax expense related to the MTI temporary differences of $1,419 and $1,202 was recorded for the nine months ended September 30, 2021 and 2020, respectively. A net deferred tax asset of $20,834 and $22,253, related to the cumulative book and tax temporary differences, existed at September 30, 2021 and December 31, 2020, respectively.

    All income tax positions taken for all open years are more likely than not to be sustained based upon their technical merit under applicable tax laws.

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MARTIN MIDSTREAM PARTNERS L.P.

NOTES TO CONSOLIDATED AND CONDENSED FINANCIAL STATEMENTS

(Dollars in thousands, except where otherwise indicated)

September 30, 2021

(Unaudited)

NOTE 17. SUBSEQUENT EVENTS

Quarterly Distribution. On October 20, 2021, the Partnership declared a quarterly cash distribution of $0.005 per common unit for the third quarter of 2021, or $0.020 per common unit on an annualized basis, which will be paid on November 12, 2021 to unitholders of record as of November 5, 2021.

    

    

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Item 2.			Management’s Discussion and Analysis of Financial Condition and Results of Operations

    You should read the following discussion of our financial condition and results of operations in conjunction with the consolidated and condensed financial statements and the notes thereto included elsewhere in this quarterly report.

Overview

 

We are a publicly traded limited partnership with a diverse set of operations focused primarily in the U.S. Gulf Coast region. Our four primary business lines include:

•Terminalling, processing, storage and packaging services for petroleum products and by-products including the refining of naphthenic crude oil;

•Land and marine transportation services for petroleum products and by-products, chemicals, and specialty products;

•Sulfur and sulfur-based products processing, manufacturing, marketing, and distribution; and

•NGL marketing, distribution, and transportation services.

The petroleum products and by-products we collect, transport, store and market are produced primarily by major and independent oil and gas companies who often turn to third parties, such as us, for the transportation and disposition of these products. In addition to these major and independent oil and gas companies, our primary customers include independent refiners, large chemical companies, and other wholesale purchasers of these products. We operate primarily in the U.S. Gulf Coast region. This region is a major hub for petroleum refining, natural gas gathering and processing, and support services for the exploration and production industry.

    We were formed in 2002 by Martin Resource Management Corporation, a privately-held company whose initial predecessor was incorporated in 1951 as a supplier of products and services to drilling rig contractors. Since then, Martin Resource Management Corporation has expanded its operations through acquisitions and internal expansion initiatives as its management identified and capitalized on the needs of producers and purchasers of petroleum products and by-products and other bulk liquids. Martin Resource Management Corporation is an important supplier and customer of ours. As of September 30, 2021, Martin Resource Management Corporation owned 15.8% of our total outstanding common limited partner units. Furthermore, Martin Resource Management Corporation controls Martin Midstream GP LLC ("MMGP"), our general partner, by virtue of its 51% voting interest in MMGP Holdings, LLC ("Holdings"), the sole member of MMGP. MMGP owns a 2.0% general partner interest in us and all of our incentive distribution rights. Martin Resource Management Corporation directs our business operations through its ownership interests in and control of our general partner.

    We entered into the Omnibus Agreement 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 Corporation and our use of certain of Martin Resource Management Corporation’s trade names and trademarks. Under the terms of the Omnibus Agreement, the employees of Martin Resource Management Corporation are responsible for conducting our business and operating our assets.

    Martin Resource Management Corporation has operated our business since our inception in 2002.  Martin Resource Management Corporation began operating our NGL business in the 1950s and our sulfur business in the 1960s. It began our land transportation business in the early 1980s and our marine transportation business in the late 1980s. It entered into our fertilizer and terminalling and storage businesses in the early 1990s.

Significant Recent Developments

Hurricane Ida. On August 29, 2021, Hurricane Ida ("Ida") made landfall in Southeast Louisiana as a category 4 hurricane. The effects of Ida did not have a material impact on our Gulf Coast shore-based terminal operations nor did we experience any material storm-related damage. As of September 30, 2021, we have spent approximately $0.2 million on restoration and recovery costs as a result of Ida and expect the total spend to be approximately $0.2 million.

Winter Storm Uri. In February 2021, we experienced Winter Storm Uri ("Uri"), an unprecedented storm bringing extreme cold temperatures to Texas and the surrounding areas, which resulted in gulf coast refineries running at reduced rates or halting operations entirely. The majority of the impact we experienced was centered around our transportation and sulfur

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services segments where we saw reduced activity due to Uri's impact on Gulf Coast refinery utilization. Additionally, our Smackover Refinery was down approximately nine days due to Uri, during which time we began preparations for the previously scheduled turnaround in March of 2021. This allowed us to minimize the amount of downtime at the Smackover Refinery which was back in operation by March 9, 2021.

COVID-19. We continue to monitor the impacts of the COVID-19 pandemic (including variants of the virus) on all aspects of our business. Travel restrictions and stay-at-home orders in place during much of 2020 that were implemented by governments in many regions and countries across the globe, including the U.S., have greatly impacted the demand for refined products resulting in a significant reduction in refinery utilization, which impacted our 2020 performance and continues to impact our marine transportation business in 2021.

Looking forward, we expect to continue to experience some adverse impacts of COVID-19 in our marine transportation segment but we believe that refinery utilization will continue to increase in the second half of 2021 as a result of widespread vaccinations, government stimulus, and a rebounding economy. This should ultimately improve refined product demand as people generally return to in-person work and resume travel. We expect this will positively impact our marine transportation business as demand for our services improves.

Overall, the extent to which the duration and severity of the pandemic impacts our business, results of operations, and financial condition will depend on future developments, which are highly uncertain and cannot be predicted at this time. Accordingly, it is possible that the impact of the pandemic, including the impact of variants of COVID-19, such as the Delta variant, could have a material adverse effect on the Partnership's results of operations, financial position and cash flows for the year ended December 31, 2021 including the recoverability of long-lived assets and goodwill, the valuation of inventory, and the amount of expected credit losses.

Management considered the impact of the pandemic on the assumptions and estimates used in the preparation of the financial statements. A sustained reduction in refinery demand and utilization could lead to future asset impairments as well as adversely affect access to capital and financing to be able to meet future obligations. Management also assessed the extent to which the current macroeconomic events brought about by the pandemic and significant declines in refined product demand impacted the valuation of expected credit losses on accounts receivable and certain inventory items or resulted in modifications to any significant contracts. Ultimately the results of these assessments did not have a material impact on our results as of September 30, 2021.

Sale of Mega Lubricants. On December 22, 2020, we entered into an asset purchase and sale agreement to sell certain assets used in connection with our Mega Lubricants shore-based terminals business ("Mega Lubricants") to John W. Stone Oil Distributor, LLC ("Stone Oil") for $22.4 million. Mega Lubricants is engaged in the business of blending, manufacturing and delivering various marine application lubricants, sub-sea specialty fluids, and proprietary commercial and industrial products. The transaction closed on December 22, 2020. The proceeds from the transaction were used to reduce outstanding borrowings under our revolving credit facility.

          

Subsequent Events

Quarterly Distribution. On October 20, 2021, we declared a quarterly cash distribution of $0.005 per common unit for the third quarter of 2021, or $0.020 per common unit on an annualized basis, which will be paid on November 12, 2021 to unitholders of record as of November 5, 2021.

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Critical Accounting Policies and Estimates    

    Our discussion and analysis of our financial condition and results of operations are based on the historical consolidated and condensed financial statements included elsewhere herein. We prepared these financial statements in conformity with U.S. GAAP. The preparation of these financial statements requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities at the dates of the financial statements and the reported amounts of revenues and expenses during the reporting periods. We base our estimates on historical experience and on various other assumptions we believe to be reasonable under the circumstances. We routinely evaluate these estimates, utilizing historical experience, consultation with experts and other methods we consider reasonable in the particular circumstances. Our results may differ from these estimates, and any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known. Changes in these estimates could materially affect our financial position, results of operations or cash flows. See the "Critical Accounting Policies and Estimates" section in "Management's Discussion and Analysis of Financial Condition and Results of Operations" and Note 2, "Significant Accounting Policies" in Notes to Consolidated Financial Statements included within our Annual Report on Form 10-K for the year ended December 31, 2020, filed with the SEC on March 3, 2021.

Our Relationship with Martin Resource Management Corporation

 Martin Resource Management Corporation is engaged in the following principal business activities:

•distributing fuel oil, asphalt, 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;

•supplying employees and services for the operation of our business; and

•operating, solely for our account, the asphalt facilities in Omaha, Nebraska, Port Neches, Texas, and South Houston, Texas

We are and will continue to be closely affiliated with Martin Resource Management Corporation as a result of the following relationships.

Ownership

    Martin Resource Management Corporation owns approximately 15.8% of the outstanding limited partner units. In addition, Martin Resource Management Corporation controls MMGP, our general partner, by virtue of its 51% voting interest in Holdings, the sole member of MMGP. MMGP owns a 2% general partner interest in us and all of our incentive distribution rights.

