10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

FORM 10‑Q

(Mark One)
☒	Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
For the quarterly period ended June 30, 2018
OR
☐	Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Commission File Number: 001‑32505

TRANSMONTAIGNE PARTNERS L.P.

(Exact name of registrant as specified in its charter)

Delaware
(State or other jurisdiction of
incorporation or organization) 34‑2037221
(I.R.S. Employer
Identification No.)

1670 Broadway

Suite 3100

Denver, Colorado 80202

(Address, including zip code, of principal executive offices)

(303) 626‑8200

(Telephone number, including area code)

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 is a large accelerated filer, an accelerated filer, a non‑accelerated filer, smaller reporting company or an emerging growth company. See the definitions 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 ☐
		(Do not check if a 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. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b‑2 of the Exchange Act). Yes ☐    No ☒

As of July  31, 2018, there were  16,222,151 units of the registrant’s Common Limited Partner Units outstanding.

TABLE OF CONTENTS

		Page No.
Part I. Financial Information
Item 1.	Unaudited Consolidated Financial Statements	4
	Consolidated balance sheets as of June 30, 2018 and December 31, 2017	5
	Consolidated statements of operations for the three and six months ended June 30, 2018 and 2017	6
	Consolidated statements of partners’ equity for the year ended December 31, 2017 and six months ended June 30, 2018	7
	Consolidated statements of cash flows for the three and six months ended June 30, 2018 and 2017	8
	Notes to consolidated financial statements	9
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	33
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	46
Item 4.	Controls and Procedures	46
Part II. Other Information
Item 1.	Legal Proceedings	47
Item 1A.	Risk Factors	47
Item 6.	Exhibits	48

2

CAUTIONARY STATEMENT REGARDING FORWARD‑LOOKING STATEMENTS

This Quarterly Report on Form 10-Q contains “forward-looking statements” within the meaning of federal securities laws. Forward-looking statements give our current expectations, contain projections of results of operations or of financial condition, or forecasts of future events. When used in this Quarterly Report, the words “could,” “may,” “should,” “will,” “seek,” “believe,” “expect,” “anticipate,” “intend,” “continue,” “estimate,” “plan,” “target,” “predict,” “project,” “attempt,” “is scheduled,” “likely,” “forecast,” the negatives thereof and other similar expressions are used to identify forward-looking statements, although not all forward-looking statements contain such identifying words. These forward-looking statements are based on our current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events. You are cautioned not to place undue reliance on any forward-looking statements.

When considering forward-looking statements, you should keep in mind the risk factors and other cautionary statements described under the heading “Item 1A. Risk Factors” included in our Annual Report on Form 10-K for the year ended December 31, 2017 and the risk factors and the risk factors and other cautionary statements contained in our other filings with the United States Securities and Exchange Commission.  

You should also understand that it is not possible to predict or identify all such factors and should not consider the following list to be a complete statement of all potential risks and uncertainties. Factors that could cause our actual results to differ materially from the results contemplated by such forward-looking statements include:

· our ability to successfully implement our business strategy;

· competitive conditions in our industry;

· actions taken by third-party customers, producers, operators, processors and transporters;

· pending legal or environmental matters;

· costs of conducting our operations;

· our ability to complete internal growth projects on time and on budget;

· general economic conditions;

· the price of oil, natural gas, natural gas liquids and other commodities in the energy industry;

· the price and availability of debt and equity financing;

· large customer defaults; 

· interest rates;

· operating hazards, natural disasters, weather-related delays, casualty losses and other matters beyond our control;

· uncertainty regarding our future operating results;

· changes in tax status;

· effects of existing and future laws and governmental regulations;

· the effects of future litigation; and

· plans, objectives, expectations and intentions contained in the Annual Report that are not historical.

All forward-looking statements, expressed or implied, included in this Quarterly Report are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue.

Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements, all of which are expressly qualified by the statements in this section, to reflect events or circumstances after the date of this Quarterly Report.

3

Part I. Financial Information

ITEM 1.  UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

The interim unaudited consolidated financial statements of TransMontaigne Partners L.P. as of and for the three and six months ended June 30, 2018 are included herein beginning on the following page. The accompanying unaudited interim consolidated financial statements should be read in conjunction with our consolidated financial statements and related notes for the year ended December 31, 2017, together with our discussion and analysis of financial condition and results of operations, included in our Annual Report on Form 10‑K, filed on March 15, 2018 with the Securities and Exchange Commission (File No. 001‑32505).

TransMontaigne Partners L.P. is a holding company with the following 100% owned operating subsidiaries during the three months ended June 30, 2018:

· TransMontaigne Operating GP L.L.C.

· TransMontaigne Operating Company L.P.

· TransMontaigne Terminals L.L.C.

· Razorback L.L.C. (d/b/a Diamondback Pipeline L.L.C.)

· TPSI Terminals L.L.C.

· TLP Finance Corp.

· TLP Operating Finance Corp.

· TPME L.L.C.

We do not have off‑balance‑sheet arrangements (other than operating leases) or special‑purpose entities.

4

TransMontaigne Partners L.P. and subsidiaries

Consolidated balance sheets (unaudited)

(Dollars in thousands)

	June 30,		December 31,
	2018		2017
ASSETS
Current assets:
Cash and cash equivalents	$	390	$	923
Trade accounts receivable, net		12,164		11,017
Due from affiliates		3,491		1,509
Other current assets		7,978		20,654
Total current assets		24,023		34,103
Property, plant and equipment, net		656,761		655,053
Goodwill		9,428		9,428
Investments in unconsolidated affiliates		231,767		233,181
Other assets, net		52,843		55,238
	$	974,822	$	987,003
LIABILITIES AND EQUITY
Current liabilities:
Trade accounts payable	$	11,058	$	8,527
Accrued liabilities		26,676		17,426
Total current liabilities		37,734		25,953
Other liabilities		3,537		3,633
Long-term debt		578,523		593,200
Total liabilities		619,794		622,786
Commitments and contingencies (Note 16)
Partners’ equity:
Common unitholders (16,222,151 units issued and outstanding at June 30, 2018 and 16,177,353 units issued and outstanding at December 31, 2017)		301,372		310,769
General partner interest (2% interest with 331,055 equivalent units outstanding at June 30, 2018 and 330,150 equivalent units outstanding at December 31, 2017)		53,656		53,448
Total partners’ equity		355,028		364,217
	$	974,822	$	987,003

See accompanying notes to consolidated financial statements (unaudited).

5

TransMontaigne Partners L.P. and subsidiaries

Consolidated statements of operations (unaudited)

(In thousands, except per unit amounts)

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
Revenue:
External customers	$	51,379	$	43,850	$	103,493	$	86,930
Affiliates		3,965		1,514		8,295		3,284
Total revenue		55,344		45,364		111,788		90,214
Operating costs and expenses:
Direct operating costs and expenses		(19,275)		(15,984)		(39,420)		(32,495)
General and administrative expenses		(4,619)		(4,080)		(9,600)		(8,051)
Insurance expenses		(1,271)		(1,002)		(2,517)		(2,008)
Equity-based compensation expense		(441)		(352)		(2,458)		(2,169)
Depreciation and amortization		(13,160)		(8,792)		(24,968)		(17,497)
Total operating costs and expenses		(38,766)		(30,210)		(78,963)		(62,220)
Earnings from unconsolidated affiliates		2,444		2,120		5,333		4,680
Operating income		19,022		17,274		38,158		32,674
Other expenses:
Interest expense		(8,273)		(2,525)		(14,734)		(4,677)
Amortization of deferred issuance costs		(1,289)		(271)		(1,790)		(565)
Total other expenses		(9,562)		(2,796)		(16,524)		(5,242)
Net earnings		9,460		14,478		21,634		27,432
Less—earnings allocable to general partner interest including incentive distribution rights		(3,872)		(3,105)		(7,638)		(5,948)
Net earnings allocable to limited partners	$	5,588	$	11,373	$	13,996	$	21,484
Net earnings per limited partner unit—basic	$	0.34	$	0.70	$	0.86	$	1.32
Net earnings per limited partner unit—diluted	$	0.34	$	0.70	$	0.86	$	1.32

See accompanying notes to consolidated financial statements (unaudited).

6

TransMontaigne Partners L.P. and subsidiaries

Consolidated statements of partners’ equity (unaudited)

Year ended December 31, 2017 and six months ended June 30, 2018

(Dollars in thousands)

			General
	Common		partner
	units		interest		Total
Balance December 31, 2016	$	320,042	$	52,692	$	372,734
Distributions to unitholders		(47,349)		(11,985)		(59,334)
Equity-based compensation		2,729		—		2,729
Issuance of 6,498 common units pursuant to our long-term incentive plan		270		—		270
Issuance of 33,205 common units pursuant to our savings and retention program		—		—		—
Settlement of tax withholdings on equity-based compensation		(711)		—		(711)
Contribution of cash by TransMontaigne GP to maintain its 2% general partner interest		—		36		36
Net earnings for year ended December 31, 2017		35,788		12,705		48,493
Balance December 31, 2017		310,769		53,448		364,217
Distributions to unitholders		(25,193)		(7,464)		(32,657)
Equity-based compensation		2,458		—		2,458
Issuance of 44,798 common units pursuant to our savings and retention program		—		—		—
Settlement of tax withholdings on equity-based compensation		(658)		—		(658)
Contribution of cash by TransMontaigne GP to maintain its 2% general partner interest		—		34		34
Net earnings for the six months ended June 30, 2018		13,996		7,638		21,634
Balance June 30, 2018	$	301,372	$	53,656	$	355,028

See accompanying notes to consolidated financial statements (unaudited).

7

TransMontaigne Partners L.P. and subsidiaries

Consolidated statements of cash flows (unaudited)

(In thousands)

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
Cash flows from operating activities:
Net earnings	$	9,460	$	14,478	$	21,634	$	27,432
Adjustments to reconcile net earnings to net cash provided by operating activities:
Depreciation and amortization		13,160		8,792		24,968		17,497
Earnings from unconsolidated affiliates		(2,444)		(2,120)		(5,333)		(4,680)
Distributions from unconsolidated affiliates		3,971		4,546		7,161		8,895
Equity-based compensation		441		352		2,458		2,169
Amortization of deferred issuance costs		1,289		271		1,790		565
Amortization of deferred revenue		(149)		10		(336)		(41)
Unrealized (gain) loss on derivative instruments		85		38		127		(220)
Changes in operating assets and liabilities, net of effects from acquisitions and dispositions:
Trade accounts receivable, net		(1,092)		(79)		(1,090)		141
Due from affiliates		312		(446)		(1,982)		(756)
Other current assets		3,620		1,043		1,821		2,759
Amounts due under long-term terminaling services agreements, net		176		(227)		204		(325)
Deposits		—		—		—		54
Trade accounts payable		(2,383)		(433)		(809)		431
Accrued liabilities		9,023		(200)		9,250		2,467
Net cash provided by operating activities		35,469		26,025		59,863		56,388
Cash flows from investing activities:
Investments in unconsolidated affiliates		(114)		(145)		(1,264)		(2,145)
Return of investment in unconsolidated affiliates		850		—		850		—
Capital expenditures		(15,452)		(19,145)		(21,955)		(28,645)
Proceeds from sale of assets		—		—		10,025		—
Net cash used in investing activities		(14,716)		(19,290)		(12,344)		(30,790)
Cash flows from financing activities:
Proceeds from senior notes		—		—		300,000		—
Borrowings under revolving credit facility		38,900		41,100		85,500		87,100
Repayments under revolving credit facility		(42,800)		(31,600)		(392,400)		(76,900)
Deferred issuance costs		(505)		(296)		(7,871)		(5,364)
Settlement of tax withholdings on equity-based compensation		(317)		(25)		(658)		(407)
Distributions paid to unitholders		(16,594)		(14,590)		(32,657)		(28,677)
Contribution of cash by TransMontaigne GP		16		—		34		22
Net cash used in financing activities		(21,300)		(5,411)		(48,052)		(24,226)
Increase (decrease) in cash and cash equivalents		(547)		1,324		(533)		1,372
Cash and cash equivalents at beginning of period		937		641		923		593
Cash and cash equivalents at end of period	$	390	$	1,965	$	390	$	1,965
Supplemental disclosures of cash flow information:
Cash paid for interest	$	3,265	$	2,374	$	7,631	$	4,591
Property, plant and equipment acquired with accounts payable	$	6,546	$	2,992	$	6,546	$	2,992

See accompanying notes to consolidated financial statements (unaudited).

8

TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited)

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

(a) Nature of business

TransMontaigne Partners L.P. (“we,” “us,” “our,” “the Partnership”) was formed in February 2005 as a Delaware limited partnership. We provide integrated terminaling, storage, transportation and related services for companies engaged in the trading, distribution and marketing of light refined petroleum products, heavy refined petroleum products, crude oil, chemicals, fertilizers and other liquid products. We conduct our operations in the United States along the Gulf Coast, in the Midwest, in Houston and Brownsville, Texas, along the Mississippi and Ohio rivers, in the Southeast and along the West Coast.

We are controlled by our general partner, TransMontaigne GP L.L.C. (“TransMontaigne GP”), which as of February 1, 2016 is a wholly‑owned indirect subsidiary of ArcLight Energy Partners Fund VI, L.P. (“ArcLight”).

(b) Basis of presentation and use of estimates

Our accounting and financial reporting policies conform to accounting principles generally accepted in the United States of America (“GAAP”). The accompanying consolidated financial statements include the accounts of TransMontaigne Partners L.P. and its controlled subsidiaries. Investments where we do not have the ability to exercise control, but do have the ability to exercise significant influence, are accounted for using the equity method of accounting. All inter‑company accounts and transactions have been eliminated in the preparation of the accompanying consolidated financial statements. The accompanying consolidated financial statements include all adjustments (consisting of normal and recurring accruals) considered necessary to present fairly our financial position as of June 30, 2018 and December 31, 2017 and our results of operations for the three and six months ended June 30, 2018 and 2017.Certain reclassifications of previously reported amounts have been made to conform to the current year presentation.

The preparation of financial statements in conformity with “GAAP” requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenue and expenses during the reporting periods. The following estimates, in management’s opinion, are subjective in nature, require the exercise of judgment, and/or involve complex analyses: business combination estimates and assumptions, useful lives of our plant and equipment and accrued environmental obligations. Changes in these estimates and assumptions will occur as a result of the passage of time and the occurrence of future events. Actual results could differ from these estimates.

(c) Accounting for terminal and pipeline operations

Effective January 1, 2018, we adopted Accounting Standards Codification (“ASC”) Topic 606, Revenue from Contracts with Customers (“ASC 606”), applying the modified retrospective transition method, which required us to apply the new standard to (i) all new revenue contracts entered into after January 1, 2018, and (ii) revenue contracts which were not completed as of January 1, 2018. ASC 606 replaces existing revenue recognition requirements in GAAP and requires entities to recognize revenue at an amount that reflects the consideration to which we expect to be entitled in exchange for transferring goods or services to a customer. ASC 606 also requires certain disclosures regarding qualitative and quantitative information regarding the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The adoption of ASC 606 did not result in a transition adjustment nor did it have an impact on the timing or amount of our revenue recognition (See Note 18 of Notes to consolidated financial statements).

9

TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

The adoption of ASC 606 did not result in changes to our accounting for trade accounts receivable (see Note 4 of Notes to consolidated financial statements), contract assets or contract liabilities. We recognize contract assets in situations where revenue recognition under ASC 606 occurs prior to billing the customer based on our rights under the contract.  Contract assets are transferred to accounts receivable when the rights become unconditional. At June 30, 2018, we did not have any contract assets related to ASC 606.

Contract liabilities primarily relate to consideration received from customers in advance of completing the performance obligation. A performance obligation is a promise in a contract to transfer goods or services to the customer. We recognize contract liabilities under these arrangements as revenue once all contingencies or potential performance obligations have been satisfied by the (i) performance of services or (ii) expiration of the customer’s rights under the contract. Short-term contract liabilities include customer advances and deposits (see Note 10 of Notes to consolidated financial statements). Long-term contract liabilities include deferred revenue related to ethanol blending fees and other projects (See Note 11 of Notes to consolidated financial statements).

We generate revenue from terminaling services fees, pipeline transportation fees and management fees. Under ASC 606, we recognize revenue over time or at a point in time, depending on the nature of the performance obligations contained in the respective contract with our customer. The contract transaction price is allocated to each performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. The majority of our revenue is recognized pursuant to ASC guidance other than ASC 606. The following is an overview of our significant revenue streams, including a description of the respective performance obligations and related method of revenue recognition. 

Terminaling services fees. Our terminaling services agreements are structured as either throughput agreements or storage agreements. Our throughput agreements contain provisions that require our customers to make minimum payments, which are based on contractually established minimum volumes of throughput of the customer’s product at our facilities, over a stipulated period of time. Due to this minimum payment arrangement, we recognize a fixed amount of revenue from the customer over a certain period of time, even if the customer throughputs less than the minimum volume of product during that period. In addition, if a customer throughputs a volume of product exceeding the minimum volume, we would recognize additional revenue on this incremental volume. Our storage agreements require our customers to make minimum payments based on the volume of storage capacity available to the customer under the agreement, which results in a fixed amount of recognized revenue. We refer to the fixed amount of revenue recognized pursuant to our terminaling services agreements as being “firm commitments.” The majority of our firm commitments under our terminaling services agreements are accounted for in accordance with ASC 840, Leases (“ASC 840 revenue”). The remainder is recognized in accordance with ASC 606 (“ASC 606 revenue”) where the minimum payment arrangement in each contract is a single performance obligation that is primarily satisfied over time through the contract term. 

Revenue recognized in excess of firm commitments and revenue recognized based solely on the volume of product distributed or injected are referred to as ancillary. The ancillary revenue associated with terminaling services include volumes of product throughput that exceed the contractually established minimum volumes,  injection fees based on the volume of product injected with additive compounds, heating and mixing of stored products, product transfer, railcar handling, butane blending, proceeds from the sale of product gains, wharfage and vapor recovery. The revenue generated by these services is primarily considered optional purchases to acquire additional services or variable consideration that is required to be estimated under ASC 606 for any uncertainty that is not resolved in the period of the service. We account for the majority of ancillary revenue at individual points in time when the services are delivered to the customer. Our ancillary revenue is recognized in accordance with ASC 606.

Pipeline transportation fees. We earn pipeline transportation fees at our Diamondback pipeline either based on the volume of product transported or under capacity reservation agreements. Revenue associated with the capacity reservation is recognized ratably over the respective term, regardless of whether the capacity is actually utilized. We earn pipeline transportation fees at our Razorback pipeline based on an allocation of the aggregate fees charged under the capacity agreement with our customer who has contracted for 100% of our Razorback system. For the six months ended June 30, 2018, pipeline transportation revenue is primarily accounted for in accordance with ASC 840.

10

TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

Management fees. We manage and operate certain tank capacity at our Port Everglades South terminal for a major oil company and receive a reimbursement of its proportionate share of operating and maintenance costs. We manage and operate the Frontera joint venture and receive a management fee based on our costs incurred. We also currently manage and operate for an affiliate of PEMEX, Mexico’s state-owned petroleum company, a bi-directional products pipeline connected to our Brownsville terminal facility and receive a management fee. We manage and operate rail sites at certain Southeast terminals on behalf of a major oil company and receive reimbursement for operating and maintenance costs. Management fee revenue is recognized at individual points in time as the services are performed or as the costs are incurred and is primarily accounted for in accordance with ASC 606.

(d) Cash and cash equivalents

We consider all short‑term investments with a remaining maturity of three months or less at the date of purchase to be cash equivalents.

(e) Property, plant and equipment

Depreciation is computed using the straight‑line method. Estimated useful lives are 15 to 25 years for terminals and pipelines and 3 to 25 years for furniture, fixtures and equipment. All items of property, plant and equipment are carried at cost. Expenditures that increase capacity or extend useful lives are capitalized. Repairs and maintenance are expensed as incurred.

We evaluate long‑lived assets for impairment whenever events or changes in circumstances indicate that the carrying value of an asset group may not be recoverable based on expected undiscounted future cash flows attributable to that asset group. If an asset group is impaired, the impairment loss to be recognized is the excess of the carrying amount of the asset group over its estimated fair value.