    Management

Martin Resource Management Corporation directs our business operations through its ownership interests in and control of our general partner. We benefit from our relationship with Martin Resource Management Corporation through access to a significant pool of management expertise and established relationships throughout the energy industry. We do not have employees. Martin Resource Management Corporation employees are responsible for conducting our business and operating our assets on our behalf.

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Related Party Agreements

The Omnibus Agreement requires us to reimburse Martin Resource Management Corporation for all direct expenses it incurs or payments it makes on our behalf or in connection with the operation of our business.  We reimbursed Martin Resource Management Corporation for $33.8 million of direct costs and expenses for the three months ended September 30, 2021 compared to $29.9 million for the three months ended September 30, 2020. We reimbursed Martin Resource Management Corporation for $96.9 million of direct costs and expenses for the nine months ended September 30, 2021 compared to $94.5 million for the nine months ended September 30, 2020. There is no monetary limitation on the amount we are required to reimburse Martin Resource Management Corporation for direct expenses.

In addition to the direct expenses, under the Omnibus Agreement, we are required to reimburse Martin Resource Management Corporation for indirect general and administrative and corporate overhead expenses.  In each of the three months ended September 30, 2021 and 2020, the Conflicts Committee approved reimbursement amounts of $3.6 million and $4.2 million, respectively. In each of the nine months ended September 30, 2021 and 2020, the Conflicts Committee approved reimbursement amounts of $10.8 million and $12.5 million, respectively. The Conflicts Committee will review and approve future adjustments in the reimbursement amount for indirect expenses, if any, annually.  These indirect expenses covered the centralized corporate functions Martin Resource Management Corporation provides for us, 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 we share with Martin Resource Management Corporation’s retained businesses.  The Omnibus Agreement also contains significant non-compete provisions and indemnity obligations.  Martin Resource Management Corporation also licenses certain of its trademarks and trade names to us under the Omnibus Agreement.

    These additional agreements include, but are not limited to, a master transportation services agreement, marine transportation agreements, terminal services agreements, a tolling agreement, and a sulfuric acid sales agency agreement. Pursuant to the terms of the Omnibus Agreement, we are prohibited from entering into certain material agreements with Martin Resource Management Corporation without the approval of the Conflicts Committee.

    For a more comprehensive discussion concerning the Omnibus Agreement and the other agreements that we have entered into with Martin Resource Management Corporation, please refer to "Item 13. Certain Relationships and Related Transactions, and Director Independence" set forth in our Annual Report on Form 10-K for the year ended December 31, 2020, filed with the SEC on March 3, 2021.

Commercial

We have been and anticipate that we will continue to be both a significant customer and supplier of products and services offered by Martin Resource Management Corporation. In the aggregate, the impact of related party transactions included in total costs and expenses accounted for approximately 18% and 23% of our total costs and expenses during the three months ended September 30, 2021 and 2020, respectively. In the aggregate, the impact of related party transactions included in total costs and expenses accounted for approximately 19% and 23% of our total costs and expenses during the nine months ended September 30, 2021 and 2020, respectively.

Correspondingly, Martin Resource Management Corporation is one of our significant customers. Our sales to Martin Resource Management Corporation accounted for approximately 10% and 14% of our total revenues for the three months ended September 30, 2021 and 2020, respectively. Our sales to Martin Resource Management Corporation accounted for approximately 10% and 13% of our total revenues for the nine months ended September 30, 2021 and 2020, respectively.

For a more comprehensive discussion concerning the agreements that we have entered into with Martin Resource Management Corporation, please refer to "Item 13. Certain Relationships and Related Transactions, and Director Independence" set forth in our Annual Report on Form 10-K for the year ended December 31, 2020, filed with the SEC on March 3, 2021.

Approval and Review of Related Party Transactions

If we contemplate entering into a transaction, other than a routine or in the ordinary course of business transaction, in which a related person will have a direct or indirect material interest, the proposed transaction is submitted for consideration to the board of directors of our general partner or to our management, as appropriate. If the board of directors of our general partner is involved in the approval process, it determines whether to refer the matter to the Conflicts Committee of our general partner's board of directors, as constituted under our limited partnership agreement. If a matter is referred to the Conflicts

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Committee, it obtains information regarding the proposed transaction from management and determines whether to engage independent legal counsel or an independent financial advisor to advise the members of the committee regarding the transaction.  If the Conflicts Committee retains such counsel or financial advisor, it considers such advice and, in the case of a financial advisor, such advisor’s opinion as to whether the transaction is fair and reasonable to us and to our unitholders.

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How We Evaluate Our Operations

Our management uses a variety of financial and operational measurements other than our financial statements prepared in accordance with U.S. GAAP to analyze our performance. These include: (1) net income before interest expense, income tax expense, and depreciation and amortization ("EBITDA"), (2) adjusted EBITDA, (3) distributable cash flow and (4) adjusted free cash flow. Our management views these measures as important performance measures of core profitability for our operations and the ability to generate and distribute cash flow, and as key components of our internal financial reporting. We believe investors benefit from having access to the same financial measures that our management uses.

EBITDA and Adjusted EBITDA. We define Adjusted EBITDA as EBITDA before unit-based compensation expenses, gains and losses on the disposition of property, plant and equipment, impairment and other similar non-cash adjustments. Certain items excluded from EBITDA and adjusted EBITDA are significant components in understanding and assessing an entity's financial performance, such as cost of capital and historical costs of depreciable assets. We have included information concerning EBITDA and adjusted EBITDA because it provides investors and management with additional information to better understand the following: financial performance of our assets without regard to financing methods, capital structure or historical cost basis; our operating performance and return on capital as compared to those of other similarly situated entities; and the viability of acquisitions and capital expenditure projects. Our method of computing adjusted EBITDA may not be the same method used to compute similar measures reported by other entities. The economic substance behind our use of adjusted EBITDA is to measure the ability of our assets to generate cash sufficient to pay interest costs, support our indebtedness and make distributions to our unitholders.

Distributable Cash Flow. We define Distributable Cash Flow as Adjusted EBITDA less cash paid for interest, cash paid for income taxes, maintenance capital expenditures, and plant turnaround costs. Distributable cash flow is a significant performance measure used by our management and by external users of our financial statements, such as investors, commercial banks and research analysts, to compare basic cash flows generated by us to the cash distributions it expects to pay unitholders. Distributable cash flow is also an important financial measure for our unitholders since it serves as an indicator of our success in providing a cash return on investment. Specifically, this financial measure indicates to investors whether or not we are generating cash flow at a level that can sustain or support an increase in our quarterly distribution rates. Distributable cash flow is also a quantitative standard used throughout the investment community with respect to publicly-traded partnerships because the value of a unit of such an entity is generally determined by the unit's yield, which in turn is based on the amount of cash distributions the entity pays to a unitholder.

Adjusted Free Cash Flow. Adjusted free cash flow is defined as distributable cash flow less growth capital expenditures and principle payments under finance lease obligations. Adjusted free cash flow is a significant performance measure used by our management and by external users of our financial statements and represents how much cash flow a business generates during a specified time period after accounting for all capital expenditures, including expenditures for growth and maintenance capital projects. We believe that adjusted free cash flow is important to investors, lenders, commercial banks and research analysts since it reflects the amount of cash available for reducing debt, investing in additional capital projects, paying distributions, and similar matters. Our calculation of adjusted free cash flow may or may not be comparable to similarly titled measures used by other entities.

EBITDA, adjusted EBITDA, distributable cash flow and adjusted free cash flow should not be considered alternatives to, or more meaningful than, net income, cash flows from operating activities, or any other measure presented in accordance with U.S. GAAP. Our method of computing these measures may not be the same method used to compute similar measures reported by other entities.

Reconciliation of Non-GAAP Financial Measures

The following table reconciles the non-GAAP financial measurements used by management to our most directly comparable GAAP measures for the three and nine months ended September 30, 2021 and 2020.

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Reconciliation of EBITDA, Adjusted EBITDA, Distributable Cash Flow and Adjusted Free Cash Flow

			Three Months Ended												Nine Months Ended
			September 30,												September 30,
			2021						2020						2021						2020
			(in thousands)												(in thousands)
Net loss			$	(6,911)					$	(10,819)					$	(11,012)					$	(4,207)
Less: Loss from discontinued operations, net of income taxes			—						—						—						—
Income (loss) from continuing operations			(6,911)						(10,819)						(11,012)						(4,207)
Adjustments:
Interest expense, net			14,110						12,943						40,372						32,245
Income tax expense			954						373						2,111						1,510
Depreciation and amortization			13,945						15,276						42,862						45,858
EBITDA			22,098						17,773						74,333						75,406
Adjustments:
(Gain) loss on sale of property, plant and equipment, net			(61)						(22)						610						153
Gain on involuntary conversion of property, plant and equipment			(186)						(4,522)						(186)						(4,522)
Unrealized mark-to-market on commodity derivatives			(412)						393						(207)						(276)
Non-cash insurance related accruals			—						—						—						250
Lower of cost or market adjustments			—						35						—						370
Loss on exchange of senior unsecured notes			—						8,516						—						8,516
Gain on repurchase of senior unsecured notes			—						—						—						(3,484)
Non-cash unit-based compensation			48						361						336						1,070
Adjusted EBITDA			21,487						22,534						74,886						77,483
Adjustments:
Interest expense, net			(14,110)						(12,943)						(40,372)						(32,245)
Income tax expense			(954)						(373)						(2,111)						(1,510)
Amortization of debt discount									—						—						—
Amortization of debt premium			—						(38)						—						(191)
Amortization of deferred debt issuance costs			1,064						1,683						2,585						2,674
Deferred income tax expense			661						184						1,419						1,202
Payments for plant turnaround costs			(985)						(406)						(2,679)						(637)
Maintenance capital expenditures			(1,945)						(2,576)						(8,386)						(7,882)
Distributable Cash Flow			$	5,218					$	8,065					$	25,342					$	38,894
Adjustments:
Expansion capital expenditures			$	(1,367)					$	(1,951)					$	(3,344)					$	(9,882)
Principal payments under finance lease obligations			(57)						(799)						(2,648)						(4,021)
Adjusted Free Cash Flow			$	3,794					$	5,315					$	19,350					$	24,991

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Results of Operations

    The results of operations for the three and nine months ended September 30, 2021 and 2020 have been derived from our consolidated and condensed financial statements.

We evaluate segment performance on the basis of operating income, which is derived by subtracting cost of products sold, operating expenses, selling, general and administrative expenses, and depreciation and amortization expense from revenues.  The following table sets forth our operating revenues and operating income by segment for the three and nine months ended September 30, 2021 and 2020.  The results of operations for these interim periods are not necessarily indicative of the results of operations which might be expected for the entire year.

Our consolidated and condensed results of operations are presented on a comparative basis below.  There are certain items of income and expense which we do not allocate on a segment basis.  These items, including interest expense and indirect selling, general and administrative expenses, are discussed following the comparative discussion of our results within each segment.

Three Months Ended September 30, 2021 Compared to the Three Months Ended September 30, 2020

			Operating Revenues						Intersegment Revenues Eliminations						Operating Revenues  after Eliminations						Operating Income (Loss)						Operating Income (Loss) Intersegment Eliminations						Operating Income (Loss)  after Eliminations
Three Months Ended September 30, 2021			(in thousands)
Terminalling and storage			$	51,226					$	(1,648)					$	49,578					$	4,439					$	(1,170)					$	3,269
Transportation			42,568						(3,489)						39,079						3,927						(3,497)						430
Sulfur services			30,837						—						30,837						2,282						2,252						4,534
Natural gas liquids			91,764						—						91,764						1,579						2,415						3,994
Indirect selling, general and administrative			—						—						—						(4,074)						—						(4,074)
Total			$	216,395					$	(5,137)					$	211,258					$	8,153					$	—					$	8,153

			Operating Revenues						Intersegment Revenues Eliminations						Operating Revenues  after Eliminations						Operating Income (Loss)						Operating Income (Loss) Intersegment Eliminations						Operating Income (Loss)  after Eliminations
Three Months Ended September 30, 2020			(in thousands)
Terminalling and storage			$	48,188					$	(1,823)					$	46,365					$	6,975					$	(549)					$	6,426
Transportation			35,712						(3,774)						31,938						1,127						(3,800)						(2,673)
Sulfur services			21,880						—						21,880						5,580						1,535						7,115
Natural gas liquids			52,350						—						52,350						1,854						2,814						4,668
Indirect selling, general and administrative			—						—						—						(4,523)						—						(4,523)
Total			$	158,130					$	(5,597)					$	152,533					$	11,013					$	—					$	11,013

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Nine Months Ended September 30, 2021 Compared to the Nine Months Ended September 30, 2020

			Operating Revenues						Intersegment Revenues Eliminations						Operating Revenues  after Eliminations						Operating Income (Loss)						Operating Income (Loss) Intersegment Eliminations						Operating Income (Loss)  after Eliminations
Nine Months Ended September 30, 2021			(in thousands)
Terminalling and storage			$	136,584					$	(4,918)					$	131,666					$	11,567					$	(3,414)					$	8,153
Transportation			114,886						(11,066)						103,820						3,286						(11,068)						(7,782)
Sulfur services			103,958						—						103,958						15,032						6,104						21,136
Natural gas liquids			257,081						—						257,081						13,360						8,378						21,738
Indirect selling, general and administrative			—						—						—						(11,773)						—						(11,773)
Total			$	612,509					$	(15,984)					$	596,525					$	31,472					$	—					$	31,472

			Operating Revenues						Intersegment Revenues Eliminations						Operating Revenues  after Eliminations						Operating Income (Loss)						Operating Income (Loss) Intersegment Eliminations						Operating Income (Loss)  after Eliminations
Nine Months Ended September 30, 2020			(in thousands)
Terminalling and storage			$	146,298					$	(5,091)					$	141,207					$	11,356					$	(1,203)					$	10,153
Transportation			116,145						(13,781)						102,364						4,071						(13,843)						(9,772)
Sulfur services			83,636						(13)						83,623						24,261						5,526						29,787
Natural gas liquids			164,865						(5)						164,860						8,141						9,520						17,661
Indirect selling, general and administrative			—						—						—						(13,256)						—						(13,256)
Total			$	510,944					$	(18,890)					$	492,054					$	34,573					$	—					$	34,573

 

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Terminalling and Storage Segment

Comparative Results of Operations for the Three Months Ended September 30, 2021 and 2020

			Three Months Ended September 30,												Variance						Percent Change
			2021						2020
			(In thousands, except BBL per day)
Revenues:
Services			$	20,628					$	22,512					$	(1,884)					(8)		%
Products			30,598						25,676						4,922						19		%
Total revenues			51,226						48,188						3,038						6		%
Cost of products sold			24,618						20,381						4,237						21		%
Operating expenses			13,789						12,064						1,725						14		%
Selling, general and administrative expenses			1,528						1,537						(9)						(1)		%
Depreciation and amortization			7,049						7,294						(245)						(3)		%
			4,242						6,912						(2,670)						(39)		%
Other operating income, net			11						1						10						1,000		%
Gain on involuntary conversion of property, plant and equipment			186						62						124						200		%
Operating income			$	4,439					$	6,975					$	(2,536)					(36)		%
Shore-based throughput volumes (guaranteed minimum) (gallons)			20,000						20,000						—						—		%
Smackover refinery throughput volumes (guaranteed minimum BBL per day)			6,500						6,500						—						—		%

    

Services revenues. Services revenues decreased $1.9 million, of which $1.0 million was primarily a result of contract termination fees, and $0.9 million was related to the disposition of the consigned lube business as part of the Mega Lubricants sale at our shore-based terminals. In addition, revenue at the Smackover refinery decreased $0.2 million primarily due to the expiration of the capital recovery fee of $0.7 million, offset by contractually prescribed, index-based fee adjustments of $0.3 million and natural gas surcharge revenue of $0.1 million.

Products revenues. The disposition of our Mega Lubricants business resulted in a $4.2 million decrease in product revenues at our shore-based terminals. Offsetting this reduction, a 32% increase in average sales price combined with a 7% rise in sales volumes at our blending and packaging facilities resulted in a $9.2 million increase to products revenues.

Cost of products sold. The disposition of our Mega Lubricants business resulted in a $5.0 million decrease in cost of products sold at our shore-based terminals. Offsetting this reduction, a 48% increase in average cost per gallon combined with a 7% rise in sales volumes at our blending and packaging facilities resulted in a $9.3 million increase in cost of products sold.

Operating expenses. Operating expenses increased primarily as a result of utilities of $1.1 million, repairs and maintenance of $0.3 million and lease expense of $0.1 million.

Selling, general and administrative expenses. Selling, general and administrative expenses remained consistent.

Depreciation and amortization. The reduction in depreciation and amortization is primarily the result of asset disposals, offset by capital expenditures.

Other operating income, net. Other operating income, net represents gains and losses from the disposition of property, plant and equipment.

Gain on involuntary conversion of property, plant and equipment.  The $0.2 million gain during the 2021 period is due to insurance proceeds received related to structural damage at one of our shore-based terminals. The $0.1 million gain during the 2020 period is due to insurance proceeds received related to structural damage at one of our specialty terminals during a weather incident at our Neches Terminal in May of 2019.