(f) Investments in unconsolidated affiliates

We account for our investments in unconsolidated affiliates, which we do not control but do have the ability to exercise significant influence over, using the equity method of accounting. Under this method, the investment is recorded at acquisition cost, increased by our proportionate share of any earnings and additional capital contributions and decreased by our proportionate share of any losses, distributions received and amortization of any excess investment. Excess investment is the amount by which our total investment exceeds our proportionate share of the book value of the net assets of the investment entity. We evaluate our investments in unconsolidated affiliates for impairment whenever events or circumstances indicate there is a loss in value of the investment that is other than temporary. In the event of impairment, we would record a charge to earnings to adjust the carrying amount to estimated fair value.

(g) Environmental obligations

We accrue for environmental costs that relate to existing conditions caused by past operations when probable and reasonably estimable (see Note 10 of Notes to consolidated financial statements). Environmental costs include initial site surveys and environmental studies of potentially contaminated sites, costs for remediation and restoration of sites determined to be contaminated and ongoing monitoring costs, as well as fines, damages and other costs, including direct legal costs. Liabilities for environmental costs at a specific site are initially recorded, on an undiscounted basis, when it is probable that we will be liable for such costs, and a reasonable estimate of the associated costs can be made based on available information. Such an estimate includes our share of the liability for each specific site and the sharing of the amounts related to each site that will not be paid by other potentially responsible parties, based on enacted laws and adopted regulations and policies. Adjustments to initial estimates are recorded, from time to time, to reflect changing circumstances and estimates based upon additional information developed in subsequent periods. Estimates of our ultimate liabilities associated with environmental costs are difficult to make with certainty due to the number of variables involved, including the early stage of investigation at certain sites, the lengthy time frames required to complete remediation, technology changes, alternatives available and the evolving nature of environmental laws and regulations.

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

We periodically file claims for insurance recoveries of certain environmental remediation costs with our insurance carriers under our comprehensive liability policies (see Note 5 of Notes to consolidated financial statements).

We recognize our insurance recoveries as a credit to income in the period that we assess the likelihood of recovery as being probable.

In connection with our previous acquisitions of certain terminals from TransMontaigne LLC, a wholly owned subsidiary of NGL Energy Partners LP and the previous owner of our general partner, TransMontaigne LLC agreed to indemnify us against certain potential environmental claims, losses and expenses at those terminals. Pursuant to the acquisition agreements for each of the Florida (except Pensacola) and Midwest terminals, the Southeast terminals, the Brownsville and the River terminals, and the Pensacola, Florida Terminal, TransMontaigne LLC is obligated to indemnify us against environmental claims, losses and expenses that were associated with the ownership or operation of the terminals prior to the purchase by the Partnership. In each acquisition agreement, TransMontaigne LLC’s maximum indemnification liability is subject to a specified time period for indemnification, cap on indemnification and satisfaction of a deductible amount before indemnification, in each case subject to certain exceptions, limitations and conditions specified therein. TransMontaigne LLC has no indemnification obligations with respect to environmental claims made as a result of additions to or modifications of environmental laws promulgated after certain specified dates.

The environmental indemnification obligations of TransMontaigne LLC to us remain in place and were not affected by ArcLight’s acquisition of our general partner on February 1, 2016.  

(h) Asset retirement obligations

Asset retirement obligations are legal obligations associated with the retirement of long‑lived assets that result from the acquisition, construction, development or normal use of the asset. Generally accepted accounting principles require that the fair value of a liability related to the retirement of long‑lived assets be recorded at the time a legal obligation is incurred. Once an asset retirement obligation is identified and a liability is recorded, a corresponding asset is recorded, which is depreciated over the remaining useful life of the asset. After the initial measurement, the liability is adjusted to reflect changes in the asset retirement obligation. If and when it is determined that a legal obligation has been incurred, the fair value of any liability is determined based on estimates and assumptions related to retirement costs, future inflation rates and interest rates. Our long‑lived assets consist of above‑ground storage facilities and underground pipelines. We are unable to predict if and when these long‑lived assets will become completely obsolete and require dismantlement. We have not recorded an asset retirement obligation, or corresponding asset, because the future dismantlement and removal dates of our long‑lived assets is indeterminable and the amount of any associated costs are believed to be insignificant. Changes in our assumptions and estimates may occur as a result of the passage of time and the occurrence of future events.

(i) Equity-based compensation

Generally accepted accounting principles require us to measure the cost of services received in exchange for an award of equity instruments based on the measurement‑date fair value of the award. That cost is recognized during the period services are provided in exchange for the award (see Note 14 of Notes to consolidated financial statements).

(j) Accounting for derivative instruments

Generally accepted accounting principles require us to recognize all derivative instruments at fair value in the consolidated balance sheets as assets or liabilities (see Notes 5 and 9 of Notes to consolidated financial statements). Changes in the fair value of our derivative instruments are recognized in earnings.

At June 30, 2018 and December 31, 2017, our derivative instruments were limited to interest rate swap agreements with an aggregate notional amount of $50.0 million and $125.0 million, respectively. At June 30, 2018 the remaining derivative instrument expires March 11, 2019. Pursuant to the terms of the interest rate swap agreements, we paid a blended fixed rate of approximately 0.97% and 1.01% for the six months ended June 30, 2018 and the year ended

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

December 31, 2017, respectively, and received interest payments based on the one-month LIBOR. The net difference to be paid or received under the interest rate swap agreements is settled monthly and is recognized as an adjustment to interest expense. The fair value of our interest rate swap agreements are determined using a pricing model based on the LIBOR swap rate and other observable market data.

(k) Income taxes

No provision for U.S. federal income taxes has been reflected in the accompanying consolidated financial statements because we are treated as a partnership for federal income tax purposes. As a partnership, all income, gains, losses, expenses, deductions and tax credits generated by us flow through to our unitholders.

(l) Net earnings per limited partner unit

Net earnings allocable to the limited partners, for purposes of calculating net earnings per limited partner unit, are calculated under the two-class method and accordingly are net of the earnings allocable to the general partner interest and distributions payable to any restricted phantom units granted under our equity-based compensation plans that participate in our distributions. The earnings allocable to the general partner interest include the distributions of available cash (as defined by our partnership agreement) attributable to the period to the general partner interest, net of adjustments for the general partner’s share of undistributed earnings, and the incentive distribution rights. Undistributed earnings are the difference between the earnings and the distributions attributable to the period. Undistributed earnings are allocated to the limited partners and general partner interest based on their respective sharing of earnings or losses specified in the partnership agreement, which is based on their ownership percentages of 98% and 2%, respectively. The incentive distribution rights are not allocated a portion of the undistributed earnings given they are not entitled to distributions other than from available cash. Further, the incentive distribution rights do not share in losses under our partnership agreement. Basic net earnings per limited partner unit is computed by dividing net earnings allocable to the limited partners by the weighted average number of limited partner units outstanding during the period. Diluted net earnings per limited partner unit is computed by dividing net earnings allocable to the limited partners by the weighted average number of limited partner units outstanding during the period and any potential dilutive securities outstanding during the period.

(m)   Comprehensive income

Entities that report items of other comprehensive income have the option to present the components of net earnings and comprehensive income in either one continuous financial statement, or two consecutive financial statements. As the Partnership has no components of comprehensive income other than net earnings, no statement of comprehensive income has been presented.

 (n) Recent accounting pronouncements

Effective January 1, 2018 we adopted ASU 2016-15, Statement of Cash Flows: Classification of Certain Cash Receipt and Cash Payments. This ASU requires changes in the presentation of certain items, including but not limited to debt prepayment or debt extinguishment costs; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance policies and distributions received from equity method investees. The adoption of this ASU did not have a material impact on our unaudited consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02, Leases. The objective of this update is to improve financial reporting about leasing transactions. ASU 2016-02 is effective for annual reporting periods beginning after December 15, 2018, including interim periods within that reporting period. We are currently evaluating the potential impact that the adoption will have on our disclosures and financial statements. Additionally, we are in the process of evaluating and designing the necessary changes to our business processes and controls to support recognition and disclosure under the new standard. As part of our evaluation process we have established an implementation team and are in the process of

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Notes to consolidated financial statements (unaudited) (continued)

implementing a third-party supported lease accounting system to facilitate the accounting and financial reporting requirements.

In January 2017, the FASB issued ASU 2017-04, Intangibles-Goodwill and Other: Simplifying the Test for Goodwill Impairment, to simplify the accounting for goodwill impairment by eliminating step 2 from the goodwill impairment test. ASU 2017-04 is effective for annual reporting periods beginning after December 15, 2019, including interim periods within that reporting period. We are currently evaluating the potential impact that the adoption will have on our disclosures and financial statements.

 (2) TRANSACTIONS WITH AFFILIATES

Third Amended and Restated Omnibus Agreement.Since the inception of the Partnership in 2005 we have been party to an omnibus agreement with the owner of our general partner, which agreement has been amended and restated from time to time.  The omnibus agreement provides for the provision of various services for our benefit. The fees payable under the omnibus agreement to the owner of our general partner are comprised of (i) the reimbursement of the direct operating costs and expenses, such as salaries and benefits of operational personnel performing services on site at our terminals and pipelines, which we refer to as on-site employees, (ii) bonus awards to key personnel who perform services for the Partnership, which are typically paid in the Partnership’s units and are subject to the approval by the compensation committee and the conflicts committee of our general partner, and (iii) the administrative fee for the provision of various general and administrative services for the Partnership’s benefit such as legal, accounting, treasury, insurance administration and claims processing, information technology, human resources, credit, payroll, taxes, engineering, environmental safety and occupational health (ESOH) and other corporate services, to the extent such services are not outsourced by the Partnership. The administrative fee is recognized as a component of general and administrative expenses andfor the three months ended June 30, 2018 and 2017, the administrative fee paid was approximately $2.7 million and $3.2 million, respectively. For both the six months ended June 30, 2018 and 2017, the administrative fee paid by the Partnership was approximately $6.1 million.

In accordance with the Second Amended and Restated Omnibus Agreement and the prior versions thereto, if we acquired or constructed additional facilities, the owner of our general partner may propose a revised administrative fee covering the provision of services for such additional facilities, subject to the approval by the conflicts committee of our general partner. In connection with our previously discussed Phase II buildout at our Collins terminal, the expansion of our Brownsville terminal and pipeline operations and the December 2017 acquisition of the West Coast terminals, on May 7, 2018, the Partnership, with the concurrence of the conflicts committee of our general partner, agreed to an annual increase in the aggregate fees payable to the owner of the general partner under the omnibus agreement of $3.6 million beginning May 13, 2018. 

To effectuate this $3.6 million annual increase in the aggregate fees payable to the owner of the general partner, on May 7, 2018 the Partnership, with the concurrence of the conflicts committee of our general partner, entered into the Third Amended and Restated Omnibus Agreement by and among the Partnership, our general partner, TransMontaigne Operating GP L.L.C., TransMontaigne Operating Company L.P., Gulf TLP Holdings, LLC, and TLP Management Services LLC. The effect of the change to the omnibus agreement is to allow the Partnership to assume the costs and expenses of personnel performing engineering and ESOH services for and on behalf of the Partnership and to receive an equal and offsetting decrease in the administrative fee. These costs and expenses are expected to approximate $8.9 million in 2018. We expect that a significant portion of the assumed engineering costs will be capitalized under generally accepted accounting principles. 

Prior to the $3.6 million annual increase and the effective date of the Third Amended and Restated Omnibus Agreement, the annual administrative fee was approximately $13.7 million and included the costs and expenses of the personnel performing engineering and ESOH services. Subsequent to the $3.6 million annual increase and the effective date of the Third Amended and Restated Omnibus Agreement, the annual administrative fee will be approximately $8.4 million and the Partnership will bear the approximately $8.9 million costs and expenses of the personnel performing engineering and ESOH services for and on behalf of the Partnership.

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

The administrative fee under the Third Amended and Restated Omnibus Agreement is subject to an increase each calendar year tied to an increase in the consumer price index, if any, plus two percent. If we acquire or construct additional facilities, the owner of our general partner may propose a revised administrative fee covering the provision of services for such additional facilities, subject to approval by the conflicts committee of our general partner.

We do not directly employ any of the persons responsible for managing our business.  We are managed by our general partner, and all of the officers of our general partner and employees who provide services to the Partnership are employed by TLP Management Services, a wholly owned subsidiary of ArcLight.  TLP Management Services provides payroll and maintains all employee benefits programs on behalf of our general partner and the Partnership pursuant to the omnibus agreement.  The omnibus agreement will continue in effect until the earlier of (i) ArcLight ceasing to control our general partner or (ii) the election of either us or the owner, following at least 24 months’ prior written notice to the other parties.

Operations and reimbursement agreement—Frontera.  We have a 50% ownership interest in the Frontera Brownsville LLC joint venture, or (Frontera). We operate Frontera, in accordance with an operations and reimbursement agreement executed between us and Frontera, for a management fee that is based on our costs incurred. Our agreement with Frontera stipulates that we may resign as the operator at any time with the prior written consent of Frontera, or that we may be removed as the operator for good cause, which includes material noncompliance with laws and material failure to adhere to good industry practice regarding health, safety or environmental matters. We recognized revenue related to this operations and reimbursement agreement of approximately $1.3 million and $1.1 million for the three months ended June 30, 2018 and 2017, respectively and approximately $2.8 million and $2.5 million for the six months ended June 30, 2018 and 2017, respectively.  

Terminaling services agreements—Brownsville terminals. We have terminaling services agreements with Frontera relating to our Brownsville, Texas facility that will expire in June 2019 and June 2020, subject to automatic renewals unless terminated by either party upon 90 days’ and 180 days’ prior notice, respectively. In exchange for its minimum throughput commitments, we have agreed to provide Frontera with approximately 301,000 barrels of storage capacity. We recognized revenue related to these agreements of approximately $0.6 million and $0.4 million for the three months ended June 30, 2018 and 2017, respectively and approximately $1.2 million and $0.8 million for the six months ended June 30, 2018 and 2017, respectively.

Terminaling services agreement—Gulf Coast terminals. Associated Asphalt Marketing, LLC is a wholly-owned indirect subsidiary of ArcLight. Effective January 1, 2018, a third party customer assigned their terminaling services agreement relating to our Gulf Coast terminals to Associated Asphalt Marketing, LLC. The agreement will expire in April 2021, subject to two, two-year automatic renewals unless terminated by either party upon 180 days’ prior notice. In exchange for its minimum throughput commitment, we have agreed to provide Associated Asphalt Marketing, LLC with approximately 750,000 barrels of storage capacity. We recognized revenue related to this agreement of approximately $2.1 million and $nil for the three months ended June 30, 2018 and 2017, respectively and approximately $4.3 million and $nil for the six months ended June 30, 2018 and 2017, respectively.

(3) BUSINESS COMBINATION, TERMINAL ACQUISITION AND DISPOSITION

On December 15, 2017, we acquired the West Coast terminals from a third party for a total purchase price of $276.8 million. The West Coast terminals consist of two waterborne refined product and crude oil terminals located in the San Francisco Bay Area refining complex including a total of 64 storage tanks with approximately 5.0 million barrels of active storage capacity. The West Coast terminals have access to domestic and international crude oil and refined products markets through marine, pipeline, truck and rail logistics capabilities. The accompanying consolidated financial statements include the assets, liabilities and results of operations of the West Coast terminals from December 15, 2017.

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

The purchase price and final assessment of the fair value of the assets acquired and liabilities assumed in the business combination were as follows (in thousands):

Other current assets	$	1,037
Property, plant and equipment		228,000
Goodwill		943
Customer relationships		47,000
Total assets acquired		276,980
Environmental obligation		220
Total liabilities assumed		220
Allocated purchase price	$	276,760

Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill represents the premium we paid to acquire the skilled workforce.

On February 20, 2018 we closed on the purchase of certain assets from a third party. Concurrently we sold these assets to another third party for cash proceeds equal to our purchase price plus expenses.

(4) CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE

Our primary market areas are located in the United States along the Gulf Coast, in the Southeast, in Brownsville, Texas, along the Mississippi and Ohio Rivers, in the Midwest and along the West Coast. We have a concentration of trade receivable balances due from companies engaged in the trading, distribution and marketing of refined products and crude oil. These concentrations of customers may affect our overall credit risk in that the customers may be similarly affected by changes in economic, regulatory or other factors. Our customers’ historical financial and operating information is analyzed prior to extending credit. We manage our exposure to credit risk through credit analysis, credit approvals, credit limits and monitoring procedures, and for certain transactions we may request letters of credit, prepayments or guarantees. Amounts included in trade accounts receivable that are accounted for as ASC 606 revenue in accordance with ASC 606 approximate $3.5 million at June 30, 2018. We maintain allowances for potentially uncollectible accounts receivable.

Trade accounts receivable, net consists of the following (in thousands):

	June 30,		December 31,
	2018		2017
Trade accounts receivable	$	12,458	$	11,128
Less allowance for doubtful accounts		(294)		(111)
	$	12,164	$	11,017

The following customers accounted for at least 10% of our consolidated revenue in at least one of the periods presented in the accompanying consolidated statements of operations:

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
NGL Energy Partners LP	23	%	27	%	23	%	26	%
RaceTrac Petroleum Inc.	12	%	13	%	12	%	12	%
Castleton Commodities International LLC	9	%	13	%	10	%	13	%

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

(5) OTHER CURRENT ASSETS

Other current assets are as follows (in thousands):

	June 30,		December 31,
	2018		2017
Prepaid insurance	$	2,761	$	4,151
Amounts due from insurance companies		1,755		1,981
Additive detergent		1,216		1,715
Unrealized gain on derivative instrument		449		—
Deposits and other assets		1,797		12,807
	$	7,978	$	20,654

Amounts due from insurance companies.  We periodically file claims for recovery of environmental remediation costs with our insurance carriers under our comprehensive liability policies. We recognize our insurance recoveries in the period that we assess the likelihood of recovery as being probable (i.e., likely to occur). At June 30, 2018 and December 31, 2017, we have recognized amounts due from insurance companies of approximately $1.8 million and $2.0 million, respectively, representing our best estimate of our probable insurance recoveries. During the six months ended June 30, 2018, we received reimbursements from insurance companies of approximately $0.2 million.

Deposits and other assets. At December 31, 2017,  deposits and other assets includes a deposit of approximately $10.2 million paid during the fourth quarter 2017 related to expansion opportunities that closed in the first quarter of 2018 (See Note 3 of Notes to consolidated financial statements).

(6) PROPERTY, PLANT AND EQUIPMENT, NET

Property, plant and equipment, net is as follows (in thousands):

	June 30,		December 31,
	2018		2017
Land	$	83,451	$	83,310
Terminals, pipelines and equipment		912,245		885,429
Furniture, fixtures and equipment		4,860		4,430
Construction in progress		19,481		21,575
		1,020,037		994,744
Less accumulated depreciation		(363,276)		(339,691)
	$	656,761	$	655,053

(7) GOODWILL

Goodwill is as follows (in thousands):

	June 30,		December 31,
	2018		2017
Brownsville terminals	$	8,485	$	8,485
West Coast terminals		943		943
	$	9,428	$	9,428

Goodwill is required to be tested for impairment annually unless events or changes in circumstances indicate it is more likely than not that an impairment loss has been incurred at an interim date. Our annual test for the impairment of goodwill is performed as of December 31. The impairment test is performed at the reporting unit level. Our reporting units are our operating segments (see Note 19 of Notes to consolidated financial statements). The fair value of each

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

reporting unit is determined on a stand‑alone basis from the perspective of a market participant and represents an estimate of the price that would be received to sell the unit as a whole in an orderly transaction between market participants at the measurement date. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered to be impaired.

At June 30, 2018 and December 31, 2017, our Brownsville and West Coast terminals contained goodwill. We did not recognize any goodwill impairment charges during the six months ended June 30, 2018 or during the year ended December 31, 2017 for these reporting units. However, a significant decline in the price of our common units with a resulting increase in the assumed market participants’ weighted average cost of capital, the loss of a significant customer, the disposition of significant assets, or an unforeseen increase in the costs to operate and maintain the Brownsville or West Coast terminals could result in the recognition of an impairment charge in the future.

(8) INVESTMENTS IN UNCONSOLIDATED AFFILIATES

At June 30, 2018 and December 31, 2017, our investments in unconsolidated affiliates include a 42.5% Class A ownership interest in Battleground Oil Specialty Terminal Company LLC (“BOSTCO”) and a 50% ownership interest in Frontera Brownsville LLC (“Frontera”). BOSTCO is a terminal facility located on the Houston Ship Channel that encompasses approximately 7.1 million barrels of distillate, residual and other black oil product storage. Class A and Class B ownership interests share in cash distributions on a 96.5% and 3.5% basis, respectively. Class B ownership interests do not have voting rights and are not required to make capital investments. Frontera is a terminal facility located in Brownsville, Texas that encompasses approximately 1.7 million barrels of light petroleum product storage, as well as related ancillary facilities.

The following table summarizes our investments in unconsolidated affiliates:

	Percentage of				Carrying value
	ownership				(in thousands)
	June 30,		December 31,		June 30,		December 31,
	2018		2017		2018		2017
BOSTCO	42.5	%	42.5	%	$	207,627	$	209,373
Frontera	50	%	50	%		24,140		23,808
Total investments in unconsolidated affiliates					$	231,767	$	233,181

At June 30, 2018 and December 31, 2017,  our investment in BOSTCO includes approximately $6.9 million and $7.0 million, respectively, of excess investment related to a one time buy-in fee to acquire our 42.5% interest and capitalization of interest on our investment during the construction of BOSTCO amortized over the useful life of the assets. Excess investment is the amount by which our investment exceeds our proportionate share of the book value of the net assets of the BOSTCO entity.

Earnings from investments in unconsolidated affiliates was as follows (in thousands):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
BOSTCO	$	1,848	$	1,275	$	3,839	$	2,981
Frontera		596		845		1,494		1,699
Total earnings from investments in unconsolidated affiliates	$	2,444	$	2,120	$	5,333	$	4,680

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

Additional capital investments in unconsolidated affiliates was as follows (in thousands):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
BOSTCO	$	—	$	145	$	—	$	145
Frontera		114		—		1,264		2,000
Additional capital investments in unconsolidated affiliates	$	114	$	145	$	1,264	$	2,145

Cash distributions received from unconsolidated affiliates was as follows (in thousands):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
BOSTCO	$	3,491	$	3,319	$	5,585	$	6,398
Frontera		1,330		1,227		2,426		2,497
Cash distributions received from unconsolidated affiliates	$	4,821	$	4,546	$	8,011	$	8,895

The summarized financial information of our unconsolidated affiliates is as follows (in thousands):

Balance sheets:

	BOSTCO				Frontera
	June 30,		December 31,		June 30,		December 31,
	2018		2017		2018		2017
Current assets	$	20,794	$	24,976	$	5,720	$	5,649
Long-term assets		460,308		469,348		44,613		44,292
Current liabilities		(7,590)		(17,550)		(1,922)		(2,147)
Long-term liabilities		(1,314)		—		(131)		(178)
Net assets	$	472,198	$	476,774	$	48,280	$	47,616

Statements of operations:

	BOSTCO				Frontera
	Three months ended				Three months ended
	June 30,				June 30,
	2018		2017		2018		2017
Revenue	$	16,908	$	17,028	$	6,009	$	5,198
Expenses		(11,515)		(13,628)		(4,817)		(3,508)
Net earnings	$	5,393	$	3,400	$	1,192	$	1,690

	BOSTCO				Frontera
	Six months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
Revenue	$	33,735	$	33,658	$	11,921	$	10,591
Expenses		(24,064)		(25,866)		(8,933)		(7,193)
Net earnings	$	9,671	$	7,792	$	2,988	$	3,398

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

(9) OTHER ASSETS, NET

Other assets, net are as follows (in thousands):

	June 30,		December 31,
	2018		2017
Customer relationships, net of accumulated amortization of $3,679 and $2,294, respectively	$	45,751	$	47,136
Revolving credit facility unamortized deferred issuance costs, net of accumulated amortization of $6,807 and $5,984, respectively		6,364		6,778
Amounts due under long-term terminaling services agreements		439		460
Unrealized gain on derivative instruments		—		576
Deposits and other assets		289		288
	$	52,843	$	55,238

Customer relationships.    Other assets, net include certain customer relationships primarily at our West Coast terminals. These customer relationships are being amortized on a straight‑line basis over twenty years.

Revolving credit facility unamortized deferred issuance costs.  Deferred issuance costs are amortized using the effective interest method over the term of the related revolving credit facility.

Amounts due under long‑term terminaling services agreements.  We have long‑term terminaling services agreements with certain of our customers that provide for minimum payments that increase at stated amounts over the terms of the respective agreements. We recognize as revenue the minimum payments under the long‑term terminaling services agreements on a straight‑line basis over the terms of the respective agreements. At June 30, 2018 and December 31, 2017, we have recognized revenue in excess of the minimum payments that was due through those respective dates under the long‑term terminaling services agreements resulting in an asset of approximately $0.4 million and $0.5 million, respectively.

(10) ACCRUED LIABILITIES

Accrued liabilities are as follows (in thousands):

	June 30,		December 31,
	2018		2017
Customer advances and deposits	$	8,540	$	10,265
Accrued property taxes		4,277		1,381
Accrued environmental obligations		1,836		1,855
Interest payable		7,960		982
Accrued expenses and other		4,063		2,943
	$	26,676	$	17,426

Customer advances and deposits.  We bill certain of our customers one month in advance for terminaling services to be provided in the following month. At June 30, 2018, approximately $0.4 million of the customer advances and deposits balance is considered contract liabilities under ASC 606. Revenue recognized during the six months ended June 30, 2018 from amounts included in contract liabilities at the beginning of the period was approximately $0.5 million. At June 30, 2018 and December 31, 2017, we have billed and collected from certain of our customers approximately $8.5 million and $10.3 million, respectively, in advance of the terminaling services being provided.

Accrued environmental obligations.  At both June 30, 2018 and December 31, 2017, we have accrued environmental obligations of approximately $1.8 million and $1.9 million, respectively, representing our best estimate of our remediation obligations. During the six months ended June 30, 2018, we made payments of approximately $0.2 million towards our environmental remediation obligations. During the six months ended June 30, 2018, we increased

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

our estimate of our future environmental remediation costs by approximately $0.2 million. Changes in our estimates of our future environmental remediation obligations may occur as a result of the passage of time and the occurrence of future events.

(11) OTHER LIABILITIES

Other liabilities are as follows (in thousands):

	June 30,		December 31,
	2018		2017
Advance payments received under long-term terminaling services agreements	$	1,782	$	1,599
Deferred revenue—ethanol blending fees and other projects		1,755		2,034
	$	3,537	$	3,633

Advance payments received under long‑term terminaling services agreements.  We have long‑term terminaling services agreements with certain of our customers that provide for advance minimum payments. We recognize the advance minimum payments as revenue either on a straight‑line basis over the term of the respective agreements or when services have been provided based on volumes of product distributed. At June 30, 2018 and December 31, 2017, we have received advance minimum payments in excess of revenue recognized under these long‑term terminaling services agreements resulting in a liability of approximately $1.8 million and $1.6 million, respectively.

Deferred revenue—ethanol blending fees and other projects.  Pursuant to agreements with our customers, we agreed to undertake certain capital projects that primarily pertain to providing ethanol blending functionality at certain of our Southeast terminals. Upon completion of the projects, our customers have paid us amounts that will be recognized as revenue on a straight‑line basis over the remaining term of the agreements. At June 30, 2018 and December 31, 2017, we have unamortized deferred revenue for completed projects of approximately $1.8 million and $2.0 million, respectively. During the six months ended June 30, 2018, we billed customers approximately $0.9 million for completed projects and recognized revenue for completed projects on a straight‑line basis of approximately $1.2 million. During the six months ended June 30, 2017, we recognized revenue for completed projects on a straight-line basis of approximately $0.3 million. At June 30, 2018, approximately $nil of the deferred revenue-ethanol blending fees and other projects balance is considered contract liabilities under ASC 606. Revenue recognized during the six months ended June 30, 2018 from amounts included in contract liabilities under ASC 606 at the beginning of the period was approximately $0.2 million.

(12) LONG‑TERM DEBT

Long-term debt is as follows (in thousands):

	June 30,		December 31,
	2018		2017
Revolving credit facility due in 2022	$	286,300	$	593,200
6.125% senior notes due in 2026		300,000		—
Senior notes unamortized deferred issuance costs, net of accumulated amortization of $301 and $nil, respectively		(7,777)		—
	$	578,523	$	593,200

On February 12, 2018, the Partnership and TLP Finance Corp., our wholly owned subsidiary, completed the sale of $300 million of 6.125% senior notes, issued at par and due 2026. The senior notes were guaranteed on a senior unsecured basis by each of our 100% owned domestic subsidiaries that guarantee obligations under our revolving credit facility. Net proceeds after $8.1 million of issuance costs, were used to repay indebtedness under our revolving credit facility.

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

Our senior secured revolving credit facility, or our “revolving credit facility”, provides for a maximum borrowing line of credit equal to $850 million. The terms of our revolving credit facility include covenants that restrict our ability to make cash distributions, acquisitions and investments, including investments in joint ventures. We may make distributions of cash to the extent of our “available cash” as defined in our partnership agreement. We may make acquisitions and investments that meet the definition of “permitted acquisitions”; “other investments” which may not exceed 5% of “consolidated net tangible assets”; and additional future “permitted JV investments” up to $175 million, which may include additional investments in BOSTCO. The primary financial covenants contained in our revolving credit facility are (i) a total leverage ratio test (not to exceed 5.25 to 1.0), (ii) a senior secured leverage ratio test (not to exceed 3.75 to 1.0), and (iii) a minimum interest coverage ratio test (not less than 2.75 to 1.0). The principal balance of loans and any accrued and unpaid interest are due and payable in full on the maturity date in March 2022. We were in compliance with all financial covenants as of and during the six months ended June 30, 2018 and the year ended December 31, 2017.  

We may elect to have loans under our revolving credit facility bear interest either (i) at a rate of LIBOR plus a margin ranging from 1.75% to 2.75% depending on the total leverage ratio then in effect, or (ii) at the base rate plus a margin ranging from 0.75% to 1.75% depending on the total leverage ratio then in effect. We also pay a commitment fee on the unused amount of commitments, ranging from 0.375% to 0.5% per annum, depending on the total leverage ratio then in effect. Our obligations under our revolving credit facility are secured by a first priority security interest in favor of the lenders in the majority of our assets, including our investments in unconsolidated affiliates. For the six months ended June 30, 2018 and 2017, the weighted average interest rate on borrowings under our revolving credit facility was approximately 4.7% and 3.4%, respectively. At June 30, 2018 and December 31, 2017, our outstanding borrowings under our revolving credit facility were $286.3 million and $593.2 million, respectively. At both June 30, 2018 and December 31, 2017 our outstanding letters of credit were $0.4 million.

We have an effective universal shelf‑registration statement and prospectus on Form S‑3 with the Securities and Exchange Commission (“SEC”) that expires in September 2019. In February 2018, we and TLP Finance Corp., our 100% owned subsidiary, used the shelf registration statement to issue senior notes that were guaranteed on a senior unsecured basis by each of our 100% owned domestic subsidiaries that guarantee obligations under our revolving credit facility. In the future, we may issue additional debt or equity securities pursuant to that registration statement. TransMontaigne Partners L.P. has no independent assets or operations unrelated to its investments in its consolidated subsidiaries. TLP Finance Corp. has no assets or operations. Our operations are conducted by subsidiaries of TransMontaigne Partners L.P. through our 100% owned operating company subsidiary, TransMontaigne Operating Company L.P. Each of TransMontaigne Operating Company L.P.s’ and our other 100% owned domestic subsidiaries (other than TLP Finance Corp., whose sole purpose is to act as co‑issuer of any debt securities) may guarantee any future debt securities we issue. We expect that any guarantees associated with future debt securities will be full and unconditional and joint and several, subject to certain automatic customary releases, including sale, disposition, or transfer of the capital stock or substantially all of the assets of a subsidiary guarantor, exercise of legal defeasance option or covenant defeasance option, and designation of a subsidiary guarantor as unrestricted in accordance with the indenture. There are no significant restrictions on the ability of TransMontaigne Partners L.P. or any guarantor to obtain funds from its subsidiaries by dividend or loan. None of the assets of TransMontaigne Partners L.P. or a guarantor represent restricted net assets pursuant to the guidelines established by the SEC.

(13) PARTNERS’ EQUITY

The number of units outstanding is as follows:

		General
	Common	partner
	units	equivalent units
Units outstanding at December 31, 2017	16,177,353	330,150
Issuance of common units pursuant to our savings and retention program	44,798	—
Contribution of cash by TransMontaigne GP to maintain its 2% general partner interest	—	905
Units outstanding at June 30, 2018	16,222,151	331,055

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

(14) EQUITY-BASED COMPENSATION

Long-term incentive plan. The TLP Management Services long-term incentive plan reserves 750,000 common units to be granted as awards under the plan, with such amount subject to adjustment as provided for under the terms of the plan if there is a change in our common units, such as a unit split or other reorganization. The common units authorized to be granted under the TLP Management Services long-term incentive plan are registered pursuant to a registration statement on Form S-8.

The TLP Management Services long‑term incentive plan is administered by the compensation committee of the board of directors of our general partner and is used for grants of units to the independent directors of our general partner. The grants to the independent directors of our general partner under the TLP Management Services long-term incentive plan are immediately vested and not subject to forfeiture. Accordingly, there are no long-term incentive plan grants outstanding as of June 30, 2018.

Generally accepted accounting principles require us to measure the cost of board member services received in exchange for an award of equity instruments based on the grant‑date fair value of the award. That cost is recognized over the vesting period on a straight line basis during which a board member is required to provide services in exchange for the award with the costs being accelerated upon the occurrence of accelerated vesting events, such as a change in control of our general partner. 

For awards to the independent directors of our general partner, equity-based compensation of approximately $140,000 is included in equity-based compensation expense for both the six months ended June 30, 2018 and 2017.

Savings and retention program. TLP Management Services savings and retention programis intended to constitute a program under, and be subject to, the TLP Management Services long-term incentive plan described above. The savings and retention program is used for awards to employees of TLP Management Services who provide services to the Partnership.

The restricted phantom units awarded and accrued under the savings and retention program are subject to forfeiture until the vesting date. Recipients have distribution equivalent rights from the date of grant that accrue additional restricted phantom units equivalent to the value of quarterly distributions paid by us on each of our outstanding common units. Recipients of restricted phantom units under the savings and retention program do not have voting rights.

The purpose of the savings and retention program is to provide for the reward and retention of participants by providing them with bonus awards that vest over future service periods. Awards under the program generally become vested as to 50% of a participant’s annual award as of the first day of the month that falls closest to the second anniversary of the grant date, and the remaining 50% as of the first day of the month that falls closest to the third anniversary of the grant date, subject to earlier vesting upon a participant’s attainment of the age and length of service thresholds, retirement, death or disability, involuntary termination without cause, or termination of a participant’s employment following a change in control of the Partnership, our general partner or TLP Management Services, as specified in the program.

A person will satisfy the age and length of service thresholds of the program upon the attainment of the earliest of (a) age sixty, (b) age fifty five and ten years of service as an officer of TLP Management Services or any of its affiliates or predecessors, or (c) age fifty and twenty years of service as an employee of TLP Management Services or any of its affiliates or predecessors.

Under the omnibus agreement we have agreed to reimburse the owner of TransMontaigne GP for bonus awards made to key employees under the savings and retention program, provided the compensation committee and the conflicts committee of our general partner approve the annual awards granted under the program (see Note 2 of Notes to consolidated financial statements). We have the option to provide the reimbursement in either a cash payment or the

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

delivery of our common units to the savings and retention program or alternatively directly to the award recipients, with the reimbursement made in accordance with the underlying vesting and payment schedule of the savings and retention program. Our reimbursement for the bonus awards is reduced for forfeitures and is increased for the value of quarterly distributions accrued under the distribution equivalent rights. We have the intent and ability to settle our reimbursement for the bonus awards in our common units, and accordingly, we account for the bonus awards as an equity award.

Given that we do not have any employees to provide corporate and support services and instead we contract for such services under the omnibus agreement, generally accepted accounting principles require us to classify the savings and retention program awards as a non-employee award and measure the cost of services received in exchange for an award of equity instruments based on the vesting‑date fair value of the award. That cost, or an estimate of that cost in the case of unvested restricted phantom units, is recognized over the period during which services are provided in exchange for the award. As of June 30, 2018, there was approximately $1.9 million of total unrecognized equity-based compensation expense related to unvested restricted phantom units, which is expected to be recognized over the remaining weighted average period of 1.73 years.

For bonus awards to employees of TLP Management Services, approximately $2.3 million and $2.0 million is included in equity-based compensation expense for the six months ended June 30, 2018 and 2017, respectively.

Activity related to our equity-based awards granted under the savings and retention program for services performed under the omnibus agreement for the six months ended June 30, 2018 is as follows:

		Weighted			Weighted
		average			average
	Vested	price		Unvested	price
Restricted phantom units outstanding at December 31, 2017	91,877	$	38.91	54,244	$	38.81
Issuance of units	(44,798)	$	37.75	—	$	—
Units withheld for settlement of withholding taxes	(16,822)	$	37.59	—	$	—
Unit accrual for distributions paid	3,371	$	37.53	2,447	$	37.56
Vesting of units	18,970	$	36.61	(18,970)	$	36.61
Grant of units	46,362	$	35.23	33,097	$	35.23
Forfeiture of units	—	$	—	(809)	$	35.23
Restricted phantom units outstanding at June 30, 2018	98,960	$	38.52	70,009	$	38.22
Vested and expected to vest at June 30, 2018	168,969	$	38.40

24

TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

(15) NET EARNINGS PER LIMITED PARTNER UNIT

The following table reconciles net earnings to net earnings allocable to limited partners and sets forth the computation of basic and diluted net earnings per limited partner unit (in thousands, except per unit amounts):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
Net earnings	$	9,460	$	14,478	$	21,634	$	27,432
Less:
Distributions payable on behalf of incentive distribution rights		(3,758)		(2,873)		(7,353)		(5,509)
Distributions payable on behalf of general partner interest		(263)		(244)		(522)		(483)
Earnings allocable to general partner interest less than distributions payable to general partner interest		149		12		237		44
Earnings allocable to general partner interest including incentive distribution rights		(3,872)		(3,105)		(7,638)		(5,948)
Net earnings allocable to limited partners per the consolidated statements of operations	$	5,588	$	11,373	$	13,996	$	21,484
Basic weighted average units		16,327		16,260		16,310		16,253
Diluted weighted average units		16,356		16,279		16,345		16,271
Net earnings per limited partner unit—basic	$	0.34	$	0.70	$	0.86	$	1.32
Net earnings per limited partner unit—diluted	$	0.34	$	0.70	$	0.86	$	1.32

Pursuant to our partnership agreement we are required to distribute available cash (as defined by our partnership agreement) as of the end of the reporting period. Such distributions are declared within 45 days after period end. The following table sets forth the distribution declared per common unit attributable to the periods indicated:

	Distribution
January 1, 2017 through March 31, 2017	$	0.725
April 1, 2017 through June 30, 2017	$	0.740
July 1, 2017 through September 30, 2017	$	0.755
October 1, 2017 through December 31, 2017	$	0.770
January 1, 2018 through March 31, 2018	$	0.785
April 1, 2018 through June 30, 2018	$	0.795

(16) COMMITMENTS AND CONTINGENCIES

Contract commitments.  At June 30, 2018, we have contractual commitments of approximately $38.0 million for the supply of services, labor and materials related to capital projects that currently are under development. We expect that these contractual commitments will be paid within the next twelve months.

Operating leases.  We lease property and equipment under non‑cancelable operating leases. At June 30, 2018, future minimum lease payments under these non‑cancelable operating leases are as follows (in thousands):

Years ending December 31:
2018 (remainder of the year)	$	1,534
2019		3,409
2020		2,047
2021		1,929
2022		978
Thereafter		4,276
	$	14,173

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

Included in the above non‑cancelable operating lease commitments are amounts for property rentals that we have sublet under non‑cancelable sublease agreements or have reimbursement agreements with affiliates, for which we expect to receive minimum rentals of approximately $7.8 million in future periods.