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Comparative Results of Operations for the Nine Months Ended September 30, 2021 and 2020

			Nine Months Ended September 30,												Variance						Percent Change
			2021						2020
			(In thousands, except BBL per day)
Revenues:
Services			$	60,945					$	66,115					$	(5,170)					(8)		%
Products			75,639						80,183						(4,544)						(6)		%
Total revenues			136,584						146,298						(9,714)						(7)		%
Cost of products sold			60,318						68,066						(7,748)						(11)		%
Operating expenses			39,246						37,269						1,977						5		%
Selling, general and administrative expenses			4,495						4,594						(99)						(2)		%
Depreciation and amortization			21,150						22,022						(872)						(4)		%
			11,375						14,347						(2,972)						(21)		%
Other operating income (loss), net			6						(3,053)						3,059						100		%
Gain on involuntary conversion of property, plant and equipment			186						62						124						200		%
Operating income			$	11,567					$	11,356					$	211					2		%
Shore-based throughput volumes (guaranteed minimum) (gallons)			60,000						60,000						—						—		%
Smackover refinery throughput volumes (guaranteed minimum) (BBL per day)			6,500						6,500						—						—		%

Services revenues. Services revenues decreased $5.2 million, of which $3.5 million was primarily a result of the disposition of the consigned lube business as part of the Mega Lubricants sale as well as a $1.0 million decrease related to contract termination fees at our shore-based terminals. In addition, revenue at the Smackover refinery decreased $1.0 primarily due to the expiration of the capital recovery fee of $1.9 million, offset by $0.9 million in contractually prescribed, index-based fee adjustments. Offsetting these decreases were increases at our specialty terminals related to storage revenue of $0.4 million and service revenue of $0.2 million.

Products revenues. The disposition of our Mega Lubricants business resulted in a $17.1 million decrease in product revenues at our shore-based terminals. Offsetting this reduction, a 14% increase in average sales price and a 5% rise in sales volumes at our blending and packaging facilities resulted in a $12.8 million increase to products revenues.

Cost of products sold. The disposition of our Mega Lubricants business resulted in a $19.4 million decrease in cost of products sold at our shore-based terminals. Offsetting this reduction, an 18% increase in average cost per gallon and a 5% rise in sales volumes at our blending and packaging facilities resulted in an $11.8 million increase in cost of products sold.

Operating expenses. Operating expenses increased primarily as a result of utilities of $1.7 million, insurance premiums of $0.5 million, repairs and maintenance of $0.3 million, and lease expense of $0.2 million offset by lower compensation expense of $0.9 million

Selling, general and administrative expenses. Selling, general and administrative expenses remained consistent.

Depreciation and amortization. The reduction in depreciation and amortization is primarily the result of asset disposals, offset by capital expenditures.

Other operating income (loss), net. Other operating income (loss), net represents gains and losses from the disposition of property, plant and equipment.

Gain on involuntary conversion of property, plant and equipment.  The $0.2 million gain during the 2021 period is due to insurance proceeds received related to structural damage at one of our shore-based terminals. The $0.1 million gain during

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the 2020 period is due to insurance proceeds received related to structural damage at one of our specialty terminals during a weather incident at our Neches Terminal in May of 2019.

Transportation Segment

Comparative Results of Operations for the Three Months Ended September 30, 2021 and 2020

			Three Months Ended September 30,												Variance						Percent Change
			2021						2020
			(In thousands)
Revenues			$	42,568					$	35,712					$	6,856					19		%
Operating expenses			33,053						28,144						4,909						17		%
Selling, general and administrative expenses			1,920						2,050						(130)						(6)		%
Depreciation and amortization			3,710						4,412						(702)						(16)		%
			3,885						1,106						2,779						251		%
Other operating income, net			42						21						21						100		%
Operating income			$	3,927					$	1,127					$	2,800					248		%

Marine Transportation Revenues. Inland revenues decreased $2.7 million, primarily related to lower transportation rates and reduction in marine equipment. Offshore revenues increased $0.5 million primarily due to higher transportation rates. Additionally, ancillary revenue (primarily fuel) increased $0.3 million.

Land Transportation Revenues. Freight revenue increased $5.9 million. Transportation rates increased 22%, resulting in a $5.0 million increase and total miles increased 4%, resulting in a $1.0 million increase. Additionally, fuel surcharge revenue increased $2.8 million.

Operating expenses. The increase in operating expenses is primarily a result of increases in compensation expense of $2.1 million, pass-through expenses (primarily fuel) of $1.6 million, repairs and maintenance of $0.8 million and regulatory taxes of $0.3 million.

Selling, general and administrative expenses. Selling, general and administrative expenses decreased primarily due to decreased compensation expense.

Depreciation and amortization. Depreciation and amortization decreased as a result of disposals and assets being fully depreciated, offset by capital expenditures as well as a transfer of assets between segments during the second quarter of 2021.

Other operating income, net. Other operating income, net represents gains from the disposition of property, plant and equipment.

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Comparative Results of Operations for the Nine Months Ended September 30, 2021 and 2020

			Nine Months Ended September 30,												Variance						Percent Change
			2021						2020
			(In thousands)
Revenues			$	114,886					$	116,145					$	(1,259)					(1)		%
Operating expenses			94,042						91,637						2,405						3		%
Selling, general and administrative expenses			5,578						6,243						(665)						(11)		%
Depreciation and amortization			12,039						13,020						(981)						(8)		%
			$	3,227					$	5,245					$	(2,018)					(38)		%
Other operating income (loss), net			59						(1,174)						1,233						105		%
Operating income			$	3,286					$	4,071					$	(785)					(19)		%

Marine Transportation Revenues. Inland revenues decreased $13.9 million, primarily related to lower utilization, transportation rates, and reduction in marine equipment. Offshore revenues decreased $0.9 million primarily due to lower utilization offset by higher transportation rates. Additionally, ancillary revenue (primarily fuel) decreased $0.3 million.

Land Transportation Revenues. Freight revenue increased primarily due to an 11% increase in transportation rates resulting in a $7.2 million increase and a 3% increase in total miles, resulting in a $2.3 million increase. Additionally, fuel surcharge increased $4.3 million.

Operating expenses. The increase in operating expenses is primarily a result of pass through expenses (primarily fuel) of $2.7 million, repairs and maintenance of $1.3 million, offset by a decrease in outside towing of $1.7 million.

Selling, general and administrative expenses. Selling, general and administrative expenses decreased primarily due to decreased compensation expense.

Depreciation and amortization. Depreciation and amortization decreased as a result of disposals and assets being fully depreciated, offset by capital expenditures as well as a transfer of assets between segments during the second quarter of 2021.

Other operating income (loss), net. Other operating income (loss), net represents losses from the disposition of property, plant and equipment.

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Sulfur Services Segment

Comparative Results of Operations for the Three Months Ended September 30, 2021 and 2020

			Three Months Ended September 30,												Variance						Percent Change
			2021						2020
			(In thousands)
Revenues:
Services			$	2,950					$	2,915					$	35					1		%
Products			27,887						18,965						8,922						47		%
Total revenues			30,837						21,880						8,957						41		%
Cost of products sold			21,799						14,141						7,658						54		%
Operating expenses			2,849						2,501						348						14		%
Selling, general and administrative expenses			1,321						1,166						155						13		%
Depreciation and amortization			2,594						2,953						(359)						(12)		%
			2,274						1,119						1,155						103		%
Other operating income, net			8						1						7						700		%
Operating income			$	2,282					$	1,120					$	1,162					104		%
Sulfur (long tons)			145						154						(9)						(6)		%
Fertilizer (long tons)			57						44						13						30		%
Total sulfur services volumes (long tons)			202						198						4						2		%

 

Services revenues.  Services revenues increased slightly as a result of a contractually prescribed, index-based fee adjustment.

Products revenues.  Products revenues increased $8.4 million as a result of a 44% rise in average sulfur services sales prices. Products revenues increased an additional $0.5 million due to a 2% increase in sales volumes, primarily related to a 30% increase in fertilizer volumes.

Cost of products sold.  A 51% increase in product cost impacted cost of products sold by $7.2 million, resulting from a rise in commodity prices. A 2% increase in sales volumes resulted in an additional increase in cost of products sold of $0.4 million.  Margin per ton increased $5.77, or 24%.

Operating expenses.  Operating expenses increased due to an increase in marine fuel and lube expense of $0.3 million, a rise in insurance premiums and claims of $0.1 million, and an increase in harbor agency fees of $0.1 million. Offsetting this increase was a decrease of $0.1 million in repairs and maintenance.

Selling, general and administrative expenses.   Selling, general and administrative expenses increased $0.1 million in employee related expenses and $0.1 million in corporate overhead.

Depreciation and amortization.   Depreciation and amortization decreased as a result of certain assets being fully depreciated in the prior period as well as a transfer of assets between segments during the three months ended June 30, 2021. A further decline was attributable to reduced amortization of turnaround costs.

Other operating income, net.  Other operating income, net represents gains and losses on the disposition of property, plant and equipment.