Rental expense under operating leases was approximately $0.5 million and $0.9 million for the three months ended June 30, 2018 and 2017, respectively, and $1.0 million and $1.7 million for the six months ended June 30, 2018 and 2017, respectively.  

Legal proceedings. We are party to various legal, regulatory and other matters arising from the day-to-day operations of our business that may result in claims against us. While the ultimate impact of any proceedings cannot be predicted with certainty, our management believes that the resolution of any of our pending legal proceedings will not have a material adverse effect on our business, financial position, results of operations or cash flows. 

(17) DISCLOSURES ABOUT FAIR VALUE

“GAAP” defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. GAAP also establishes a fair value hierarchy that prioritizes the use of higher‑level inputs for valuation techniques used to measure fair value. The three levels of the fair value hierarchy are: (1) Level 1 inputs, which are quoted prices (unadjusted) in active markets for identical assets or liabilities; (2) Level 2 inputs, which are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly; and (3) Level 3 inputs, which are unobservable inputs for the asset or liability.

The fair values of the following financial instruments represent our best estimate of the amounts that would be received to sell those assets or that would be paid to transfer those liabilities in an orderly transaction between market participants at that date. Our fair value measurements maximize the use of observable inputs. However, in situations where there is little, if any, market activity for the asset or liability at the measurement date, the fair value measurement reflects our judgments about the assumptions that market participants would use in pricing the asset or liability based on the best information available in the circumstances. The following methods and assumptions were used to estimate the fair value of financial instruments at June 30, 2018 and December 31, 2017.

Cash equivalents.  The carrying amount approximates fair value because of the short‑term maturity of these instruments. The fair value is categorized in Level 1 of the fair value hierarchy.

Derivative instruments.  The carrying amount of our interest rate swaps was determined using a pricing model based on the LIBOR swap rate and other observable market data. The fair value is categorized in Level 2 of the fair value hierarchy.

Debt. The carrying amount of our revolving credit facility debt approximates fair value since borrowings under the facility bear interest at current market interest rates. The carrying value of our publicly traded senior notes approximates fair value as of June 30, 2018 and December 31, 2017. The fair value of our publicly traded senior notes is based on the prices of those senior notes at June 30, 2018 and December 31, 2017. The fair value is categorized in Level 2 of the fair value hierarchy.

(18) REVENUE FROM CONTRACTS WITH CUSTOMERS

The majority of our terminaling service agreements contain firm commitments for minimum revenue streams and are accounted for in accordance with ASC 840, Leases (“ASC 840 revenue”). The remainder is recognized in accordance with ASC 606, Revenue From Contracts With Customers (“ASC 606 revenue”).

26

TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

The following table provides details of our revenue disaggregated by category of revenue (in thousands):    

	Three months ended		Six months ended
	June 30,		June 30,
	2018		2018
Terminaling services fees:
Firm commitments (ASC 840 revenue)	$	39,149	$	77,855
Firm commitments (ASC 606 revenue)		3,549		6,976
Total firm commitments revenue		42,698		84,831
Ancillary revenue (ASC 606 revenue)		9,680		20,738
Total terminaling services fees		52,378		105,569
Pipeline transportation fees (ASC 840 revenue)		794		1,663
Management fees (ASC 606 revenue)		2,172		4,556
Total revenue	$	55,344	$	111,788

The following table includes our estimated revenue associated with our firm commitments under our terminaling services fees which is expected to be recognized as ASC 606 revenue in the specified period related to the future performance obligations as of the end of the reporting period (in thousands):

Estimated Future ASC 606 Revenue by Segment

			Midwest
			Terminals and
	Gulf Coast		Pipeline			Brownsville		River		Southeast		West Coast
	Terminals		System			Terminals		Terminals		Terminals		Terminals		Total
Remainder of 2018	$	2,060	$	—	$	—	$	578	$	—	$	3,040	$	5,678
2019		721		—		—		1,039		—		1,594		3,354
2020		—		—		—		1,039		—		125		1,164
2021		—		—		—		519		—		—		519
Thereafter		—		—		—		—		—		—		—
Total estimated ASC 606 revenue	$	2,781	$	—	$	—	$	3,175	$	—	$	4,759	$	10,715

Our ASC 606 revenue, for purposes of the tabular presentation above, excludes estimates of future rate changes due to changes in indices or contractually negotiated rate escalations and is generally limited to contracts that have minimum payment arrangements. The balances include the full amount of our customer commitments accounted for as ASC 606 revenue as of June 30, 2018 through the expiration of the related contracts. The balances disclosed exclude all performance obligations for which the original expected term is one year or less, the term of the contract with the customer is open and cannot be estimated, the contract includes options for future purchases or the consideration is variable.

Estimated revenue in the table above excludes revenue arrangements accounted for in accordance with ASC 840 in the amount of $77.3 million for the remainder of 2018, $124.2 million for 2019, $103.3 million for 2020, $78.5 million for 2021 and $59.9 million thereafter.

27

TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

(19) BUSINESS SEGMENTS

We provide integrated terminaling, storage, transportation and related services to companies engaged in the trading, distribution and marketing of refined petroleum products, crude oil, chemicals, fertilizers and other liquid products. Our chief operating decision maker is our general partner’s chief executive officer. Our general partner’s chief executive officer reviews the financial performance of our business segments using disaggregated financial information about “net margins” for purposes of making operating decisions and assessing financial performance. “Net margins” is composed of revenue less direct operating costs and expenses. Accordingly, we present “net margins” for each of our business segments: (i) Gulf Coast terminals, (ii) Midwest terminals and pipeline system, (iii) Brownsville terminals, (iv) River terminals, (v) Southeast terminals and (vi) West Coast terminals.

28

TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

The financial performance of our business segments is as follows (in thousands):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
Gulf Coast Terminals:
Terminaling services fees	$	16,465	$	15,533	$	32,638	$	31,540
Management fees		86		263		183		546
Revenue		16,551		15,796		32,821		32,086
Direct operating costs and expenses		(5,413)		(5,426)		(11,245)		(10,980)
Net margins		11,138		10,370		21,576		21,106
Midwest Terminals and Pipeline System:
Terminaling services fees		2,405		2,465		4,824		4,868
Pipeline transportation fees		433		433		866		866
Revenue		2,838		2,898		5,690		5,734
Direct operating costs and expenses		(743)		(693)		(1,455)		(1,405)
Net margins		2,095		2,205		4,235		4,329
Brownsville Terminals:
Terminaling services fees		1,977		2,505		4,043		4,972
Pipeline transportation fees		361		1,363		797		2,646
Management fees		1,892		1,614		3,996		3,538
Revenue		4,230		5,482		8,836		11,156
Direct operating costs and expenses		(2,135)		(2,582)		(4,176)		(5,454)
Net margins		2,095		2,900		4,660		5,702
River Terminals:
Terminaling services fees		2,589		2,740		5,343		5,410
Revenue		2,589		2,740		5,343		5,410
Direct operating costs and expenses		(1,805)		(1,535)		(3,641)		(3,185)
Net margins		784		1,205		1,702		2,225
Southeast Terminals:
Terminaling services fees		19,510		18,263		39,749		35,460
Management fees		194		185		377		368
Revenue		19,704		18,448		40,126		35,828
Direct operating costs and expenses		(5,714)		(5,748)		(12,333)		(11,471)
Net margins		13,990		12,700		27,793		24,357
West Coast Terminals:
Terminaling services fees		9,432		—		18,972		—
Revenue		9,432		—		18,972		—
Direct operating costs and expenses		(3,465)		—		(6,570)		—
Net margins		5,967		—		12,402		—
Total net margins		36,069		29,380		72,368		57,719
General and administrative expenses		(4,619)		(4,080)		(9,600)		(8,051)
Insurance expenses		(1,271)		(1,002)		(2,517)		(2,008)
Equity-based compensation expense		(441)		(352)		(2,458)		(2,169)
Depreciation and amortization		(13,160)		(8,792)		(24,968)		(17,497)
Earnings from unconsolidated affiliates		2,444		2,120		5,333		4,680
Operating income		19,022		17,274		38,158		32,674
Other expenses		(9,562)		(2,796)		(16,524)		(5,242)
Net earnings	$	9,460	$	14,478	$	21,634	$	27,432

29

TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

Supplemental information about our business segments is summarized below (in thousands):

	Three months ended June 30, 2018
			Midwest
			Terminals and
	Gulf Coast		Pipeline		Brownsville		River		Southeast		West Coast
	Terminals		System		Terminals		Terminals		Terminals		Terminals		Total
Revenue:
External customers	$	14,480	$	2,838	$	2,336	$	2,589	$	19,704	$	9,432	$	51,379
Frontera		—		—		1,894		—		—		—		1,894
Associated Asphalt, LLC		2,071		—		—		—		—		—		2,071
Revenue	$	16,551	$	2,838	$	4,230	$	2,589	$	19,704	$	9,432	$	55,344
Capital expenditures	$	1,814	$	35	$	2,024	$	345	$	9,152	$	2,082	$	15,452
Identifiable assets	$	122,011	$	20,488	$	42,507	$	48,710	$	221,539	$	274,479	$	729,734
Cash and cash equivalents														390
Investments in unconsolidated affiliates														231,767
Deferred issuance costs														6,364
Other														6,567
Total assets													$	974,822

	Three months ended June 30, 2017
			Midwest
			Terminals and
	Gulf Coast		Pipeline		Brownsville		River		Southeast		West Coast
	Terminals		System		Terminals		Terminals		Terminals		Terminals		Total
Revenue:
External customers	$	15,796	$	2,898	$	3,968	$	2,740	$	18,448	$	—	$	43,850
Frontera		—		—		1,514		—		—		—		1,514
Revenue	$	15,796	$	2,898	$	5,482	$	2,740	$	18,448	$	—	$	45,364
Capital expenditures	$	1,059	$	45	$	228	$	652	$	17,161	$	—	$	19,145

	Six months ended June 30, 2018
			Midwest
			Terminals and
	Gulf Coast		Pipeline		Brownsville		River		Southeast		West Coast
	Terminals		System		Terminals		Terminals		Terminals		Terminals		Total
Revenue:
External customers	$	28,538	$	5,690	$	4,824	$	5,343	$	40,126	$	18,972	$	103,493
Frontera		—		—		4,012		—		—		—		4,012
Associated Asphalt, LLC		4,283		—		—		—		—		—		4,283
Revenue	$	32,821	$	5,690	$	8,836	$	5,343	$	40,126	$	18,972	$	111,788
Capital expenditures	$	3,180	$	336	$	2,467	$	892	$	12,435	$	2,645	$	21,955

30

TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

	Six months ended June 30, 2017
			Midwest
			Terminals and
	Gulf Coast		Pipeline		Brownsville		River		Southeast		West Coast
	Terminals		System		Terminals		Terminals		Terminals		Terminals		Total
Revenue:
External customers	$	32,086	$	5,734	$	7,872	$	5,410	$	35,828	$	—	$	86,930
Frontera		—		—		3,284		—		—		—		3,284
Revenue	$	32,086	$	5,734	$	11,156	$	5,410	$	35,828	$	—	$	90,214
Capital expenditures	$	2,586	$	267	$	372	$	1,046	$	24,374	$	—	$	28,645

31

TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (continued)

r

(20) SUBSEQUENT EVENTS

ArcLight buyout offer.    On July 9, 2018 the board of directors of TransMontaigne GP L.L.C. received a non-binding proposal from affiliates of ArcLight, directed to the conflicts committee of our general partner, pursuant to which ArcLight would acquire through a subsidiary all common units of the Partnership that ArcLight and its affiliates do not already own in exchange for $38.00 per common unit. If approved, the transaction would be effected through a merger of the Partnership with a subsidiary of ArcLight.

The transaction, as proposed, is subject to a number of contingencies, including ArcLight’s completion of due diligence, the approval of the conflicts committee, the approval by holders of a majority of the outstanding common units of the Partnership and the satisfaction of any conditions to the consummation of a transaction set forth in any definitive agreement concerning the transaction. There can be no assurance that definitive documentation will be executed or that any transaction will materialize.

Quarterly distribution.  On July 17, 2018, we announced a distribution of $0.795 per unit for the period from April 1, 2018 through June 30, 2018. This distribution was paid on August 8, 2018 to unitholders of record on July 31, 2018. 

32

ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

RECENT DEVELOPMENTS

ArcLight buyout offer.    On July 9, 2018 the board of directors of TransMontaigne GP L.L.C. received a non-binding proposal from affiliates of ArcLight, directed to the conflicts committee of our general partner, pursuant to which ArcLight would acquire through a subsidiary all common units of the Partnership that ArcLight and its affiliates do not already own in exchange for $38.00 per common unit. If approved, the transaction would be effected through a merger of the Partnership with a subsidiary of ArcLight.

The transaction, as proposed, is subject to a number of contingencies, including ArcLight’s completion of due diligence, the approval of the conflicts committee, the approval by holders of a majority of the outstanding common units of the Partnership and the satisfaction of any conditions to the consummation of a transaction set forth in any definitive agreement concerning the transaction. There can be no assurance that definitive documentation will be executed or that any transaction will materialize.

Eleventh consecutive increase in quarterly distribution.On July 17, 2018, we announced a quarterly distribution of $0.795 per unit for the three months ended June 30, 2018. This $0.01 increase over the previous quarter reflects the eleventh consecutive increase in our distribution and represents annual growth of 7.4% over the second quarter of last year. This distribution was paid on August 8, 2018 to unitholders of record on July 31, 2018.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

A summary of the significant accounting policies that we have adopted and followed in the preparation of our consolidated financial statements is detailed in our consolidated financial statements for the year ended December 31, 2017, included in our Annual Report on Form 10‑K, filed on March 15, 2018. Certain of these accounting policies require the use of estimates. The following estimates, in management’s opinion, are subjective in nature, require the exercise of judgment, and involve complex analyses: business combination estimates and assumptions, useful lives of our plant and equipment and accrued environmental obligations. These estimates are based on our knowledge and understanding of current conditions and actions we may take in the future. Changes in these estimates will occur as a result of the passage of time and the occurrence of future events. Subsequent changes in these estimates may have a significant impact on our financial condition and results of operations (see Note 1 of Notes to consolidated financial statements).

RESULTS OF OPERATIONS—THREE MONTHS ENDED JUNE 30, 2018 AND 2017

The following discussion and analysis of the results of operations and financial condition should be read in conjunction with the accompanying unaudited consolidated financial statements.

ANALYSIS OF REVENUE

Total revenue.  We derive revenue from our terminal and pipeline transportation operations by charging fees for providing integrated terminaling, transportation and related services. Our total revenue by category was as follows (in thousands):

Total Revenue by Category

	Three months ended June 30,
	2018		2017
Terminaling services fees	$	52,378	$	41,506
Pipeline transportation fees		794		1,796
Management fees		2,172		2,062
Revenue	$	55,344	$	45,364

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See discussion below for a detailed analysis of terminaling services fees, pipeline transportation fees and management fees included in the table above.

We operate our business and report our results of operations in six principal business segments: (i) Gulf Coast terminals, (ii) Midwest terminals and pipeline system, (iii) Brownsville terminals, (iv) River terminals, (v) Southeast terminals and (vi) West Coast terminals. The aggregate revenue of each of our business segments was as follows (in thousands):

Total Revenue by Business Segment

	Three months ended June 30,
	2018		2017
Gulf Coast terminals	$	16,551	$	15,796
Midwest terminals and pipeline system		2,838		2,898
Brownsville terminals		4,230		5,482
River terminals		2,589		2,740
Southeast terminals		19,704		18,448
West Coast terminals		9,432		—
Revenue	$	55,344	$	45,364

Total revenue by business segment is presented and further analyzed below by category of revenue.

Terminaling services fees.    Our terminaling services agreements are structured as either throughput agreements or storage agreements. Our throughput agreements contain provisions that require our customers to make minimum payments, which are based on contractually established minimum volume of throughput of the customer’s product at our facilities over a stipulated period of time. Due to this minimum payment arrangement, we recognize a fixed amount of revenue from the customer over a certain period of time, even if the customer throughputs less than the minimum volume of product during that period. In addition, if a customer throughputs a volume of product exceeding the minimum volume, we would recognize additional revenue on this incremental volume. Our storage agreements require our customers to make minimum payments based on the volume of storage capacity available to the customer under the agreement, which results in a fixed amount of recognized revenue.

We refer to the fixed amount of revenue recognized pursuant to our terminaling services agreements as being “firm commitments.” Revenue recognized in excess of firm commitments and revenue recognized based solely on the volume of product distributed or injected are referred to as “ancillary.” In addition “ancillary” revenue also includes fees received from ancillary services including heating and mixing of stored products, product transfer, railcar handling, butane blending, proceeds from the sale of product gains, wharfage and vapor recovery.

The terminaling services fees by business segments were as follows (in thousands):

Terminaling Services Fees by Business Segment

	Three months ended June 30,
	2018		2017
Gulf Coast terminals	$	16,465	$	15,533
Midwest terminals and pipeline system		2,405		2,465
Brownsville terminals		1,977		2,505
River terminals		2,589		2,740
Southeast terminals		19,510		18,263
West Coast terminals		9,432		—
Terminaling services fees	$	52,378	$	41,506

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The increase in terminaling services fees at our Southeast terminals includes an increase of approximately $1.0 million resulting from placing into service approximately 2.0 million barrels of new tank capacity at our Collins, Mississippi bulk storage terminal in various stages beginning in the fourth quarter of 2016 through the second quarter of 2017. The increase in terminaling services fees at our West Coast terminals is a result of the West Coast terminals acquisition on December 15, 2017.

Included in terminaling services fees for the three months ended June 30, 2018 and 2017 are fees charged to affiliates of approximately $2.7 million and $0.4 million, respectively.

The “firm commitments” and “ancillary” revenue included in terminaling services fees were as follows (in thousands):

Firm Commitments and Ancillary Revenue

	Three months ended June 30,
	2018		2017
Firm commitments	$	42,698	$	33,669
Ancillary		9,680		7,837
Terminaling services fees	$	52,378	$	41,506

The remaining terms on the terminaling services agreements that generated “firm commitments” for the three months ended June 30, 2018 are as follows (in thousands):

Less than 1 year remaining	$	11,206	26%
1 year or more, but less than 3 years remaining		11,563	27%
3 years or more, but less than 5 years remaining		17,857	42%
5 years or more remaining		2,072	5%
Total firm commitments for the three months ended June 30, 2018	$	42,698

Pipeline transportation fees.    We earned pipeline transportation fees at our Diamondback pipeline either based on the volume of product transported or under capacity reservation agreements. Revenue associated with the capacity reservation is recognized ratably over the respective term, regardless of whether the capacity is actually utilized. We earn pipeline transportation fees at our Razorback pipeline based on an allocation of the aggregate fees charged under the capacity agreement with our customer who has contracted for 100% of our Razorback system. We own the Razorback and Diamondback pipelines, and we leased the Ella‑Brownsville pipeline from a third party through December 31, 2017. The pipeline transportation fees by business segments were as follows (in thousands):

Pipeline Transportation Fees by Business Segment

	Three months ended June 30,
	2018		2017
Gulf Coast terminals	$	—	$	—
Midwest terminals and pipeline system		433		433
Brownsville terminals		361		1,363
River terminals		—		—
Southeast terminals		—		—
West Coast terminals		—		—
Pipeline transportation fees	$	794	$	1,796

The decrease in pipeline transportation fees at our Brownsville terminals is attributable to suspending operations on the Diamondback pipeline in the first quarter of 2018 in connection with the expansion of our Brownville operations. We expect to recommission and resume operations on the Diamondback pipeline by the end of 2019.

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Management fees.    We manage and operate certain tank capacity at our Port Everglades South terminal for a major oil company and receive a reimbursement of its proportionate share of operating and maintenance costs. We manage and operate the Frontera joint venture and receive a management fee based on our costs incurred. We also currently manage and operate for an affiliate of PEMEX, Mexico’s state-owned petroleum company, a bi-directional products pipeline connected to our Brownsville terminal facility and receive a management fee. We expect this operating arrangement to expire in the third quarter of 2018, after which it is anticipated that a third party will take operatorship of the pipeline. We manage and operate rail sites at certain Southeast terminals on behalf of a major oil company and receive reimbursement for operating and maintenance costs. The management fees by business segments were as follows (in thousands):

Management Fees by Business Segment

	Three months ended June 30,
	2018		2017
Gulf Coast terminals	$	86	$	263
Midwest terminals and pipeline system		—		—
Brownsville terminals		1,892		1,614
River terminals		—		—
Southeast terminals		194		185
West Coast terminals		—		—
Management fees	$	2,172	$	2,062

Included in management fees for the three months ended June 30, 2018 and 2017 are fees charged to affiliates of approximately $1.3 million and $1.1 million, respectively.

ANALYSIS OF COSTS AND EXPENSES

The direct operating costs and expenses of our operations include the directly related wages and employee benefits, utilities, communications, repairs and maintenance, rent, property taxes, vehicle expenses, environmental compliance costs, materials and supplies. Consistent with historical trends across our terminaling and transportation facilities we anticipate an increase in repairs and maintenance expenses in the later months of the year as the weather becomes more conducive to these types of projects. The direct operating costs and expenses of our operations were as follows (in thousands):

Direct Operating Costs and Expenses

	Three months ended June 30,
	2018		2017
Wages and employee benefits	$	7,444	$	6,171
Utilities and communication charges		2,123		2,102
Repairs and maintenance		2,205		2,415
Office, rentals and property taxes		3,010		2,559
Vehicles and fuel costs		195		138
Environmental compliance costs		923		730
Other		3,375		1,869
Direct operating costs and expenses	$	19,275	$	15,984

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The direct operating costs and expenses of our business segments were as follows (in thousands):

Direct Operating Costs and Expenses by Business Segment

	Three months ended June 30,
	2018		2017
Gulf Coast terminals	$	5,413	$	5,426
Midwest terminals and pipeline system		743		693
Brownsville terminals		2,135		2,582
River terminals		1,805		1,535
Southeast terminals		5,714		5,748
West Coast terminals		3,465		—
Direct operating costs and expenses	$	19,275	$	15,984

The decrease in direct operating costs and expenses at our Brownsville terminals is primarily attributable to terminating our lease of the Ella‑Brownsville pipeline from a third party on December 31, 2017 in connection with the expansion of our Brownville operations. The increase in direct operating costs and expenses at our West Coast terminals is a result of the West Coast terminals acquisition on December 15, 2017.

General and administrative expenses include fees paid to the owner of TransMontaigne GP under the omnibus agreement to cover the costs of centralized corporate functions such as legal, accounting, treasury, insurance administration and claims processing, health, safety and environmental, information technology, human resources, credit, payroll, taxes, engineering and other corporate services. General and administrative expenses also include direct general and administrative expenses for third party accounting costs associated with annual and quarterly reports and tax return and Schedule K‑1 preparation and distribution, legal fees and independent director fees. The general and administrative expenses were approximately $4.6 million and $4.1 million for the three months ended June 30, 2018 and 2017, respectively. The increase in general and administrative expenses is primarily attributable to the previously announced increases in the omnibus fee beginning as of May 13, 2018  and May 3, 2017.

Insurance expenses include charges for insurance premiums to cover costs of insuring activities such as property, casualty, pollution, automobile, directors’ and officers’ liability, and other insurable risks. For the three months ended June 30, 2018 and 2017, the expense associated with insurance was approximately $1.3 million and $1.0 million, respectively. 

Equity-based compensation expense includes expense associated with us reimbursing an affiliate of TransMontaigne GP for awards granted by them to certain key officers and employees who provide service to us that vest over future service periods and grants to the independent directors of our general partner under our long-term incentive plan. We have the intent and ability to settle our reimbursement for the bonus awards by issuing additional common units, and accordingly, we account for the bonus awards as an equity award. The expense associated with these reimbursements was approximately $0.4 million for both the three months ended June 30, 2018 and 2017. 

For the three months ended June 30, 2018 and 2017, depreciation and amortization expense was approximately $13.2 million and $8.8 million, respectively. The increase in depreciation and amortization expense is primarily attributable to the West Coast terminals acquisition on December 15, 2017 and placing into service new tank capacity at our Collins, Mississippi bulk storage terminal in various stages beginning in the fourth quarter of 2016 through the second quarter of 2017.

For the three months ended June 30, 2018 and 2017, interest expense was approximately $8.3 million and $2.5 million, respectively. The increase in interest expense is primarily attributable to financing the December 15, 2017 acquisition of the West Coast terminals, the issuance of senior notes and increases in LIBOR rates.

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ANALYSIS OF INVESTMENTS IN UNCONSOLIDATED AFFILIATES

Our investments in unconsolidated affiliates include a 42.5% Class A ownership interest in BOSTCO and a 50% ownership interest in Frontera. BOSTCO is a terminal facility located on the Houston Ship Channel that encompasses approximately 7.1 million barrels of distillate, residual and other black oil product storage. Class A and Class B ownership interests share in cash distributions on a 96.5% and 3.5% basis, respectively. Class B ownership interests do not have voting rights and are not required to make capital investments. Frontera is a terminal facility located in Brownsville, Texas that encompasses approximately 1.7 million barrels of light petroleum product storage, as well as related ancillary facilities.

Earnings from investments in unconsolidated affiliates were as follows (in thousands):

	Three months ended June 30,
	2018		2017
BOSTCO	$	1,848	$	1,275
Frontera		596		845
Total earnings from investments in unconsolidated affiliates	$	2,444	$	2,120

Additional capital investments in unconsolidated affiliates were as follows (in thousands):

	Three months ended June 30,
	2018		2017
BOSTCO	$	—	$	145
Frontera		114		—
Additional capital investments in unconsolidated affiliates	$	114	$	145

Cash distributions received from unconsolidated affiliates were as follows (in thousands):

	Three months ended June 30,
	2018		2017
BOSTCO	$	3,491	$	3,319
Frontera		1,330		1,227
Cash distributions received from unconsolidated affiliates	$	4,821	$	4,546

For the three months ended June 30, 2018, approximately $0.9 million of the cash distributions received relates to a return of prior year working capital contributions made to BOSTCO.

RESULTS OF OPERATIONS—SIX MONTHS ENDED JUNE 30, 2018 AND 2017

The following discussion and analysis of the results of operations and financial condition should be read in conjunction with the accompanying unaudited consolidated financial statements.

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ANALYSIS OF REVENUE

Total revenue.  We derive revenue from our terminal and pipeline transportation operations by charging fees for providing integrated terminaling, transportation and related services. Our total revenue by category was as follows (in thousands):

Total Revenue by Category

	Six months ended June 30,
	2018		2017
Terminaling services fees	$	105,569	$	82,250
Pipeline transportation fees		1,663		3,512
Management fees		4,556		4,452
Revenue	$	111,788	$	90,214

See discussion below for a detailed analysis of terminaling services fees, pipeline transportation fees and management fees included in the table above.

We operate our business and report our results of operations in six principal business segments: (i) Gulf Coast terminals, (ii) Midwest terminals and pipeline system, (iii) Brownsville terminals, (iv) River terminals, (v) Southeast terminals and (vi) West Coast terminals. The aggregate revenue of each of our business segments was as follows (in thousands):

Total Revenue by Business Segment

	Six months ended June 30,
	2018		2017
Gulf Coast terminals	$	32,821	$	32,086
Midwest terminals and pipeline system		5,690		5,734
Brownsville terminals		8,836		11,156
River terminals		5,343		5,410
Southeast terminals		40,126		35,828
West Coast terminals		18,972		—
Revenue	$	111,788	$	90,214

Total revenue by business segment is presented and further analyzed below by category of revenue.

Terminaling services fees.    Our terminaling services agreements are structured as either throughput agreements or storage agreements. Our throughput agreements contain provisions that require our customers to make minimum payments, which are based on contractually established minimum volume of throughput of the customer’s product at our facilities over a stipulated period of time. Due to this minimum payment arrangement, we recognize a fixed amount of revenue from the customer over a certain period of time, even if the customer throughputs less than the minimum volume of product during that period. In addition, if a customer throughputs a volume of product exceeding the minimum volume, we would recognize additional revenue on this incremental volume. Our storage agreements require our customers to make minimum payments based on the volume of storage capacity available to the customer under the agreement, which results in a fixed amount of recognized revenue.

We refer to the fixed amount of revenue recognized pursuant to our terminaling services agreements as being “firm commitments.” Revenue recognized in excess of firm commitments and revenue recognized based solely on the volume of product distributed or injected are referred to as “ancillary.” In addition “ancillary” revenue also includes fees received from ancillary services including heating and mixing of stored products, product transfer, railcar handling, butane blending, proceeds from the sale of product gains, wharfage and vapor recovery.

The terminaling services fees by business segments were as follows (in thousands):

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Terminaling Services Fees by Business Segment

		Six months ended June 30,
		2018		2017
Gulf Coast terminals	$	32,638	$	31,540
Midwest terminals and pipeline system		4,824		4,868
Brownsville terminals		4,043		4,972
River terminals		5,343		5,410
Southeast terminals		39,749		35,460
West Coast terminals		18,972		—
Terminaling services fees	$	105,569	$	82,250

The increase in terminaling services fees at our Southeast terminals includes an increase of approximately $3.0 million resulting from placing into service approximately 2.0 million barrels of new tank capacity at our Collins, Mississippi bulk storage terminal in various stages beginning in the fourth quarter of 2016 through the second quarter of 2017. The increase in terminaling services fees at our West Coast terminals is a result of the West Coast terminals acquisition on December 15, 2017.

Included in terminaling services fees for the six months ended June 30, 2018 and 2017 are fees charged to affiliates of approximately $5.5 million and $0.8 million, respectively.

The “firm commitments” and “ancillary” revenue included in terminaling services fees were as follows (in thousands):

Firm Commitments and Ancillary Revenue

	Six months ended June 30,
	2018		2017
Firm commitments	$	84,831	$	65,733
Ancillary		20,738		16,517
Terminaling services fees	$	105,569	$	82,250

The remaining terms on the terminaling services agreements that generated “firm commitments” for the six months ended June 30, 2018 are as follows (in thousands):

Less than 1 year remaining	$	22,074	26%
1 year or more, but less than 3 years remaining		23,106	27%
3 years or more, but less than 5 years remaining		35,470	42%
5 years or more remaining		4,181	5%
Total firm commitments for the six months ended June 30, 2018	$	84,831

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Pipeline transportation fees.    We earned pipeline transportation fees at our Diamondback pipeline either based on the volume of product transported or under capacity reservation agreements. Revenue associated with the capacity reservation is recognized ratably over the respective term, regardless of whether the capacity is actually utilized. We earn pipeline transportation fees at our Razorback pipeline based on an allocation of the aggregate fees charged under the capacity agreement with our customer who has contracted for 100% of our Razorback system. We own the Razorback and Diamondback pipelines, and we leased the Ella‑Brownsville pipeline from a third party through December 31, 2017. The pipeline transportation fees by business segments were as follows (in thousands):

Pipeline Transportation Fees by Business Segment

	Six months ended June 30,
	2018		2017
Gulf Coast terminals	$	—	$	—
Midwest terminals and pipeline system		866		866
Brownsville terminals		797		2,646
River terminals		—		—
Southeast terminals		—		—
West Coast terminals		—		—
Pipeline transportation fees	$	1,663	$	3,512

The decrease in pipeline transportation fees at our Brownsville terminals is attributable to suspending operations on the Diamondback pipeline in the first quarter of 2018 in connection with the expansion of our Brownville operations. We expect to recommission and resume operations on the Diamondback pipeline by the end of 2019.

Management fees.    We manage and operate certain tank capacity at our Port Everglades South terminal for a major oil company and receive a reimbursement of its proportionate share of operating and maintenance costs. We manage and operate the Frontera joint venture and receive a management fee based on our costs incurred. We also currently manage and operate for an affiliate of PEMEX, Mexico’s state-owned petroleum company, a bi-directional products pipeline connected to our Brownsville terminal facility and receive a management fee. We expect this operating arrangement to expire in the third quarter of 2018, after which it is anticipated that a third party will take operatorship of the pipeline. We manage and operate rail sites at certain Southeast terminals on behalf of a major oil company and receive reimbursement for operating and maintenance costs. The management fees by business segments were as follows (in thousands):

Management Fees by Business Segment

	Six months ended June 30,
	2018		2017
Gulf Coast terminals	$	183	$	546
Midwest terminals and pipeline system		—		—
Brownsville terminals		3,996		3,538
River terminals		—		—
Southeast terminals		377		368
West Coast terminals		—		—
Management fees	$	4,556	$	4,452

Included in management fees for the six months ended June 30, 2018 and 2017 are fees charged to affiliates of approximately $2.8 million and $2.5 million, respectively.

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ANALYSIS OF COSTS AND EXPENSES

The direct operating costs and expenses of our operations include the directly related wages and employee benefits, utilities, communications, repairs and maintenance, rent, property taxes, vehicle expenses, environmental compliance costs, materials and supplies. Consistent with historical trends across our terminaling and transportation facilities we anticipate an increase in repairs and maintenance expenses in the later months of the year as the weather becomes more conducive to these types of projects. The direct operating costs and expenses of our operations were as follows (in thousands):

Direct Operating Costs and Expenses

	Six months ended June 30,
	2018		2017
Wages and employee benefits	$	15,222	$	12,270
Utilities and communication charges		4,548		4,229
Repairs and maintenance		6,751		5,582
Office, rentals and property taxes		5,972		5,109
Vehicles and fuel costs		384		333
Environmental compliance costs		1,710		1,243
Other		4,833		3,729
Direct operating costs and expenses	$	39,420	$	32,495

The direct operating costs and expenses of our business segments were as follows (in thousands):

Direct Operating Costs and Expenses by Business Segment

	Six months ended June 30,
	2018		2017
Gulf Coast terminals	$	11,245	$	10,980
Midwest terminals and pipeline system		1,455		1,405
Brownsville terminals		4,176		5,454
River terminals		3,641		3,185
Southeast terminals		12,333		11,471
West Coast terminals		6,570		—
Direct operating costs and expenses	$	39,420	$	32,495

The decrease in direct operating costs and expenses at our Brownsville terminals is primarily attributable to terminating our lease of the Ella‑Brownsville pipeline from a third party on December 31, 2017 in connection with the expansion of our Brownville operations. The increase in direct operating costs and expenses at our Southeast terminals is primarily attributable to placing into service approximately 2.0 million barrels of new tank capacity at our Collins, MS bulk storage terminal in various stages beginning in the fourth quarter of 2016 through the second quarter of 2017. The increase in direct operating costs and expenses at our West Coast terminals is a result of the West Coast terminals acquisition on December 15, 2017.

General and administrative expenses include fees paid to the owner of TransMontaigne GP under the omnibus agreement to cover the costs of centralized corporate functions such as legal, accounting, treasury, insurance administration and claims processing, health, safety and environmental, information technology, human resources, credit, payroll, taxes, engineering and other corporate services. General and administrative expenses also include direct general and administrative expenses for third party accounting costs associated with annual and quarterly reports and tax return and Schedule K‑1 preparation and distribution, legal fees and independent director fees. The general and administrative expenses were approximately $9.6 million and $8.1 million for the six months ended June 30, 2018 and 2017, respectively. The increase in general and administrative expenses is primarily attributable to the previously announced increases in the omnibus fee beginning as of May 13, 2018 and May 3, 2017.

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Insurance expenses include charges for insurance premiums to cover costs of insuring activities such as property, casualty, pollution, automobile, directors’ and officers’ liability, and other insurable risks. For the six months ended June 30, 2018 and 2017, the expense associated with insurance was approximately $2.5 million and $2.0 million, respectively.

Equity-based compensation expense includes expense associated with us reimbursing an affiliate of TransMontaigne GP for awards granted by them to certain key officers and employees who provide service to us that vest over future service periods and grants to the independent directors of our general partner under our long-term incentive plan. We have the intent and ability to settle our reimbursement for the bonus awards by issuing additional common units, and accordingly, we account for the bonus awards as an equity award. The expense associated with these reimbursements was approximately $2.5 million and $2.2 million for the six months ended June 30, 2018 and 2017, respectively.

For the six months ended June 30, 2018 and 2017, depreciation and amortization expense was approximately $25.0 million and $17.5 million, respectively. The increase in depreciation and amortization expense is primarily attributable to the West Coast terminals acquisition on December 15, 2017 and placing into service new tank capacity at our Collins, Mississippi bulk storage terminal in various stages beginning in the fourth quarter of 2016 through the second quarter of 2017.

For the six months ended June 30, 2018 and 2017, interest expense was approximately $14.7 million and $4.7 million, respectively. The increase in interest expense is primarily attributable to financing the December 15, 2017 acquisition of the West Coast terminals, the issuance of senior notes and increases in LIBOR rates.

ANALYSIS OF INVESTMENTS IN UNCONSOLIDATED AFFILIATES

Our investments in unconsolidated affiliates include a 42.5% Class A ownership interest in BOSTCO and a 50% ownership interest in Frontera. BOSTCO is a terminal facility located on the Houston Ship Channel that encompasses approximately 7.1 million barrels of distillate, residual and other black oil product storage. Class A and Class B ownership interests share in cash distributions on a 96.5% and 3.5% basis, respectively. Class B ownership interests do not have voting rights and are not required to make capital investments. Frontera is a terminal facility located in Brownsville, Texas that encompasses approximately 1.7 million barrels of light petroleum product storage, as well as related ancillary facilities.

Earnings from investments in unconsolidated affiliates were as follows (in thousands):

	Six months ended June 30,
	2018		2017
BOSTCO	$	3,839	$	2,981
Frontera		1,494		1,699
Total earnings from investments in unconsolidated affiliates	$	5,333	$	4,680

Additional capital investments in unconsolidated affiliates were as follows (in thousands):

	Six months ended June 30,
	2018		2017
BOSTCO	$	—	$	145
Frontera		1,264		2,000
Additional capital investments in unconsolidated affiliates	$	1,264	$	2,145

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Cash distributions received from unconsolidated affiliates were as follows (in thousands):

	Six months ended June 30,
	2018		2017
BOSTCO	$	5,585	$	6,398
Frontera		2,426		2,497
Cash distributions received from unconsolidated affiliates	$	8,011	$	8,895

For the six months ended June 30, 2018, approximately $0.9 million of the cash distributions received relates to a return of prior year working capital contributions made to BOSTCO.

LIQUIDITY AND CAPITAL RESOURCES

Our primary liquidity needs are to fund our working capital requirements, distributions to unitholders, approved investments, approved capital projects and approved future expansion, development and acquisition opportunities. We expect to initially fund any investments, capital projects and future expansion, development and acquisition opportunities with undistributed cash flows from operations and additional borrowings under our revolving credit facility. After initially funding expenditures with borrowings under our revolving credit facility, we may raise funds through additional equity offerings and debt financings. The proceeds of such equity offerings and debt financings may then be used to reduce our outstanding borrowings under our revolving credit facility.

Net cash provided by (used in) operating activities, investing activities and financing activities were as follows (in thousands):

	Six months ended June 30,
	2018		2017
Net cash provided by operating activities	$	59,863	$	56,388
Net cash used in investing activities	$	(12,344)	$	(30,790)
Net cash used in financing activities	$	(48,052)	$	(24,226)

The increase in net cash provided by operating activities is primarily related to the timing of working capital requirements. 

The decrease in net cash used in investing activities is primarily related to the timing of construction spend and the receipt of approximately $10.0 million from the sale of assets in February 2018.  

Management and the board of directors of our general partner have approved additional investments and expansion capital projects at our terminals that currently are, or will be, under construction with estimated completion dates that extend through the second quarter of 2019. At June 30, 2018, the remaining expenditures to complete the approved projects are estimated to be approximately $100 million, assuming our Frontera joint venture does not exercise its rights of first refusal related to our Brownsville terminaling expansion efforts. These expenditures primarily relate to the construction costs associated with the approximately 870,000 barrels of new storage capacity and our share of improvements to the pipeline connections at our Collins bulk storage terminal and the expansion of the Brownsville terminal. 