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Comparative Results of Operations for the Nine Months Ended September 30, 2021 and 2020    

			Nine Months Ended September 30,												Variance						Percent Change
			2021						2020
			(In thousands)
Revenues:
Services			$	8,849					$	8,744					$	105					1		%
Products			95,109						74,892						20,217						27		%
Total revenues			103,958						83,636						20,322						24		%
Cost of products sold			69,619						49,546						20,073						41		%
Operating expenses			7,662						8,553						(891)						(10)		%
Selling, general and administrative expenses			3,777						3,535						242						7		%
Depreciation and amortization			7,882						8,978						(1,096)						(12)		%
			15,018						13,024						1,994						15		%
Other operating income, net			14						6,777						(6,763)						(100)		%
Gain on involuntary conversion of property, plant and equipment			—						4,460						(4,460)						(100)		%
Operating income			$	15,032					$	24,261					$	(9,229)					(38)		%
Sulfur (long tons)			364						503						(139)						(28)		%
Fertilizer (long tons)			236						209						27						13		%
Total sulfur services volumes (long tons)			600						712						(112)						(16)		%

Services revenues.  Services revenues increased slightly as a result of a contractually prescribed, index-based fee adjustment.

Products revenues.  Products revenues increased $38.0 million as a result of a 51% rise in average sulfur services sales prices. Products revenues decreased $17.8 million due to a 16% decrease in sales volumes, primarily related to a 28% decrease in sulfur volumes.

Cost of products sold.  A 67% increase in product cost impacted cost of products sold by $33.1 million, resulting from a rise in commodity prices. A 16% decrease in sales volumes resulted in an offsetting decrease in cost of products sold of $13.0 million.  Margin per ton increased $6.89, or 19%.

Operating expenses.  Operating expenses decreased due to a reduction in outside towing of $0.4 million, repairs and maintenance of marine assets and railcars of $0.3 million, insurance premiums and claims of $0.2 million, assist tugs of $0.2 million, and lease expense of $0.1 million. Offsetting this decrease was an increase in utilities of $0.1 million, marine fuel of $0.1 million, and harbor agency fees of $0.1 million.

Selling, general and administrative expenses.   Selling, general and administrative expenses increased $0.1 million in employee related expenses and $0.1 million in corporate overhead.

Depreciation and amortization.   Depreciation and amortization decreased as a result of certain assets being fully depreciated in the prior period as well as a transfer of assets between segments during the three months ended June 30, 2021. A further decline was attributable to reduced amortization of turnaround costs.

Other operating income, net.  Other operating income, net decreased $2.7 million as a result of business interruption recoveries related to downtime associated with the Neches ship-loader insurance claim received in the first quarter of 2020. An additional $4.1 million decrease is related to a net gain from the disposition of property, plant and equipment during the first quarter of 2020.

Gain on involuntary conversion of property, plant and equipment.  The $4.5 million gain in the nine months ended September 30, 2020 is due to insurance proceeds received related to structural damage of our ship-loader assets during a weather incident at our Neches Terminal in May of 2019.

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Natural Gas Liquids Segment

Comparative Results of Operations for the Three Months Ended September 30, 2021 and 2020

			Three Months Ended September 30,												Variance						Percent Change
			2021						2020
			(In thousands)
Products revenues			$	91,764					$	52,350					$	39,414					75		%
Cost of products sold			87,551						47,723						39,828						83		%
Operating expenses			1,088						1,039						49						5		%
Selling, general and administrative expenses			954						1,117						(163)						(15)		%
Depreciation and amortization			592						617						(25)						(4)		%
Operating income			$	1,579					$	1,854					$	(275)					(15)		%
NGL sales volumes (Bbls)			1,435						1,723						(288)						(17)		%

    

    Products Revenues. Our average sales price per barrel increased $33.56, or 110%, increasing revenues by $57.8 million. The increase in average sales price per barrel was due to a rise in commodity prices. Sales volumes decreased 17%, lowering revenues by $18.4 million.

Cost of products sold.  Our average cost per barrel increased $33.31, or 120%, increasing cost of products sold by $57.4 million.  The increase in average cost per barrel was due to a rise in commodity prices.  The decrease in sales volume of 17% resulted in a $17.6 million reduction to cost of products sold. Our margins improved $0.25 per barrel, or 9%, during the period.

Operating expenses.  Operating expenses remained relatively consistent.

Selling, general and administrative expenses.  Selling, general and administrative expenses decreased primarily due to decreased compensation expense.

    Depreciation and amortization. Depreciation and amortization remained relatively consistent.

Comparative Results of Operations for the Nine Months Ended September 30, 2021 and 2020

			Nine Months Ended September 30,												Variance						Percent Change
			2021						2020
			(In thousands)
Products revenues			$	257,081					$	164,865					$	92,216					56		%
Cost of products sold			234,239						148,562						85,677						58		%
Operating expenses			3,144						3,128						16						1		%
Selling, general and administrative expenses			3,858						3,194						664						21		%
Depreciation and amortization			1,791						1,838						(47)						(3)		%
			14,049						8,143						5,906						73		%
Other operating loss, net			(689)						(2)						(687)						(34,350)		%
Operating income			$	13,360					$	8,141					$	5,219					64		%
NGL sales volumes (Bbls)			4,839						5,892						(1,053)						(18)		%

    Products Revenues. Our average sales price per barrel increased $25.15, or 90%, increasing revenues by $148.2 million. The increase in average sales price per barrel was due to a rise in commodity prices. Sales volumes decreased 18%, lowering revenues by $55.9 million.

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Cost of products sold.  Our average cost per barrel increased $23.19, or 92%, increasing cost of products sold by $136.7 million.  The increase in average cost per barrel was the result of an increase in market prices.  The decrease in sales volume of 18% resulted in a $51.0 million reduction to cost of products sold. Our margins improved $1.95 per barrel, or 71%, during the period.

    Operating expenses.  Operating expenses remained relatively consistent.

Selling, general and administrative expenses.  Selling, general and administrative increased primarily as a result of increased compensation expense.

Depreciation and amortization. Depreciation and amortization remained relatively consistent.

Other operating loss, net.  Other operating income, net represents gains and losses from the disposition of property, plant and equipment.

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Interest Expense, Net

    

Comparative Components of Interest Expense, Net for the Three Months Ended September 30, 2021 and 2020

			Three Months Ended September 30,												Variance						Percent Change
			2021						2020
			(In thousands)
Revolving credit facility			$	2,631					$	2,200					$	431					20		%
Senior notes			9,846						8,528						1,318						15		%
Amortization of deferred debt issuance costs			1,064						1,683						(619)						(37)		%
Amortization of debt discount			—						(38)						38						100		%
Other			564						526						38						7		%
Finance leases			5						61						(56)						(92)		%
Capitalized interest			—						(17)						17						100		%
Total interest expense, net			$	14,110					$	12,943					$	1,167					9		%

Comparative Components of Interest Expense, Net for the Nine Months Ended September 30, 2021 and 2020

			Nine Months Ended September 30,												Variance						Percent Change
			2021						2020
			(In thousands)
Revolving credit facility			$	6,948					$	6,364					$	584					9		%
Senior notes			29,349						21,738						7,611						35		%
Amortization of deferred debt issuance costs			2,585						2,674						(89)						(3)		%
Amortization of debt premium			—						(191)						191						100		%
Other			1,471						1,426						45						3		%
Finance leases			19						260						(241)						(93)		%
Capitalized interest			—						(26)						26						100		%
Total interest expense, net			$	40,372					$	32,245					$	8,127					25		%

Indirect Selling, General and Administrative Expenses

			Three Months Ended September 30,												Variance						Percent Change						Nine Months Ended September 30,												Variance						Percent Change
			2021						2020																		2021						2020
			(In thousands)																								(In thousands)
Indirect selling, general and administrative expenses			$	4,074					$	4,523					$	(449)					(10)		%				$	11,773					$	13,256					$	(1,483)					(11)		%

    Indirect selling, general and administrative expenses decreased for the three and nine months ended September 30, 2021 compared to the three and nine months ended September 30, 2020 primarily due to a decrease in the indirect expenses allocated from Martin Resource Management Corporation.

    Martin Resource Management Corporation allocates to us a portion of its indirect selling, general and administrative expenses for services such as accounting, legal, treasury, clerical, billing, information technology, administration of insurance, engineering, general office expense and employee benefit plans and other general corporate overhead functions we share with Martin Resource Management Corporation retained businesses. This allocation is based on the percentage of time spent by Martin Resource Management Corporation personnel that provide such centralized services. GAAP also permits other methods for allocation of these expenses, such as basing the allocation on the percentage of revenues contributed by a segment. The allocation of these expenses between Martin Resource Management Corporation and us is subject to a number of judgments and estimates, regardless of the method used. We can provide no assurances that our method of allocation, in the past or in the future, is or will

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be the most accurate or appropriate method of allocation for these expenses. Other methods could result in a higher allocation of selling, general and administrative expense to us, which would reduce our net income.

    Under the Omnibus Agreement, we are required to reimburse Martin Resource Management Corporation for indirect general and administrative and corporate overhead expenses. The Conflicts Committee of our general partner approved the following reimbursement amounts during the three and nine months ended September 30, 2021 and 2020:

			Three Months Ended September 30,												Variance						Percent Change						Nine Months Ended September 30,												Variance						Percent Change
			2021						2020																		2021						2020
			(In thousands)																								(In thousands)
Conflicts Committee approved reimbursement amount			$	3,597					$	4,103					$	(506)					(12)		%				$	10,790					$	12,364					$	(1,574)					(13)		%

    The amounts reflected above represent our allocable share of such expenses. The Conflicts Committee will review and approve future adjustments in the reimbursement amount for indirect expenses, if any, annually.

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Liquidity and Capital Resources

 

General

    Our primary sources of liquidity to meet operating expenses, service our indebtedness, fund capital expenditures and pay distributions to our unitholders have historically been cash flows generated by our operations, borrowings under our revolving credit facility and access to debt and equity capital markets, both public and private. Set forth below is a description of our cash flows for the periods indicated.

Cash Flows - Nine Months Ended September 30, 2021 Compared to Nine Months Ended September 30, 2020

    The following table details the cash flow changes between the nine months ended September 30, 2021 and 2020:

			Nine Months Ended September 30,												Variance						Percent Change
			2021						2020
			(In thousands)
Net cash provided by (used in):
Operating activities			$	(12,406)					$	19,150					$	(31,556)					(165)		%
Investing activities			(13,629)						(12,747)						(882)						(7)		%
Financing activities			27,860						(7,397)						35,257						477		%
Net increase (decrease) in cash and cash equivalents			$	1,825					$	(994)					$	2,819					284		%

    Net cash provided by operating activities. The decrease in net cash provided by operating activities for the nine months ended September 30, 2021 includes a reduction in operating results of $6.8 million and an unfavorable variance in working capital of $30.4 million, primarily related to the season build of butane inventory. Offsetting this decrease was a $4.7 million increase in other non-cash charges and a favorable variance in other non-current assets and liabilities of $0.9 million.

    

    Net cash used in investing activities. Net cash used in investing activities for the nine months ended September 30, 2021 increased $0.9 million. Net proceeds from the sale of property, plant and equipment decreased $4.2 million and proceeds received from the involuntary conversion of property, plant and equipment decreased $6.9 million. A reduction in cash used of $10.2 million resulted from higher payments for capital expenditures and plant turnaround costs in 2020.

    Net cash used in financing activities. Net cash used in financing activities for the nine months ended September 30, 2021 decreased primarily as a result of a $26.3 million reduction in net payments of long-term borrowings. Further, cash distributions paid decreased $4.5 million, costs associated with the credit facility decreased $3.0 million, and payments of finance lease obligations decreased $1.4 million.

Total Contractual Obligations

A summary of our total contractual cash obligations as of September 30, 2021, is as follows: 

			Payments due by period
Type of Obligation			Total Obligation						Less than One Year						1-3 Years						3-5 Years						Due Thereafter
Revolving credit facility			$	208,500					$	—					$	208,500					$	—					$	—
11.5% senior secured notes, due 2025			291,970						—						—						291,970						—
10.0% senior secured notes, due 2024			53,750						—						53,750						—						—
Throughput commitment			4,679						4,679						—						—						—
Operating leases			26,660						7,801						8,025						3,714						7,120
Finance lease obligations			348						240						108						—						—
Interest payable on finance lease obligations			13						12						1						—						—
Interest payable on fixed long-term debt obligations			127,710						38,952						74,768						13,990						—
Total contractual cash obligations			$	713,630					$	51,684					$	345,152					$	309,674					$	7,120

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The interest payable under our credit facility is not reflected in the above table because such amounts depend on the  outstanding balances and interest rates, which vary from time to time. 

Letters of Credit.  At September 30, 2021, we had outstanding irrevocable letters of credit in the amount of $28.2 million, which were issued under our revolving credit facility.

Off Balance Sheet Arrangements.  We do not have any off-balance sheet financing arrangements.

 

Description of Our Indebtedness

Revolving Credit Facility

At September 30, 2021, we maintained a $275.0 million revolving credit facility that matures on August 31, 2023. As of September 30, 2021, we had $208.5 million outstanding under the revolving credit facility and $28.2 million of outstanding irrevocable letters of credit, leaving a maximum available amount to be borrowed under our credit facility for future revolving credit borrowings and letters of credit of $38.3 million. After giving effect to our then current borrowings, letters of credit, and the financial covenants contained in our revolving credit facility, we had the ability to borrow approximately $26.0 million in additional amounts thereunder as of September 30, 2021.

The revolving credit facility is used for ongoing working capital needs and general partnership purposes, and to finance permitted investments, acquisitions and capital expenditures.  During the nine months ended September 30, 2021, the level of outstanding draws on our credit facility has ranged from a low of $148.0 million to a high of $228.0 million.

The credit facility is guaranteed by substantially all of our subsidiaries. Obligations under the credit facility are secured by first priority liens on substantially all of our assets and those of the guarantors, including, without limitation, inventory, accounts receivable, bank accounts, marine vessels, equipment, fixed assets and the interests in our subsidiaries.

    We may prepay all amounts outstanding under the credit facility at any time without premium or penalty (other than customary LIBOR breakage costs), subject to certain notice requirements. The credit facility requires mandatory prepayments of amounts outstanding thereunder with excess cash that exceeds $25.0 million and the net proceeds of certain asset sales, equity issuances and debt incurrences.

    Indebtedness under the credit facility bears interest at our option at the Eurodollar Rate (LIBOR), with a floor for LIBOR of 1%, plus an applicable margin, or the Base Rate (the highest of the Federal Funds Rate plus 0.50%, the 30-day Eurodollar Rate plus 1.0%, or the administrative agent’s prime rate) plus an applicable margin. We pay a per annum fee on all letters of credit issued under the credit facility, and we pay a commitment fee per annum on the unused revolving credit commitments under the credit facility. The letter of credit fee, the commitment fee and the applicable margins for our interest rate vary quarterly based on our Total Leverage Ratio (as defined in the credit facility, being generally computed as the ratio of total funded debt to consolidated earnings before interest, taxes, depreciation, amortization and certain other non-cash charges) and are as follows as of September 30, 2021:

Leverage Ratio			Base Rate Loans						Eurodollar Rate Loans						Letters of Credit
Less than 3.00 to 1.00			1.75		%				2.75		%				2.75		%
Greater than or equal to 3.00 to 1.00 and less than 3.50 to 1.00			2.00		%				3.00		%				3.00		%
Greater than or equal to 3.50 to 1.00 and less than 4.00 to 1.00			2.25		%				3.25		%				3.25		%
Greater than or equal to 4.00 to 1.00 and less than 4.50 to 1.00			2.50		%				3.50		%				3.50		%
Greater than or equal to 4.50 to 1.00 and less than 5.00 to 1.00			2.75		%				3.75		%				3.75		%
Greater than or equal to 5.00 to 1.00			3.00		%				4.00		%				4.00		%

    

    The applicable margin for LIBOR borrowings at September 30, 2021 is 4.00%, with a 1% floor for LIBOR.

    The credit facility includes financial covenants that are tested on a quarterly basis, based on the rolling four quarter period that ends on the last day of each fiscal quarter. On July 16, 2021, the credit facility was amended to, among other things:

•require the Operating Partnership to maintain a minimum Interest Coverage Ratio (as defined in the Credit Agreement) of 1.75:1.0 with respect to the fiscal quarter ended in September of 2021, 1.75:1.0 with respect to the fiscal quarter

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ending in December of 2021, 1.85:1.0 with respect to the fiscal quarters ending in March and June of 2022, and 2.0:1.0 with respect to each fiscal quarter thereafter;

•require the Operating Partnership to maintain a maximum Total Leverage Ratio (as defined in the Credit Agreement) of not more than 5.75:1.0 with respect to the fiscal quarter ended in September of 2021, 5.25:1.0 with respect to the fiscal quarter ending in December of 2021, and 5.0:1.0 with respect to each fiscal quarter thereafter; and

•require the Operating Partnership to maintain a maximum First Lien Leverage Ratio (as defined in the Credit Agreement) of not more than 2.25:1.0 with respect to each fiscal quarter ending in 2021, 1.75:1.0 with respect to each fiscal quarter ending in 2022, and 1.5:1.0 with respect to each fiscal quarter thereafter.

    In addition, the credit facility contains various covenants, which, among other things, limit our and our subsidiaries’ ability to: (i) grant or assume liens; (ii) make investments (including investments in our joint ventures) and acquisitions; (iii) enter into certain types of hedging agreements; (iv) incur or assume indebtedness; (v) sell, transfer, assign or convey assets; (vi) repurchase our equity, make distributions (including a limit on our ability to make quarterly distributions to unitholders in excess of $0.005 per unit unless our Total Leverage Ratio (as defined in the credit facility) is below 3.75:1:00) and certain other restricted payments; (vii) change the nature of our business; (viii) engage in transactions with affiliates; (ix) enter into certain burdensome agreements; (x) make certain amendments to the Omnibus Agreement and our material agreements; and (xi) permit our joint ventures to incur indebtedness or grant certain liens.