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The increase in net cash used in financing activities includes a decrease of $17.1 million in net debt borrowings primarily related to the timing of construction spend and the receipt of approximately $10.0 million from the sale of assets in February 2018 and an increase of $4.0 million in distributions paid as a result of increasing our quarterly distributions. Net proceeds of the senior notes were primarily used to repay indebtedness under our revolving credit facility.

Third amended and restated senior secured credit facility.  On December 14, 2017 we amended our revolving credit facility, which increased the maximum borrowing line of credit to $850 million from $600 million, in connection with the acquisition of the West Coast terminals. At our request, the maximum borrowing line of credit may be increased by an additional $250 million, subject to the approval of the administrative agent and the receipt of additional commitments from one or more lenders. The terms of our revolving credit facility include covenants that restrict our ability to make cash distributions, acquisitions and investments, including investments in joint ventures. We may make distributions of cash to the extent of our “available cash” as defined in our partnership agreement. We may make acquisitions and investments that meet the definition of “permitted acquisitions”; “other investments” which may not exceed 5% of “consolidated net tangible assets”; and additional future “permitted JV investments” up to $175 million, which may include additional investments in BOSTCO. The principal balance of loans and any accrued and unpaid interest are due and payable in full on the maturity date, March 13, 2022.

We may elect to have loans under our revolving credit facility bear interest either (i) at a rate of LIBOR plus a margin ranging from 1.75% to 2.75% depending on the total leverage ratio then in effect, or (ii) at the base rate plus a margin ranging from 0.75% to 1.75% depending on the total leverage ratio then in effect. We also pay a commitment fee on the unused amount of commitments, ranging from 0.375% to 0.5% per annum, depending on the total leverage ratio then in effect. Our obligations under our revolving credit facility are secured by a first priority security interest in favor of the lenders in the majority of our assets, including our investments in unconsolidated affiliates. At June 30, 2018, our outstanding borrowings under our revolving credit facility were $286.3 million.

Our revolving credit facility also contains customary representations and warranties (including those relating to organization and authorization, compliance with laws, absence of defaults, material agreements and litigation) and customary events of default (including those relating to monetary defaults, covenant defaults, cross defaults and bankruptcy events). The primary financial covenants contained in our revolving credit facility are (i) a total leverage ratio test (not to exceed 5.25 to 1.0), (ii) a senior secured leverage ratio test (not to exceed 3.75 to 1.0), and (iii) a minimum interest coverage ratio test (not less than 2.75 to 1.0). These financial covenants are based on a non-GAAP, defined financial performance measure within our revolving credit facility known as “Consolidated EBITDA.” We were in compliance with all financial covenants as of and during the six months ended June 30, 2018 and the year ended December 31, 2017.   

If we were to fail either financial performance covenant, or any other covenant contained in our revolving credit facility, we would seek a waiver from our lenders under such facility. If we were unable to obtain a waiver from our lenders and the default remained uncured after any applicable grace period, we would be in breach of our revolving credit facility, and the lenders would be entitled to declare all outstanding borrowings immediately due and payable.

Senior notes.  On February 12, 2018, the Partnership and our wholly owned subsidiary, TLP Finance Corp., completed the sale of $300 million of 6.125% senior notes, issued at par and due 2026. The senior notes were guaranteed on a senior unsecured basis by each of our 100% owned domestic subsidiaries that guarantee obligations under our revolving credit facility. Net proceeds were used to repay indebtedness under our revolving credit facility. 

The senior notes will mature on February 15, 2026.  Interest on the senior notes is payable semi-annually in arrears on February 15 and August 15 of each year, beginning on August 15, 2018. The senior notes are fully and unconditionally guaranteed, jointly and severally, on a senior unsecured basis by each of our 100% owned domestic subsidiaries in each case that guarantee obligations under our revolving credit facility.  The senior notes and the associated guarantees rank equally in right of payment with all of our existing and future unsecured senior indebtedness and senior to all of the Partnership’s future subordinated indebtedness.  The senior notes and the guarantees are effectively subordinated in right of payment to all of the Partnership’s existing and future secured debt, including debt under our revolving credit facility, to the extent of the value of the assets securing such debt, and are structurally subordinated to all liabilities of our subsidiaries (other than TLP Finance Corp.) that do not guarantee the senior notes.

45

At any time prior to February 15, 2021, we may on any one or more occasions redeem up to 35% of the aggregate principal amount of the senior notes at a redemption price of 106.125% of the principal amount of the senior notes, plus accrued and unpaid interest, if any, to, but not including, the redemption date, with the net cash proceeds of certain equity offerings. On and after February 15, 2021, we may redeem all or a part of the senior notes at redemption prices (expressed as percentages of principal amount) equal to (i) 104.594% for the twelve-month period beginning on February 15, 2021; (ii) 103.063% for the twelve-month period beginning on February 15, 2022; (iii) 101.531% for the twelve month-period beginning on February 15, 2023; and (iv) 100.000% for the twelve-month period beginning on February 15, 2024 and at any time thereafter, plus accrued and unpaid interest.

Common unit offeringprogram. On September 2, 2016, the Securities and Exchange Commission declared effective a universal shelf registration statement, which replaced our prior shelf registration statement that previously expired. As with the prior shelf registration statement, the new shelf registration statement allows us to issue common units and debt securities. In connection with the shelf registration statement, we established a common unit offering program under which we may issue and sell common units from time to time, representing limited partner interests, up to an aggregate gross sales amount of $50 million. We intend to use the net proceeds from any equity sales pursuant to the common unit offering program, after deducting the agent’s commissions and the partnership’s offering expenses, for general partnership purposes, which may include, among other things, repayment of indebtedness, capital expenditures, working capital or acquisitions. In February 2018, we used the shelf registration statement to issue the senior notes (see Note 12 of Notes to consolidated financial statements).

ITEM 3.  QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The information contained in this Item 3 updates, and should be read in conjunction with, information set forth in Part II, Item 7A of our Annual Report on Form 10‑K, filed on March 15, 2018, in addition to the interim unaudited consolidated financial statements, accompanying notes and Management’s Discussion and Analysis of Financial Condition and Results of Operations presented in Part 1, Items 1 and 2 of this Quarterly Report on Form 10‑Q. There are no material changes in the market risks faced by us from those reported in our Annual Report on Form 10‑K for the year ended December 31, 2017.

Market risk is the risk of loss arising from adverse changes in market rates and prices. A principal market risk to which we are exposed is interest rate risk associated with borrowings under our revolving credit facility. Borrowings under our revolving credit facility bear interest at a variable rate based on LIBOR or the lender’s base rate. We manage a portion of our interest rate risk with interest rate swaps, which reduce our exposure to changes in interest rates by converting variable interest rates to fixed interest rates. At June 30, 2018, we are party to an interest rate swap agreement with a notional amount of $50.0 million that expires March 11, 2019. Pursuant to the terms of the interest rate swap agreement, we pay a fixed rate of approximately 0.97% and receive interest payments based on the one-month LIBOR. The net difference to be paid or received under the interest rate swap agreement is settled monthly and is recognized as an adjustment to interest expense. At June 30, 2018, we had outstanding borrowings of $286.3 million under our revolving credit facility. Based on the outstanding balance of our variable‑interest‑rate debt at June 30, 2018, the terms of our interest rate swap agreement and assuming market interest rates increase or decrease by 100 basis points, the potential annual increase or decrease in interest expense is approximately $2.4 million.

We do not purchase or market products that we handle or transport and, therefore, we do not have material direct exposure to changes in commodity prices, except for the value of product gains arising from certain of our terminaling services agreements with our customers. We do not use derivative commodity instruments to manage the commodity risk associated with the product we may own at any given time. Generally, to the extent we are entitled to retain product pursuant to terminaling services agreements with our customers, we sell the product to our customers on a contractually established periodic basis; the sales price is based on industry indices.

ITEM 4.  CONTROLS AND PROCEDURES

We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed by us in the reports that we file or submit to the Securities and Exchange Commission under the Securities Exchange Act of 1934, as amended, is recorded, processed, summarized and reported within the time periods specified by the Commission’s rules and forms, and that information is accumulated and communicated to the management of our general partner, including our general partner’s principal executive and principal financial officer (whom we refer to as

46

the Certifying Officers), as appropriate to allow timely decisions regarding required disclosure. The management of our general partner evaluated, with the participation of the Certifying Officers, the effectiveness of our disclosure controls and procedures as of June 30, 2018, pursuant to Rule 13a‑15(b) under the Exchange Act. Based upon that evaluation, the Certifying Officers concluded that, as of June 30, 2018, our disclosure controls and procedures were effective. There were no changes in our internal control over financial reporting that occurred during our most recently completed fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Part II. Other Information

ITEM 1.  LEGAL PROCEEDINGS

See Part I, Item 1 Note 16 to our consolidated financial statements entitled “Legal proceedings” which is incorporated into this item by reference.  

ITEM 1A.  RISK FACTORS

In addition to the other information set forth in this report, you should carefully consider the risk factors and other cautionary statements described under the heading “Item 1A. Risk Factors” included in our 2017 Annual Report on Form 10-K filed on March 15, 2018, which could materially affect our businesses, financial condition, or future results. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition, or future results.

There have been no material changes from risk factors as previously disclosed in our Annual Report on Form 10‑K for the year ended December 31, 2017, filed on March 15, 2018.

47

ITEM 6.  EXHIBITS

The exhibits listed on the accompanying Exhibit Index are filed or incorporated by reference as part of this report, and such Exhibit Index is incorporated herein by reference.

48

Exhibit number	EXHIBIT INDEX Description of exhibits
31.1	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes‑Oxley Act of 2002.
31.2	Certification 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.
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.
101	The following financial information from the Quarterly Report on Form 10‑Q of TransMontaigne Partners L.P. and subsidiaries for the quarter ended June 30, 2018, formatted in XBRL (eXtensible Business Reporting Language): (i) consolidated balance sheets, (ii) consolidated statements of operations, (iii) consolidated statements of partners’ equity, (iv) consolidated statements of cash flows and (v) notes to consolidated financial statements.

49

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.

		Chief Executive Officer
Date: August  9, 2018	TransMontaigne Partners L.P. (Registrant)
	TransMontaigne GP L.L.C., its General Partner
	By:	/s/ Frederick W. Boutin Frederick W. Boutin Chief Executive Officer
	By:	/s/ Robert T. Fuller Robert T. Fuller Chief Financial Officer

50

EX-31.1

Exhibit 31.1

Certification Pursuant to

Section 302 of the Sarbanes‑Oxley Act of 2002

I, Frederick W. Boutin, Chief Executive Officer of TransMontaigne GP L.L.C., a Delaware limited liability company and general partner of TransMontaigne Partners L.P. (the “Company”), certify that:

1. I have reviewed this Quarterly Report on Form 10‑Q of TransMontaigne Partners L.P. for the fiscal quarter ended June 30, 2018;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a‑15(e) and 15d‑15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a‑15(f) and 15d‑15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August  9, 2018

Chief Executive Officer

/s/ Frederick W. Boutin

Frederick W. Boutin
Chief Executive Officer

EX-31.2

Exhibit 31.2

Certification Pursuant to

Section 302 of the Sarbanes‑Oxley Act of 2002

I, Robert T. Fuller, Chief Financial Officer of TransMontaigne GP L.L.C., a Delaware limited liability company and general partner of TransMontaigne Partners L.P. (the “Company”), certify that:

1. I have reviewed this Quarterly Report on Form 10‑Q of TransMontaigne Partners L.P. for the fiscal quarter ended June 30, 2018;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a‑15(e) and 15d‑15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a‑15(f) and 15d‑15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 9, 2018

Chief Financial Officer

/s/ Robert T. Fuller

Robert T. Fuller
Chief Financial Officer

EX-32.1

Exhibit 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

(18 U.S.C. Section 1350)

The undersigned, the Chief Executive Officer of TransMontaigne GP L.L.C., a Delaware limited liability company and general partner of TransMontaigne Partners L.P. (the “Company”), hereby certifies that, to his knowledge on the date hereof:

(a) the Quarterly Report on Form 10‑Q of the Company for the fiscal quarter ended June 30, 2018, filed on the date hereof with the Securities and Exchange Commission (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(b) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Chief Executive Officer
May 6, 2014

/s/ Frederick W. Boutin

Frederick W. Boutin
Chief Executive Officer
August  9, 2018

EX-32.2

Exhibit 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

(18 U.S.C. Section 1350)

The undersigned, the Chief Financial Officer of TransMontaigne GP L.L.C., a Delaware limited liability company and general partner of TransMontaigne Partners L.P. (the “Company”), hereby certifies that, to his knowledge on the date hereof:

(a) the Quarterly Report on Form 10‑Q of the Company for the fiscal quarter ended June 30, 2018, filed on the date hereof with the Securities and Exchange Commission (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(b) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Chief Financial Officer
May 6, 2014

/s/ Robert T. Fuller

Robert T. Fuller
Chief Financial Officer
August  9, 2018

XML

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2018	Jul. 31, 2018
Document and Entity Information
Entity Registrant Name	TransMontaigne Partners L.P.
Entity Central Index Key	0001319229
Document Type	10-Q
Document Period End Date	Jun. 30, 2018
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		16,222,151
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q2

XML

Consolidated balance sheets - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 390	$ 923
Trade accounts receivable, net	12,164	11,017
Due from affiliates	3,491	1,509
Other current assets	7,978	20,654
Total current assets	24,023	34,103
Property, plant and equipment, net	656,761	655,053
Goodwill	9,428	9,428
Investments in unconsolidated affiliates	231,767	233,181
Other assets, net	52,843	55,238
TOTAL ASSETS	974,822	987,003
Current liabilities:
Trade accounts payable	11,058	8,527
Accrued liabilities	26,676	17,426
Total current liabilities	37,734	25,953
Other liabilities	3,537	3,633
Long-term debt	578,523	593,200
Total liabilities	619,794	622,786
Commitments and contingencies (Note 16)
Partners’ equity:
Common unitholders (16,222,151 units issued and outstanding at June 30, 2018 and 16,177,353 units issued and outstanding at December 31, 2017)	301,372	310,769
General partner interest (2% interest with 331,055 equivalent units outstanding at June 30, 2018 and 330,150 equivalent units outstanding at December 31, 2017)	53,656	53,448
Total partners’ equity	355,028	364,217
TOTAL LIABILITIES AND EQUITY	$ 974,822	$ 987,003

XML

Consolidated balance sheets (Parenthetical) - shares	6 Months Ended	12 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Consolidated balance sheets
Common unitholders, units issued	16,222,151	16,177,353
Common unitholders, units outstanding	16,222,151	16,177,353
General partner interest (as a percent)	2.00%	2.00%
General partner interest, equivalent units outstanding	331,055	330,150

XML

Consolidated statements of operations - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Revenue:
Total revenue	$ 55,344	$ 45,364	$ 111,788	$ 90,214
Operating costs and expenses
Direct operating costs and expenses	(19,275)	(15,984)	(39,420)	(32,495)
General and administrative expenses	(4,619)	(4,080)	(9,600)	(8,051)
Insurance expenses	(1,271)	(1,002)	(2,517)	(2,008)
Equity-based compensation expense	(441)	(352)	(2,458)	(2,169)
Depreciation and amortization	(13,160)	(8,792)	(24,968)	(17,497)
Total operating costs and expenses	(38,766)	(30,210)	(78,963)	(62,220)
Earnings from unconsolidated affiliates	2,444	2,120	5,333	4,680
Operating income	19,022	17,274	38,158	32,674
Other expenses:
Interest expense	(8,273)	(2,525)	(14,734)	(4,677)
Amortization of deferred financing costs	(1,289)	(271)	(1,790)	(565)
Total other expenses	(9,562)	(2,796)	(16,524)	(5,242)
Net earnings	9,460	14,478	21,634	27,432
Less-earnings allocable to general partner interest including incentive distribution rights	(3,872)	(3,105)	(7,638)	(5,948)
Net earnings allocable to limited partners	$ 5,588	$ 11,373	$ 13,996	$ 21,484
Net earnings per limited partner unit-basic (in dollars per unit)	$ 0.34	$ 0.70	$ 0.86	$ 1.32
Net earnings per limited partner unit-diluted (in dollars per unit)	$ 0.34	$ 0.70	$ 0.86	$ 1.32
External customers (excluding affiliates)
Revenue:
Total revenue	$ 51,379	$ 43,850	$ 103,493	$ 86,930
Affiliates
Revenue:
Total revenue	$ 3,965	$ 1,514	$ 8,295	$ 3,284

XML

Consolidated statements of partners' equity - USD ($) $ in Thousands	Common units	General partner interest	Total
Balance at Dec. 31, 2016	$ 320,042	$ 52,692	$ 372,734
Increase (Decrease) in Partners' Capital
Distributions to unitholders	(47,349)	(11,985)	(59,334)
Equity-based compensation	2,729		2,729
Issuance of common units pursuant to our long-term incentive plan	270		270
Settlement of tax withholdings on equity-based compensation	(711)		(711)
Contribution of cash by TransMontaigne GP to maintain its 2% general partner interest		36	36
Net earnings	35,788	12,705	48,493
Balance at Dec. 31, 2017	310,769	53,448	364,217
Increase (Decrease) in Partners' Capital
Distributions to unitholders	(25,193)	(7,464)	(32,657)
Equity-based compensation	2,458		2,458
Settlement of tax withholdings on equity-based compensation	(658)		(658)
Contribution of cash by TransMontaigne GP to maintain its 2% general partner interest		34	34
Net earnings	13,996	7,638	21,634
Balance at Jun. 30, 2018	$ 301,372	$ 53,656	$ 355,028

XML

Consolidated statements of partners' equity (Parenthetical)	6 Months Ended
	Jun. 30, 2018 shares
General partner interest (as a percent)	2.00%
Tranche One
Issuance of common units pursuant to our savings and retention program (in units)	44,798

XML

Consolidated statements of cash flows - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Cash flows from operating activities:
Net earnings	$ 9,460	$ 14,478	$ 21,634	$ 27,432
Adjustments to reconcile net earnings to net cash provided by operating activities:
Depreciation and amortization	13,160	8,792	24,968	17,497
Earnings from unconsolidated affiliates	(2,444)	(2,120)	(5,333)	(4,680)
Distributions from unconsolidated affiliates	3,971	4,546	7,161	8,895
Equity-based compensation	441	352	2,458	2,169
Amortization of deferred financing costs	1,289	271	1,790	565
Amortization of deferred revenue	(149)	10	(336)	(41)
Unrealized (gain) loss on derivative instruments	85	38	127	(220)
Changes in operating assets and liabilities, net of effects from acquisitions and dispositions:
Trade accounts receivable, net	(1,092)	(79)	(1,090)	141
Due from affiliates	312	(446)	(1,982)	(756)
Other current assets	3,620	1,043	1,821	2,759
Amounts due under long-term terminaling services agreements, net	176	(227)	204	(325)
Deposits				54
Trade accounts payable	(2,383)	(433)	(809)	431
Accrued liabilities	9,023	(200)	9,250	2,467
Net cash provided by operating activities	35,469	26,025	59,863	56,388
Cash flows from investing activities:
Investments in unconsolidated affiliates	(114)	(145)	(1,264)	(2,145)
Return of investment in unconsolidated affiliates	850		850
Capital expenditures	(15,452)	(19,145)	(21,955)	(28,645)
Proceeds from sale of assets			10,025
Net cash used in investing activities	(14,716)	(19,290)	(12,344)	(30,790)
Cash flows from financing activities:
Proceeds from senior notes			300,000
Borrowings under revolving credit facility	38,900	41,100	85,500	87,100
Repayments under revolving credit facility	(42,800)	(31,600)	(392,400)	(76,900)
Deferred issuance costs	(505)	(296)	(7,871)	(5,364)
Settlement of tax withholdings on equity-based compensation	(317)	(25)	(658)	(407)
Distributions paid to unitholders	(16,594)	(14,590)	(32,657)	(28,677)
Contribution of cash by TransMontaigne GP	16		34	22
Net cash used in financing activities	(21,300)	(5,411)	(48,052)	(24,226)
Increase (decrease) in cash and cash equivalents	(547)	1,324	(533)	1,372
Cash and cash equivalents at beginning of period	937	641	923	593
Cash and cash equivalents at end of period	390	1,965	390	1,965
Supplemental disclosures of cash flow information:
Cash paid for interest	3,265	2,374	7,631	4,591
Property, plant and equipment acquired with accounts payable	$ 6,546	$ 2,992	$ 6,546	$ 2,992

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Jun. 30, 2018

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

(a) Nature of business

TransMontaigne Partners L.P. (“we,” “us,” “our,” “the Partnership”) was formed in February 2005 as a Delaware limited partnership. We provide integrated terminaling, storage, transportation and related services for companies engaged in the trading, distribution and marketing of light refined petroleum products, heavy refined petroleum products, crude oil, chemicals, fertilizers and other liquid products. We conduct our operations in the United States along the Gulf Coast, in the Midwest, in Houston and Brownsville, Texas, along the Mississippi and Ohio rivers, in the Southeast and along the West Coast.