    The credit facility contains customary events of default, including, without limitation: (i) failure to pay any principal, interest, fees, expenses or other amounts when due; (ii) failure to meet the quarterly financial covenants; (iii) failure to observe any other agreement, obligation, or covenant in the credit facility or any related loan document, subject to cure periods for certain failures; (iv) the failure of any representation or warranty to be materially true and correct when made; (v) our, or any of our subsidiaries’ default under other indebtedness that exceeds a threshold amount; (vi) bankruptcy or other insolvency events involving us or any of our subsidiaries; (vii) judgments against us or any of our subsidiaries, in excess of a threshold amount; (viii) certain ERISA events involving us or any of our subsidiaries, in excess of a threshold amount; (ix) a change in control (as defined in the credit facility); and (x) the invalidity of any of the loan documents or the failure of any of the collateral documents to create a lien on the collateral.

    The credit facility also contains certain default provisions relating to Martin Resource Management Corporation. If Martin Resource Management Corporation no longer controls our general partner, the lenders under the credit facility may declare all amounts outstanding thereunder immediately due and payable. In addition, an event of default by Martin Resource Management Corporation under its credit facility could independently result in an event of default under our credit facility if it is deemed to have a material adverse effect on us.

    If an event of default relating to bankruptcy or other insolvency events occurs with respect to us or any of our subsidiaries, all indebtedness under our credit facility will immediately become due and payable. If any other event of default exists under our credit facility, the lenders may terminate their commitments to lend us money, accelerate the maturity of the indebtedness outstanding under the credit facility and exercise other rights and remedies. In addition, if any event of default exists under our credit facility, the lenders may commence foreclosure or other actions against the collateral.

Senior Secured Notes due 2025 and 2024

For a description of our 11.50% senior secured second lien notes due 2025 and 10.00% senior secured 1.5 lien notes due 2024, see "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Description of Our Long-Term Debt" in our Annual Report on Form 10-K for the year ended December 31, 2020.

    Capital Resources and Liquidity

    Historically, we have generally satisfied our working capital requirements and funded our debt service obligations and capital expenditures with cash generated from operations and borrowings under our revolving credit facility.

    On September 30, 2021, we had cash and cash equivalents of $6.8 million and available borrowing capacity of $38.3 million under our revolving credit facility with $208.5 million of borrowings outstanding.  After giving effect to our current borrowings, outstanding letters of credit and the financial covenants contained in our revolving credit facility, we had the ability to borrow approximately $26.0 million in additional amounts thereunder as of September 30, 2021. Our revolving credit facility matures on August 31, 2023.

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    We expect that our primary sources of liquidity to meet operating expenses, service our indebtedness, pay distributions to our unitholders and fund capital expenditures will be provided by cash flows generated by our operations, borrowings under our revolving credit facility and access to the debt and equity capital markets.  Our ability to generate cash from operations will depend upon our future operating performance, which is subject to certain risks.   For a discussion of such risks, please read "Item 1A. Risk Factors" of our Form 10-K for the year ended December 31, 2020, filed with the SEC on March 3, 2021.  In addition, due to the covenants in our revolving credit facility, our financial and operating performance impacts the amount we are permitted to borrow under that facility. 

    We are in compliance with all debt covenants as of September 30, 2021 and expect to be in compliance for the next twelve months.

    Interest Rate Risk

    

We are subject to interest rate risk on our credit facility due to the variable interest rate and may enter into interest rate swaps to reduce this variable rate risk.

Seasonality

    A substantial portion of our revenues is dependent on sales prices of products, particularly NGLs and fertilizers, which fluctuate in part based on winter and spring weather conditions. The demand for NGLs is strongest during the winter heating season and refinery blending season. The demand for fertilizers is strongest during the early spring planting season. However, our Terminalling and Storage and Transportation business segments and the molten sulfur business are typically not impacted by seasonal fluctuations and a significant portion of our net income is derived from our Terminalling and Storage, Sulfur Services and Transportation business segments. Further, extraordinary weather events, such as hurricanes, have in the past, and could in the future, impact our Terminalling and Storage, Sulfur Services, and Transportation business segments.

Impact of Inflation

    Inflation did not have a material impact on our results of operations for the nine months ended September 30, 2021 or 2020. Inflation may increase the cost to acquire or replace property, plant and equipment. It may also increase the costs of labor and supplies.  In the future, increasing energy prices could adversely affect our results of operations. Diesel fuel, natural gas, chemicals and other supplies are recorded in operating expenses.  An increase in price of these products would increase our operating expenses which could adversely affect net income. We cannot provide assurance that we will be able to pass along increased operating expenses to our customers.

Environmental Matters

    Our operations are subject to environmental laws and regulations adopted by various governmental authorities in the jurisdictions in which these operations are conducted. We incurred no material environmental costs, liabilities or expenditures to mitigate or eliminate environmental contamination during the nine months ended September 30, 2021 or 2020.

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Item 3.			Quantitative and Qualitative Disclosures about Market Risk

The Partnership is exposed to commodity risk and interest rate risk in its normal business activities. The following disclosures about market risk provide an update to, and should be read in conjunction with, “Item 7A. Quantitative and Qualitative Disclosures about Market Risk” set forth in our Annual Report on Form 10-K for the year ended December 31, 2020, filed with the SEC on March 3, 2021.

    

Commodity Risk. The Partnership from time to time uses 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.  We have established a hedging policy and monitor and manage the commodity market risk associated with potential commodity risk exposure.  In addition, we focus on utilizing counterparties for these transactions whose financial condition is appropriate for the credit risk involved in each specific transaction.

We have entered into hedging transactions as of September 30, 2021 to protect a portion of our commodity price risk exposure. These hedging arrangements are in the form of swaps and options for NGLs. We have instruments totaling a gross notional quantity of 400,000 barrels settling during the period from October 31, 2021 through December 31, 2021. These instruments settle against the applicable pricing source for each grade and location. These instruments are recorded on our Consolidated and Condensed Balance Sheets at September 30, 2021 in "Fair value of derivatives" as a current liability of $5.1 million. Based on the current net notional volume hedged as of September 30, 2021, a $0.10 change in the expected settlement price of these contracts would result in an impact to our net income of approximately $1.7 million.

Our hedging strategy is designed to protect us from excessive pricing volatility. However, since we do not typically hedge 100% of our exposure, abnormal price volatility in any of these commodity markets could influence operating income.

For derivatives designated in cash flow hedging relationships, we record the gains and losses from the use of these instruments in accumulated other comprehensive income (loss) on the consolidated balance sheets and subsequently recognize the accumulated gains and losses into cost of products sold in the same period when the associated underlying transactions occur. At September 30, 2021, accumulated other comprehensive income (loss) included $6.0 million in unrealized losses for these derivative instruments. All other commodity derivatives are marked-to-market and recognized into cost of products sold with the offset recognized as an asset or accrued liability. See Note 8 of the consolidated financial statements for further information on our outstanding derivatives.    

Interest Rate Risk. We are exposed to changes in interest rates as a result of our credit facility, which had a weighted-average interest rate of 5.00% as of September 30, 2021.  Based on the amount of unhedged floating rate debt owed by us on September 30, 2021, the impact of a 100 basis point increase in interest rates on this amount of debt would result in an increase in interest expense and a corresponding decrease in net income of approximately $2.1 million annually.

We are not exposed to changes in interest rates with respect to our 2024 Notes and 2025 Notes as these obligations are fixed rate.  Based on the quoted prices for identical liabilities in markets that are not active at September 30, 2021, the estimated fair value of the 2024 Notes and 2025 Notes was $55.1 million and $302.8 million, respectively. Market risk is estimated as the potential decrease in fair value of our long-term debt resulting from a hypothetical increase of a 100 basis point increase in interest rates. Such an increase in interest rates at September 30, 2021, would result in a $0.04 million decrease in the fair value of our 2024 Notes and a $8.4 million decrease in the fair value of our 2025 Notes.

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Item 4.			Controls and Procedures

Evaluation of disclosure controls and procedures. In accordance with Rules 13a-15 and 15d-15 of the Exchange Act, we, under the supervision and with the participation of the Chief Executive Officer and Chief Financial Officer of our general partner, carried out an evaluation of the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) and 15d-15(e) of the Exchange Act) as of the end of the period covered by this report. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer of our general partner concluded that our disclosure controls and procedures were effective, as of the end of the period covered by this report, to ensure that information required to be disclosed in our reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms.

    There were no changes in our internal controls over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) that occurred during our most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal controls over financial reporting.

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PART II - OTHER INFORMATION

Item 1.			Legal Proceedings

    From time to time, we are subject to certain legal proceedings, claims and disputes that arise in the ordinary course of our business. Although we cannot predict the outcomes of these legal proceedings, we do not believe these actions, in the aggregate, will have a material adverse impact on our financial position, results of operations or liquidity. Information regarding legal proceedings is set forth in Note 13 in Part I of this Form 10-Q.

Item 1A.			Risk Factors

    There have been no material changes to the Partnership's risk factors since our Annual Report on Form 10-K for the year ended December 31, 2020, filed with the SEC on March 3, 2021.

Item 6.			Exhibits

The information required by this Item 6 is set forth in the Index to Exhibits accompanying this quarterly report and is incorporated herein by reference.

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INDEX TO EXHIBITS

Exhibit Number						Exhibit Name
3.1						Certificate of Limited Partnership of Martin Midstream Partners L.P. (the "Partnership"), dated June 21, 2002 (filed as Exhibit 3.1 to the Partnership's Registration Statement on Form S-1 (Reg. No. 333-91706), filed July 1, 2002, and incorporated herein by reference).
3.2						Second Amended and Restated Agreement of Limited Partnership of the Partnership, dated November 25, 2009 (filed as Exhibit 10.1 to the Partnership's Amendment to Current Report on Form 8-K/A (SEC File No. 000-50056), filed January 19, 2010, and incorporated herein by reference).
3.3						Amendment No. 2 to the Second Amended and Restated Agreement of Limited Partnership of the Partnership dated January 31, 2011 (filed as Exhibit 3.1 to the Partnership's Current Report on Form 8-K (SEC File No. 000-50056), filed February 1, 2011, and incorporated herein by reference).
3.4						Amendment No. 3 to the Second Amended and Restated Agreement of Limited Partnership of the Partnership dated October 2, 2012 (filed as Exhibit 10.5 to the Partnership's Current Report on Form 8-K (SEC File No. 000-50056), filed October 9, 2012, and incorporated herein by reference).
3.5						Certificate of Limited Partnership of Martin Operating Partnership L.P. (the "Operating Partnership"), dated June 21, 2002 (filed as Exhibit 3.3 to the Partnership's Registration Statement on Form S-1 (Reg. No. 333-91706), filed July 1, 2002, and incorporated herein by reference).
3.6						Amended and Restated Agreement of Limited Partnership of the Operating Partnership, dated November 6, 2002 (filed as Exhibit 3.2 to the Partnership's Current Report on Form 8-K (SEC File No. 000-50056), filed November 19, 2002, and incorporated herein by reference).
3.7						Certificate of Formation of Martin Midstream GP LLC (the "General Partner"), dated June 21, 2002 (filed as Exhibit 3.5 to the Partnership's Registration Statement on Form S-1 (Reg. No. 333-91706), filed July 1, 2002, and incorporated herein by reference).
3.8						Amended and Restated Limited Liability Company Agreement of the General Partner, dated August 30, 2013 (filed as Exhibit 3.1 to the Partnership's Current Report on Form 8-K (Reg. No. 000-50056), filed September 3, 2013, and incorporated herein by reference).
3.9						Certificate of Formation of Martin Operating GP LLC (the "Operating General Partner"), dated June 21, 2002 (filed as Exhibit 3.7 to the Partnership's Registration Statement on Form S-1 (Reg. No. 333-91706), filed July 1, 2002, and incorporated herein by reference).
3.10						Limited Liability Company Agreement of the Operating General Partner, dated June 21, 2002 (filed as Exhibit 3.8 to the Partnership's Registration Statement on Form S-1 (Reg. No. 333-91706), filed July 1, 2002, and incorporated herein by reference).
3.11						Certificate of Formation of Arcadia Gas Storage, LLC, dated June 26, 2006 (filed as Exhibit 3.11 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.12						Company Agreement of Arcadia Gas Storage, LLC, dated December 27, 2006 (filed as Exhibit 3.12 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.13						Amendment to the Company Agreement of Arcadia Gas Storage, LLC, dated September 5, 2014 (filed as Exhibit 3.13 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.14						Certificate of Formation of Cadeville Gas Storage LLC, dated May 23, 2008 (filed as Exhibit 3.14 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.15						Limited Liability Company Agreement of Cadeville Gas Storage LLC, dated May 23, 2008 (filed as Exhibit 3.15 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.16						First Amendment to the Limited Liability Company Agreement of Cadeville Gas Storage LLC, dated April 16, 2012 (filed as Exhibit 3.16 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.17						Second Amendment to the Limited Liability Company Agreement of Cadeville Gas Storage LLC, dated September 5, 2014 (filed as Exhibit 3.17 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.18						Certificate of Formation of Monroe Gas Storage Company, LLC, dated June 14, 2006 (filed as Exhibit 3.18 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).

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3.19						Amended and Restated Limited Liability Company Agreement of Monroe Gas Storage Company, LLC, dated May 31, 2011 (filed as Exhibit 3.19 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.20						First Amendment to the Amended and Restated Limited Liability Company Agreement of Monroe Gas Storage Company, LLC, dated September 5, 2014 (filed as Exhibit 3.20 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.21						Certificate of Formation of Perryville Gas Storage LLC, dated May 23, 2008.(filed as Exhibit 3.21 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.22						Limited Liability Company Agreement of Perryville Gas Storage LLC, dated June 16, 2008 (filed as Exhibit 3.22 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.23						First Amendment to the Limited Liability Company Agreement of Perryville Gas Storage LLC, dated April 14, 2010 (filed as Exhibit 3.23 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.24						Second Amendment to the Limited Liability Company Agreement of Perryville Gas Storage LLC, dated September 5, 2014 (filed as Exhibit 3.24 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.25						Certificate of Formation of Cardinal Gas Storage Partners LLC, dated April 2, 2008 (filed as Exhibit 3.25 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.26						Third Amended and Restated Limited Liability Company Agreement of Cardinal Gas Storage Partners LLC (F/K/A Redbird Gas Storage LLC) dated October 27, 2014 (filed as Exhibit 3.26 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
3.27						Certificate of Formation of Redbird Gas Storage LLC, dated May 24, 2011 (filed as Exhibit 3.27 to the Partnership's Annual Report on Form 10-K (SEC File No. 000-50056), filed March 2, 2015, and incorporation herein by reference).
3.28						Second Amended and Restated LLC Agreement of Redbird Gas Storage LLC, dated as of October 2, 2012. (filed as Exhibit 10.6 to the Partnership's Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed November 5, 2012, and incorporated herein by reference).
3.29						Certificate of Merger of Cardinal Gas Storage Partners LLC with and into Redbird Gas Storage LLC, dated October 27, 2014 (filed as Exhibit 3.27 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed October 29, 2014, and incorporated herein by reference).
10.1						Martin Midstream Partners L.P. 2021 Phantom Unit Plan, effective as of July 21, 2021 (filed as Exhibit 10.1 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed July 26, 2021, and incorporated herein by reference).
10.2						Form of Phantom Unit Award Agreement for the Martin Midstream Partners L.P. 2021 Phantom Unit Plan (filed as Exhibit 10.2 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed July 26, 2021, and incorporated herein by reference).
10.3						Form of Phantom Unit Appreciation Right Award Agreement for the Martin Midstream Partners L.P. 2021 Phantom Unit Plan (filed as Exhibit 10.3 to the Partnership’s Quarterly Report on Form 10-Q (SEC File No. 000-50056), filed July 26, 2021, and incorporated herein by reference).
10.4						Twelfth Amendment to Third Amended and Restated Credit Agreement, dated as of July 16, 2021, by and among Martin Operating Partnership L.P., as borrower, Martin Midstream Partners L.P., the other Loan Parties party thereto, the Lenders party thereto, and Royal Bank of Canada, as administrative agent and collateral agent for the Lenders and as an L/C Issuer and a Lender (filed as Exhibit 10.1 to the Partnership’s Current Report on Form 8-K (SEC File No. 000-50056), filed July 22, 2021, and incorporated herein by reference).
31.1*						Certifications of Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*						Certifications of Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1*						Certification of Chief Executive Officer pursuant to 18 U.S.C., Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.  Pursuant to SEC Release 34-47551, this Exhibit is furnished to the SEC and shall not be deemed to be "filed."
32.2*						Certification of Chief Financial Officer pursuant to 18 U.S.C., Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.  Pursuant to SEC Release 34-47551, this Exhibit is furnished to the SEC and shall not be deemed to be "filed."

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101						Inline Interactive Data: the following financial information from Martin Midstream Partners L.P.’s Quarterly Report on Form 10-Q for the fiscal quarter ended September 30, 2021, formatted in Extensible Business Reporting Language: (1) the Consolidated and Condensed Balance Sheets; (2) the Consolidated and Condensed Statements of Income; (3) the Consolidated and Condensed Statements of Comprehensive Income (4) the Consolidated and Condensed Statements of Cash Flows; (5) the Consolidated and Condensed Statements of Capital; and (6) the Notes to Consolidated and Condensed Financial Statements.
104						Cover Page Interactive Data File - the cover page XBRL tags are embedded within the Inline XBRL document (contained in Exhibit 101).

* Filed or furnished herewith

** Schedules omitted pursuant to Item 601(a)(5) of Regulation S-K. A copy of any omitted schedule will be furnished supplementally to the Securities and Exchange Commission upon request.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this Report to be signed on its behalf by the undersigned thereunto duly authorized.

Martin Midstream Partners L.P.

By:

Martin Midstream GP LLC

Its General Partner

October 25, 2021

By:

/s/ Sharon L. Taylor

Sharon L. Taylor

Vice President and Chief Financial Officer

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