We are controlled by our general partner, TransMontaigne GP L.L.C. (“TransMontaigne GP”), which as of February 1, 2016 is a wholly‑owned indirect subsidiary of ArcLight Energy Partners Fund VI, L.P. (“ArcLight”). 

 (b) Basis of presentation and use of estimates

Our accounting and financial reporting policies conform to accounting principles generally accepted in the United States of America (“GAAP”). The accompanying consolidated financial statements include the accounts of TransMontaigne Partners L.P. and its controlled subsidiaries. Investments where we do not have the ability to exercise control, but do have the ability to exercise significant influence, are accounted for using the equity method of accounting. All inter‑company accounts and transactions have been eliminated in the preparation of the accompanying consolidated financial statements. The accompanying consolidated financial statements include all adjustments (consisting of normal and recurring accruals) considered necessary to present fairly our financial position as of June 30, 2018 and December 31, 2017 and our results of operations for the three and six months ended June 30, 2018 and 2017.Certain reclassifications of previously reported amounts have been made to conform to the current year presentation.

The preparation of financial statements in conformity with “GAAP” requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenue and expenses during the reporting periods. The following estimates, in management’s opinion, are subjective in nature, require the exercise of judgment, and/or involve complex analyses: business combination estimates and assumptions, useful lives of our plant and equipment and accrued environmental obligations. Changes in these estimates and assumptions will occur as a result of the passage of time and the occurrence of future events. Actual results could differ from these estimates.

(c) Accounting for terminal and pipeline operations

Effective January 1, 2018, we adopted Accounting Standards Codification (“ASC”) Topic 606, Revenue from Contracts with Customers (“ASC 606”), applying the modified retrospective transition method, which required us to apply the new standard to (i) all new revenue contracts entered into after January 1, 2018, and (ii) revenue contracts which were not completed as of January 1, 2018. ASC 606 replaces existing revenue recognition requirements in GAAP and requires entities to recognize revenue at an amount that reflects the consideration to which we expect to be entitled in exchange for transferring goods or services to a customer. ASC 606 also requires certain disclosures regarding qualitative and quantitative information regarding the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The adoption of ASC 606 did not result in a transition adjustment nor did it have an impact on the timing or amount of our revenue recognition (See Note 18 of Notes to consolidated financial statements).

The adoption of ASC 606 did not result in changes to our accounting for trade accounts receivable (see Note 4 of Notes to consolidated financial statements), contract assets or contract liabilities. We recognize contract assets in situations where revenue recognition under ASC 606 occurs prior to billing the customer based on our rights under the contract. Contract assets are transferred to accounts receivable when the rights become unconditional. At June 30, 2018, we did not have any contract assets related to ASC 606.

Contract liabilities primarily relate to consideration received from customers in advance of completing the performance obligation. A performance obligation is a promise in a contract to transfer goods or services to the customer. We recognize contract liabilities under these arrangements as revenue once all contingencies or potential performance obligations have been satisfied by the (i) performance of services or (ii) expiration of the customer’s rights under the contract. Short-term contract liabilities include customer advances and deposits (see Note 10 of Notes to consolidated financial statements). Long-term contract liabilities include deferred revenue related to ethanol blending fees and other projects (See Note 11 of Notes to consolidated financial statements).

We generate revenue from terminaling services fees, pipeline transportation fees and management fees. Under ASC 606, we recognize revenue over time or at a point in time, depending on the nature of the performance obligations contained in the respective contract with our customer. The contract transaction price is allocated to each performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. The majority of our revenue is recognized pursuant to ASC guidance other than ASC 606. The following is an overview of our significant revenue streams, including a description of the respective performance obligations and related method of revenue recognition. 

Terminaling services fees. Our terminaling services agreements are structured as either throughput agreements or storage agreements. Our throughput agreements contain provisions that require our customers to make minimum payments, which are based on contractually established minimum volumes of throughput of the customer’s product at our facilities, over a stipulated period of time. Due to this minimum payment arrangement, we recognize a fixed amount of revenue from the customer over a certain period of time, even if the customer throughputs less than the minimum volume of product during that period. In addition, if a customer throughputs a volume of product exceeding the minimum volume, we would recognize additional revenue on this incremental volume. Our storage agreements require our customers to make minimum payments based on the volume of storage capacity available to the customer under the agreement, which results in a fixed amount of recognized revenue. We refer to the fixed amount of revenue recognized pursuant to our terminaling services agreements as being “firm commitments.” The majority of our firm commitments under our terminaling services agreements are accounted for in accordance with ASC 840, Leases (“ASC 840 revenue”). The remainder is recognized in accordance with ASC 606 (“ASC 606 revenue”) where the minimum payment arrangement in each contract is a single performance obligation that is primarily satisfied over time through the contract term. 

Revenue recognized in excess of firm commitments and revenue recognized based solely on the volume of product distributed or injected are referred to as ancillary. The ancillary revenue associated with terminaling services include volumes of product throughput that exceed the contractually established minimum volumes,  injection fees based on the volume of product injected with additive compounds, heating and mixing of stored products, product transfer, railcar handling, butane blending, proceeds from the sale of product gains, wharfage and vapor recovery. The revenue generated by these services is primarily considered optional purchases to acquire additional services or variable consideration that is required to be estimated under ASC 606 for any uncertainty that is not resolved in the period of the service. We account for the majority of ancillary revenue at individual points in time when the services are delivered to the customer. Our ancillary revenue is recognized in accordance with ASC 606.

Pipeline transportation fees. We earn pipeline transportation fees at our Diamondback pipeline either based on the volume of product transported or under capacity reservation agreements. Revenue associated with the capacity reservation is recognized ratably over the respective term, regardless of whether the capacity is actually utilized. We earn pipeline transportation fees at our Razorback pipeline based on an allocation of the aggregate fees charged under the capacity agreement with our customer who has contracted for 100% of our Razorback system. For the six months ended June 30, 2018, pipeline transportation revenue is primarily accounted for in accordance with ASC 840.

Management fees. We manage and operate certain tank capacity at our Port Everglades South terminal for a major oil company and receive a reimbursement of its proportionate share of operating and maintenance costs. We manage and operate the Frontera joint venture and receive a management fee based on our costs incurred. We also currently manage and operate for an affiliate of PEMEX, Mexico’s state-owned petroleum company, a bi-directional products pipeline connected to our Brownsville terminal facility and receive a management fee. We manage and operate rail sites at certain Southeast terminals on behalf of a major oil company and receive reimbursement for operating and maintenance costs. Management fee revenue is recognized at individual points in time as the services are performed or as the costs are incurred and is primarily accounted for in accordance with ASC 606. 

 (d) Cash and cash equivalents

We consider all short‑term investments with a remaining maturity of three months or less at the date of purchase to be cash equivalents.

(e) Property, plant and equipment

Depreciation is computed using the straight‑line method. Estimated useful lives are 15 to 25 years for terminals and pipelines and 3 to 25 years for furniture, fixtures and equipment. All items of property, plant and equipment are carried at cost. Expenditures that increase capacity or extend useful lives are capitalized. Repairs and maintenance are expensed as incurred.

We evaluate long‑lived assets for impairment whenever events or changes in circumstances indicate that the carrying value of an asset group may not be recoverable based on expected undiscounted future cash flows attributable to that asset group. If an asset group is impaired, the impairment loss to be recognized is the excess of the carrying amount of the asset group over its estimated fair value.

(f) Investments in unconsolidated affiliates

We account for our investments in unconsolidated affiliates, which we do not control but do have the ability to exercise significant influence over, using the equity method of accounting. Under this method, the investment is recorded at acquisition cost, increased by our proportionate share of any earnings and additional capital contributions and decreased by our proportionate share of any losses, distributions received and amortization of any excess investment. Excess investment is the amount by which our total investment exceeds our proportionate share of the book value of the net assets of the investment entity. We evaluate our investments in unconsolidated affiliates for impairment whenever events or circumstances indicate there is a loss in value of the investment that is other than temporary. In the event of impairment, we would record a charge to earnings to adjust the carrying amount to estimated fair value.

(g) Environmental obligations

We accrue for environmental costs that relate to existing conditions caused by past operations when probable and reasonably estimable (see Note 10 of Notes to consolidated financial statements). Environmental costs include initial site surveys and environmental studies of potentially contaminated sites, costs for remediation and restoration of sites determined to be contaminated and ongoing monitoring costs, as well as fines, damages and other costs, including direct legal costs. Liabilities for environmental costs at a specific site are initially recorded, on an undiscounted basis, when it is probable that we will be liable for such costs, and a reasonable estimate of the associated costs can be made based on available information. Such an estimate includes our share of the liability for each specific site and the sharing of the amounts related to each site that will not be paid by other potentially responsible parties, based on enacted laws and adopted regulations and policies. Adjustments to initial estimates are recorded, from time to time, to reflect changing circumstances and estimates based upon additional information developed in subsequent periods. Estimates of our ultimate liabilities associated with environmental costs are difficult to make with certainty due to the number of variables involved, including the early stage of investigation at certain sites, the lengthy time frames required to complete remediation, technology changes, alternatives available and the evolving nature of environmental laws and regulations. We periodically file claims for insurance recoveries of certain environmental remediation costs with our insurance carriers under our comprehensive liability policies (see Note 5 of Notes to consolidated financial statements).

We recognize our insurance recoveries as a credit to income in the period that we assess the likelihood of recovery as being probable.

In connection with our previous acquisitions of certain terminals from TransMontaigne LLC, a wholly owned subsidiary of NGL Energy Partners LP and the previous owner of our general partner, TransMontaigne LLC agreed to indemnify us against certain potential environmental claims, losses and expenses at those terminals. Pursuant to the acquisition agreements for each of the Florida (except Pensacola) and Midwest terminals, the Southeast terminals, the Brownsville and the River terminals, and the Pensacola, Florida Terminal, TransMontaigne LLC is obligated to indemnify us against environmental claims, losses and expenses that were associated with the ownership or operation of the terminals prior to the purchase by the Partnership. In each acquisition agreement, TransMontaigne LLC’s maximum indemnification liability is subject to a specified time period for indemnification, cap on indemnification and satisfaction of a deductible amount before indemnification, in each case subject to certain exceptions, limitations and conditions specified therein. TransMontaigne LLC has no indemnification obligations with respect to environmental claims made as a result of additions to or modifications of environmental laws promulgated after certain specified dates.

The environmental indemnification obligations of TransMontaigne LLC to us remain in place and were not affected by ArcLight’s acquisition of our general partner on February 1, 2016.  

(h) Asset retirement obligations

Asset retirement obligations are legal obligations associated with the retirement of long‑lived assets that result from the acquisition, construction, development or normal use of the asset. Generally accepted accounting principles require that the fair value of a liability related to the retirement of long‑lived assets be recorded at the time a legal obligation is incurred. Once an asset retirement obligation is identified and a liability is recorded, a corresponding asset is recorded, which is depreciated over the remaining useful life of the asset. After the initial measurement, the liability is adjusted to reflect changes in the asset retirement obligation. If and when it is determined that a legal obligation has been incurred, the fair value of any liability is determined based on estimates and assumptions related to retirement costs, future inflation rates and interest rates. Our long‑lived assets consist of above‑ground storage facilities and underground pipelines. We are unable to predict if and when these long‑lived assets will become completely obsolete and require dismantlement. We have not recorded an asset retirement obligation, or corresponding asset, because the future dismantlement and removal dates of our long‑lived assets is indeterminable and the amount of any associated costs are believed to be insignificant. Changes in our assumptions and estimates may occur as a result of the passage of time and the occurrence of future events.

(i) Equity-based compensation

Generally accepted accounting principles require us to measure the cost of services received in exchange for an award of equity instruments based on the measurement‑date fair value of the award. That cost is recognized during the period services are provided in exchange for the award (see Note 14 of Notes to consolidated financial statements).

(j) Accounting for derivative instruments

Generally accepted accounting principles require us to recognize all derivative instruments at fair value in the consolidated balance sheets as assets or liabilities (see Notes 5 and 9 of Notes to consolidated financial statements). Changes in the fair value of our derivative instruments are recognized in earnings.

At June 30, 2018 and December 31, 2017, our derivative instruments were limited to interest rate swap agreements with an aggregate notional amount of $50.0 million and $125.0 million, respectively. At June 30, 2018 the remaining derivative instrument expires March 11, 2019. Pursuant to the terms of the interest rate swap agreements, we paid a blended fixed rate of approximately 0.97% and 1.01% for the six months ended June 30, 2018 and the year ended December 31, 2017, respectively, and received interest payments based on the one-month LIBOR. The net difference to be paid or received under the interest rate swap agreements is settled monthly and is recognized as an adjustment to interest expense. The fair value of our interest rate swap agreements are determined using a pricing model based on the LIBOR swap rate and other observable market data.

(k) Income taxes

No provision for U.S. federal income taxes has been reflected in the accompanying consolidated financial statements because we are treated as a partnership for federal income tax purposes. As a partnership, all income, gains, losses, expenses, deductions and tax credits generated by us flow through to our unitholders.

(l) Net earnings per limited partner unit

Net earnings allocable to the limited partners, for purposes of calculating net earnings per limited partner unit, are calculated under the two-class method and accordingly are net of the earnings allocable to the general partner interest and distributions payable to any restricted phantom units granted under our equity-based compensation plans that participate in our distributions. The earnings allocable to the general partner interest include the distributions of available cash (as defined by our partnership agreement) attributable to the period to the general partner interest, net of adjustments for the general partner’s share of undistributed earnings, and the incentive distribution rights. Undistributed earnings are the difference between the earnings and the distributions attributable to the period. Undistributed earnings are allocated to the limited partners and general partner interest based on their respective sharing of earnings or losses specified in the partnership agreement, which is based on their ownership percentages of 98% and 2%, respectively. The incentive distribution rights are not allocated a portion of the undistributed earnings given they are not entitled to distributions other than from available cash. Further, the incentive distribution rights do not share in losses under our partnership agreement. Basic net earnings per limited partner unit is computed by dividing net earnings allocable to the limited partners by the weighted average number of limited partner units outstanding during the period. Diluted net earnings per limited partner unit is computed by dividing net earnings allocable to the limited partners by the weighted average number of limited partner units outstanding during the period and any potential dilutive securities outstanding during the period.

(m)   Comprehensive income

Entities that report items of other comprehensive income have the option to present the components of net earnings and comprehensive income in either one continuous financial statement, or two consecutive financial statements. As the Partnership has no components of comprehensive income other than net earnings, no statement of comprehensive income has been presented.

 (n) Recent accounting pronouncements

Effective January 1, 2018 we adopted ASU 2016-15, Statement of Cash Flows: Classification of Certain Cash Receipt and Cash Payments. This ASU requires changes in the presentation of certain items, including but not limited to debt prepayment or debt extinguishment costs; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance policies and distributions received from equity method investees. The adoption of this ASU did not have a material impact on our unaudited consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02, Leases. The objective of this update is to improve financial reporting about leasing transactions. ASU 2016-02 is effective for annual reporting periods beginning after December 15, 2018, including interim periods within that reporting period. We are currently evaluating the potential impact that the adoption will have on our disclosures and financial statements. Additionally, we are in the process of evaluating and designing the necessary changes to our business processes and controls to support recognition and disclosure under the new standard. As part of our evaluation process we have established an implementation team and are in the process of implementing a third-party supported lease accounting system to facilitate the accounting and financial reporting requirements.

In January 2017, the FASB issued ASU 2017-04, Intangibles-Goodwill and Other: Simplifying the Test for Goodwill Impairment, to simplify the accounting for goodwill impairment by eliminating step 2 from the goodwill impairment test. ASU 2017-04 is effective for annual reporting periods beginning after December 15, 2019, including interim periods within that reporting period. We are currently evaluating the potential impact that the adoption will have on our disclosures and financial statements.

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TRANSACTIONS WITH AFFILIATES

6 Months Ended

Jun. 30, 2018

TRANSACTIONS WITH AFFILIATES

TRANSACTIONS WITH AFFILIATES

 (2) TRANSACTIONS WITH AFFILIATES

Third Amended and Restated Omnibus Agreement.Since the inception of the Partnership in 2005 we have been party to an omnibus agreement with the owner of our general partner, which agreement has been amended and restated from time to time.  The omnibus agreement provides for the provision of various services for our benefit. The fees payable under the omnibus agreement to the owner of our general partner are comprised of (i) the reimbursement of the direct operating costs and expenses, such as salaries and benefits of operational personnel performing services on site at our terminals and pipelines, which we refer to as on-site employees, (ii) bonus awards to key personnel who perform services for the Partnership, which are typically paid in the Partnership’s units and are subject to the approval by the compensation committee and the conflicts committee of our general partner, and (iii) the administrative fee for the provision of various general and administrative services for the Partnership’s benefit such as legal, accounting, treasury, insurance administration and claims processing, information technology, human resources, credit, payroll, taxes, engineering, environmental safety and occupational health (ESOH) and other corporate services, to the extent such services are not outsourced by the Partnership. The administrative fee is recognized as a component of general and administrative expenses andfor the three months ended June 30, 2018 and 2017, the administrative fee paid was approximately $2.7 million and $3.2 million, respectively. For both the six months ended June 30, 2018 and 2017, the administrative fee paid by the Partnership was approximately $6.1 million.

In accordance with the Second Amended and Restated Omnibus Agreement and the prior versions thereto, if we acquired or constructed additional facilities, the owner of our general partner may propose a revised administrative fee covering the provision of services for such additional facilities, subject to the approval by the conflicts committee of our general partner. In connection with our previously discussed Phase II buildout at our Collins terminal, the expansion of our Brownsville terminal and pipeline operations and the December 2017 acquisition of the West Coast terminals, on May 7, 2018, the Partnership, with the concurrence of the conflicts committee of our general partner, agreed to an annual increase in the aggregate fees payable to the owner of the general partner under the omnibus agreement of $3.6 million beginning May 13, 2018. 

To effectuate this $3.6 million annual increase in the aggregate fees payable to the owner of the general partner, on May 7, 2018 the Partnership, with the concurrence of the conflicts committee of our general partner, entered into the Third Amended and Restated Omnibus Agreement by and among the Partnership, our general partner, TransMontaigne Operating GP L.L.C., TransMontaigne Operating Company L.P., Gulf TLP Holdings, LLC, and TLP Management Services LLC. The effect of the change to the omnibus agreement is to allow the Partnership to assume the costs and expenses of personnel performing engineering and ESOH services for and on behalf of the Partnership and to receive an equal and offsetting decrease in the administrative fee. These costs and expenses are expected to approximate $8.9 million in 2018. We expect that a significant portion of the assumed engineering costs will be capitalized under generally accepted accounting principles. 

Prior to the $3.6 million annual increase and the effective date of the Third Amended and Restated Omnibus Agreement, the annual administrative fee was approximately $13.7 million and included the costs and expenses of the personnel performing engineering and ESOH services. Subsequent to the $3.6 million annual increase and the effective date of the Third Amended and Restated Omnibus Agreement, the annual administrative fee will be approximately $8.4 million and the Partnership will bear the approximately $8.9 million costs and expenses of the personnel performing engineering and ESOH services for and on behalf of the Partnership.

The administrative fee under the Third Amended and Restated Omnibus Agreement is subject to an increase each calendar year tied to an increase in the consumer price index, if any, plus two percent. If we acquire or construct additional facilities, the owner of our general partner may propose a revised administrative fee covering the provision of services for such additional facilities, subject to approval by the conflicts committee of our general partner.

We do not directly employ any of the persons responsible for managing our business.  We are managed by our general partner, and all of the officers of our general partner and employees who provide services to the Partnership are employed by TLP Management Services, a wholly owned subsidiary of ArcLight.  TLP Management Services provides payroll and maintains all employee benefits programs on behalf of our general partner and the Partnership pursuant to the omnibus agreement. The omnibus agreement will continue in effect until the earlier of (i) ArcLight ceasing to control our general partner or (ii) the election of either us or the owner, following at least 24 months’ prior written notice to the other parties.

Operations and reimbursement agreement—Frontera.  We have a 50% ownership interest in the Frontera Brownsville LLC joint venture, or (Frontera). We operate Frontera, in accordance with an operations and reimbursement agreement executed between us and Frontera, for a management fee that is based on our costs incurred. Our agreement with Frontera stipulates that we may resign as the operator at any time with the prior written consent of Frontera, or that we may be removed as the operator for good cause, which includes material noncompliance with laws and material failure to adhere to good industry practice regarding health, safety or environmental matters. We recognized revenue related to this operations and reimbursement agreement of approximately $1.3 million and $1.1 million for the three months ended June 30, 2018 and 2017, respectively and approximately $2.8 million and $2.5 million for the six months ended June 30, 2018 and 2017, respectively.

Terminaling services agreements—Brownsville terminals. We have terminaling services agreements with Frontera relating to our Brownsville, Texas facility that will expire in June 2019 and June 2020, subject to automatic renewals unless terminated by either party upon 90 days’ and 180 days’ prior notice, respectively. In exchange for its minimum throughput commitments, we have agreed to provide Frontera with approximately 301,000 barrels of storage capacity. We recognized revenue related to these agreements of approximately $0.6 million and $0.4 million for the three months ended June 30, 2018 and 2017, respectively and approximately $1.2 million and $0.8 million for the six months ended June 30, 2018 and 2017, respectively.

Terminaling services agreement—Gulf Coast terminals. Associated Asphalt Marketing, LLC is a wholly-owned indirect subsidiary of ArcLight. Effective January 1, 2018, a third party customer assigned their terminaling services agreement relating to our Gulf Coast terminals to Associated Asphalt Marketing, LLC. The agreement will expire in April 2021, subject to two, two-year automatic renewals unless terminated by either party upon 180 days’ prior notice. In exchange for its minimum throughput commitment, we have agreed to provide Associated Asphalt Marketing, LLC with approximately 750,000 barrels of storage capacity. We recognized revenue related to this agreement of approximately $2.1 million and $nil for the three months ended June 30, 2018 and 2017, respectively and approximately $4.3 million and $nil for the six months ended June 30, 2018 and 2017, respectively.

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BUSINESS COMBINATION AND TERMINAL ACQUISITION AND DISPOSITION

6 Months Ended

Jun. 30, 2018

BUSINESS COMBINATION AND TERMINAL ACQUISITION AND DISPOSITION

BUSINESS COMBINATION AND TERMINAL ACQUISITION AND DISPOSITION

(3) BUSINESS COMBINATION, TERMINAL ACQUISITION AND DISPOSITION

On December 15, 2017, we acquired the West Coast terminals from a third party for a total purchase price of $276.8 million. The West Coast terminals consist of two waterborne refined product and crude oil terminals located in the San Francisco Bay Area refining complex including a total of 64 storage tanks with approximately 5.0 million barrels of active storage capacity. The West Coast terminals have access to domestic and international crude oil and refined products markets through marine, pipeline, truck and rail logistics capabilities. The accompanying consolidated financial statements include the assets, liabilities and results of operations of the West Coast terminals from December 15, 2017.

The purchase price and final assessment of the fair value of the assets acquired and liabilities assumed in the business combination were as follows (in thousands):

Other current assets	$	1,037
Property, plant and equipment		228,000
Goodwill		943
Customer relationships		47,000
Total assets acquired		276,980
Environmental obligation		220
Total liabilities assumed		220
Allocated purchase price	$	276,760

Goodwill represents the excess of the consideration paid for the acquired business over the fair value of the individual assets acquired, net of liabilities assumed. Goodwill represents the premium we paid to acquire the skilled workforce.

On February 20, 2018 we closed on the purchase of certain assets from a third party. Concurrently we sold these assets to another third party for cash proceeds equal to our purchase price plus expenses.

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CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE

6 Months Ended

Jun. 30, 2018

CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE

CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE

(4) CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE

Our primary market areas are located in the United States along the Gulf Coast, in the Southeast, in Brownsville, Texas, along the Mississippi and Ohio Rivers, in the Midwest and along the West Coast. We have a concentration of trade receivable balances due from companies engaged in the trading, distribution and marketing of refined products and crude oil. These concentrations of customers may affect our overall credit risk in that the customers may be similarly affected by changes in economic, regulatory or other factors. Our customers’ historical financial and operating information is analyzed prior to extending credit. We manage our exposure to credit risk through credit analysis, credit approvals, credit limits and monitoring procedures, and for certain transactions we may request letters of credit, prepayments or guarantees. Amounts included in trade accounts receivable that are accounted for as ASC 606 revenue in accordance with ASC 606 approximate $3.5 million at June 30, 2018. We maintain allowances for potentially uncollectible accounts receivable.

Trade accounts receivable, net consists of the following (in thousands):

	June 30,		December 31,
	2018		2017
Trade accounts receivable	$	12,458	$	11,128
Less allowance for doubtful accounts		(294)		(111)
	$	12,164	$	11,017

The following customers accounted for at least 10% of our consolidated revenue in at least one of the periods presented in the accompanying consolidated statements of operations:

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
NGL Energy Partners LP	23	%	27	%	23	%	26	%
RaceTrac Petroleum Inc.	12	%	13	%	12	%	12	%
Castleton Commodities International LLC	9	%	13	%	10	%	13	%

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OTHER CURRENT ASSETS

6 Months Ended

Jun. 30, 2018

OTHER CURRENT ASSETS

OTHER CURRENT ASSETS

(5) OTHER CURRENT ASSETS

Other current assets are as follows (in thousands):

	June 30,		December 31,
	2018		2017
Prepaid insurance	$	2,761	$	4,151
Amounts due from insurance companies		1,755		1,981
Additive detergent		1,216		1,715
Unrealized gain on derivative instrument		449		—
Deposits and other assets		1,797		12,807
	$	7,978	$	20,654

Amounts due from insurance companies.  We periodically file claims for recovery of environmental remediation costs with our insurance carriers under our comprehensive liability policies. We recognize our insurance recoveries in the period that we assess the likelihood of recovery as being probable (i.e., likely to occur). At June 30, 2018 and December 31, 2017, we have recognized amounts due from insurance companies of approximately $1.8 million and $2.0 million, respectively, representing our best estimate of our probable insurance recoveries. During the six months ended June 30, 2018, we received reimbursements from insurance companies of approximately $0.2 million.

Deposits and other assets. At December 31, 2017, deposits and other assets includes a deposit of approximately $10.2 million paid during the fourth quarter 2017 related to expansion opportunities that closed in the first quarter of 2018 (See Note 3 of Notes to consolidated financial statements).

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PROPERTY, PLANT AND EQUIPMENT, NET

6 Months Ended

Jun. 30, 2018

PROPERTY, PLANT AND EQUIPMENT, NET

PROPERTY, PLANT AND EQUIPMENT, NET

(6) PROPERTY, PLANT AND EQUIPMENT, NET

Property, plant and equipment, net is as follows (in thousands):

	June 30,		December 31,
	2018		2017
Land	$	83,451	$	83,310
Terminals, pipelines and equipment		912,245		885,429
Furniture, fixtures and equipment		4,860		4,430
Construction in progress		19,481		21,575
		1,020,037		994,744
Less accumulated depreciation		(363,276)		(339,691)
	$	656,761	$	655,053

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GOODWILL

6 Months Ended

Jun. 30, 2018

GOODWILL

GOODWILL

(7) GOODWILL

Goodwill is as follows (in thousands):

	June 30,		December 31,
	2018		2017
Brownsville terminals	$	8,485	$	8,485
West Coast terminals		943		943
	$	9,428	$	9,428

Goodwill is required to be tested for impairment annually unless events or changes in circumstances indicate it is more likely than not that an impairment loss has been incurred at an interim date. Our annual test for the impairment of goodwill is performed as of December 31. The impairment test is performed at the reporting unit level. Our reporting units are our operating segments (see Note 19 of Notes to consolidated financial statements). The fair value of each reporting unit is determined on a stand‑alone basis from the perspective of a market participant and represents an estimate of the price that would be received to sell the unit as a whole in an orderly transaction between market participants at the measurement date. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting unit is not considered to be impaired.

At June 30, 2018 and December 31, 2017, our Brownsville and West Coast terminals contained goodwill. We did not recognize any goodwill impairment charges during the six months ended June 30, 2018 or during the year ended December 31, 2017 for these reporting units. However, a significant decline in the price of our common units with a resulting increase in the assumed market participants’ weighted average cost of capital, the loss of a significant customer, the disposition of significant assets, or an unforeseen increase in the costs to operate and maintain the Brownsville or West Coast terminals could result in the recognition of an impairment charge in the future.

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INVESTMENTS IN UNCONSOLIDATED AFFILIATES

6 Months Ended

Jun. 30, 2018

INVESTMENTS IN UNCONSOLIDATED AFFILIATES

INVESTMENTS IN UNCONSOLIDATED AFFILIATES

(8) INVESTMENTS IN UNCONSOLIDATED AFFILIATES

At June 30, 2018 and December 31, 2017, our investments in unconsolidated affiliates include a 42.5% Class A ownership interest in Battleground Oil Specialty Terminal Company LLC (“BOSTCO”) and a 50% ownership interest in Frontera Brownsville LLC (“Frontera”). BOSTCO is a terminal facility located on the Houston Ship Channel that encompasses approximately 7.1 million barrels of distillate, residual and other black oil product storage. Class A and Class B ownership interests share in cash distributions on a 96.5% and 3.5% basis, respectively. Class B ownership interests do not have voting rights and are not required to make capital investments. Frontera is a terminal facility located in Brownsville, Texas that encompasses approximately 1.7 million barrels of light petroleum product storage, as well as related ancillary facilities.

The following table summarizes our investments in unconsolidated affiliates:

	Percentage of				Carrying value
	ownership				(in thousands)
	June 30,		December 31,		June 30,		December 31,
	2018		2017		2018		2017
BOSTCO	42.5	%	42.5	%	$	207,627	$	209,373
Frontera	50	%	50	%		24,140		23,808
Total investments in unconsolidated affiliates					$	231,767	$	233,181

At June 30, 2018 and December 31, 2017, our investment in BOSTCO includes approximately $6.9 million and $7.0 million, respectively, of excess investment related to a one time buy-in fee to acquire our 42.5% interest and capitalization of interest on our investment during the construction of BOSTCO amortized over the useful life of the assets. Excess investment is the amount by which our investment exceeds our proportionate share of the book value of the net assets of the BOSTCO entity.

Earnings from investments in unconsolidated affiliates was as follows (in thousands):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
BOSTCO	$	1,848	$	1,275	$	3,839	$	2,981
Frontera		596		845		1,494		1,699
Total earnings from investments in unconsolidated affiliates	$	2,444	$	2,120	$	5,333	$	4,680

Additional capital investments in unconsolidated affiliates was as follows (in thousands):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
BOSTCO	$	—	$	145	$	—	$	145
Frontera		114		—		1,264		2,000
Additional capital investments in unconsolidated affiliates	$	114	$	145	$	1,264	$	2,145

Cash distributions received from unconsolidated affiliates was as follows (in thousands):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
BOSTCO	$	3,491	$	3,319	$	5,585	$	6,398
Frontera		1,330		1,227		2,426		2,497
Cash distributions received from unconsolidated affiliates	$	4,821	$	4,546	$	8,011	$	8,895

The summarized financial information of our unconsolidated affiliates is as follows (in thousands):

Balance sheets:

	BOSTCO				Frontera
	June 30,		December 31,		June 30,		December 31,
	2018		2017		2018		2017
Current assets	$	20,794	$	24,976	$	5,720	$	5,649
Long-term assets		460,308		469,348		44,613		44,292
Current liabilities		(7,590)		(17,550)		(1,922)		(2,147)
Long-term liabilities		(1,314)		—		(131)		(178)
Net assets	$	472,198	$	476,774	$	48,280	$	47,616

Statements of operations:

	BOSTCO				Frontera
	Three months ended				Three months ended
	June 30,				June 30,
	2018		2017		2018		2017
Revenue	$	16,908	$	17,028	$	6,009	$	5,198
Expenses		(11,515)		(13,628)		(4,817)		(3,508)
Net earnings	$	5,393	$	3,400	$	1,192	$	1,690

	BOSTCO				Frontera
	Six months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
Revenue	$	33,735	$	33,658	$	11,921	$	10,591
Expenses		(24,064)		(25,866)		(8,933)		(7,193)
Net earnings	$	9,671	$	7,792	$	2,988	$	3,398

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OTHER ASSETS, NET

6 Months Ended

Jun. 30, 2018

OTHER ASSETS, NET

OTHER ASSETS, NET

(9) OTHER ASSETS, NET

Other assets, net are as follows (in thousands):

	June 30,		December 31,
	2018		2017
Customer relationships, net of accumulated amortization of $3,679 and $2,294, respectively	$	45,751	$	47,136
Revolving credit facility unamortized deferred issuance costs, net of accumulated amortization of $6,807 and $5,984, respectively		6,364		6,778
Amounts due under long-term terminaling services agreements		439		460
Unrealized gain on derivative instruments		—		576
Deposits and other assets		289		288
	$	52,843	$	55,238

Customer relationships.  Other assets, net include certain customer relationships primarily at our West Coast terminals. These customer relationships are being amortized on a straight‑line basis over twenty years.

Revolving credit facility unamortized deferred issuance costs.  Deferred issuance costs are amortized using the effective interest method over the term of the related revolving credit facility.

Amounts due under long‑term terminaling services agreements.  We have long‑term terminaling services agreements with certain of our customers that provide for minimum payments that increase at stated amounts over the terms of the respective agreements. We recognize as revenue the minimum payments under the long‑term terminaling services agreements on a straight‑line basis over the terms of the respective agreements. At June 30, 2018 and December 31, 2017, we have recognized revenue in excess of the minimum payments that was due through those respective dates under the long‑term terminaling services agreements resulting in an asset of approximately $0.4 million and $0.5 million, respectively.

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ACCRUED LIABILITIES

6 Months Ended

Jun. 30, 2018

ACCRUED LIABILITIES

ACCRUED LIABILITIES

(10) ACCRUED LIABILITIES

Accrued liabilities are as follows (in thousands):

	June 30,		December 31,
	2018		2017
Customer advances and deposits	$	8,540	$	10,265
Accrued property taxes		4,277		1,381
Accrued environmental obligations		1,836		1,855
Interest payable		7,960		982
Accrued expenses and other		4,063		2,943
	$	26,676	$	17,426

Customer advances and deposits.    We bill certain of our customers one month in advance for terminaling services to be provided in the following month. At June 30, 2018, approximately $0.4 million of the customer advances and deposits balance is considered contract liabilities under ASC 606. Revenue recognized during the six months ended June 30, 2018 from amounts included in contract liabilities at the beginning of the period was approximately $0.5 million. At June 30, 2018 and December 31, 2017, we have billed and collected from certain of our customers approximately $8.5 million and $10.3 million, respectively, in advance of the terminaling services being provided.

Accrued environmental obligations.  At both June 30, 2018 and December 31, 2017, we have accrued environmental obligations of approximately $1.8 million and $1.9 million, respectively, representing our best estimate of our remediation obligations. During the six months ended June 30, 2018, we made payments of approximately $0.2 million towards our environmental remediation obligations. During the six months ended June 30, 2018, we increased our estimate of our future environmental remediation costs by approximately $0.2 million. Changes in our estimates of our future environmental remediation obligations may occur as a result of the passage of time and the occurrence of future events.

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OTHER LIABILITIES

6 Months Ended

Jun. 30, 2018

OTHER LIABILITIES

OTHER LIABILITIES

(11) OTHER LIABILITIES

Other liabilities are as follows (in thousands):

	June 30,		December 31,
	2018		2017
Advance payments received under long-term terminaling services agreements	$	1,782	$	1,599
Deferred revenue—ethanol blending fees and other projects		1,755		2,034
	$	3,537	$	3,633

Advance payments received under long‑term terminaling services agreements.  We have long‑term terminaling services agreements with certain of our customers that provide for advance minimum payments. We recognize the advance minimum payments as revenue either on a straight‑line basis over the term of the respective agreements or when services have been provided based on volumes of product distributed. At June 30, 2018 and December 31, 2017, we have received advance minimum payments in excess of revenue recognized under these long‑term terminaling services agreements resulting in a liability of approximately $1.8 million and $1.6 million, respectively.

Deferred revenue—ethanol blending fees and other projects.  Pursuant to agreements with our customers, we agreed to undertake certain capital projects that primarily pertain to providing ethanol blending functionality at certain of our Southeast terminals. Upon completion of the projects, our customers have paid us amounts that will be recognized as revenue on a straight‑line basis over the remaining term of the agreements. At June 30, 2018 and December 31, 2017, we have unamortized deferred revenue for completed projects of approximately $1.8 million and $2.0 million, respectively. During the six months ended June 30, 2018, we billed customers approximately $0.9 million for completed projects and recognized revenue for completed projects on a straight‑line basis of approximately $1.2 million. During the six months ended June 30, 2017, we recognized revenue for completed projects on a straight-line basis of approximately $0.3 million. At June 30, 2018, approximately $nil of the deferred revenue-ethanol blending fees and other projects balance is considered contract liabilities under ASC 606. Revenue recognized during the six months ended June 30, 2018 from amounts included in contract liabilities under ASC 606 at the beginning of the period was approximately $0.2 million.

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LONG-TERM DEBT

6 Months Ended

Jun. 30, 2018

LONG-TERM DEBT

LONG-TERM DEBT

(12) LONG‑TERM DEBT

Long-term debt is as follows (in thousands):

	June 30,		December 31,
	2018		2017
Revolving credit facility due in 2022	$	286,300	$	593,200
6.125% senior notes due in 2026		300,000		—
Senior notes unamortized deferred issuance costs, net of accumulated amortization of $301 and $nil, respectively		(7,777)		—
	$	578,523	$	593,200

On February 12, 2018, the Partnership and TLP Finance Corp., our wholly owned subsidiary, completed the sale of $300 million of 6.125% senior notes, issued at par and due 2026. The senior notes were guaranteed on a senior unsecured basis by each of our 100% owned domestic subsidiaries that guarantee obligations under our revolving credit facility. Net proceeds after $8.1 million of issuance costs, were used to repay indebtedness under our revolving credit facility.

Our senior secured revolving credit facility, or our “revolving credit facility”, provides for a maximum borrowing line of credit equal to $850 million. The terms of our revolving credit facility include covenants that restrict our ability to make cash distributions, acquisitions and investments, including investments in joint ventures. We may make distributions of cash to the extent of our “available cash” as defined in our partnership agreement. We may make acquisitions and investments that meet the definition of “permitted acquisitions”; “other investments” which may not exceed 5% of “consolidated net tangible assets”; and additional future “permitted JV investments” up to $175 million, which may include additional investments in BOSTCO. The primary financial covenants contained in our revolving credit facility are (i) a total leverage ratio test (not to exceed 5.25 to 1.0), (ii) a senior secured leverage ratio test (not to exceed 3.75 to 1.0), and (iii) a minimum interest coverage ratio test (not less than 2.75 to 1.0). The principal balance of loans and any accrued and unpaid interest are due and payable in full on the maturity date in March 2022. We were in compliance with all financial covenants as of and during the six months ended June 30, 2018 and the year ended December 31, 2017.  

We may elect to have loans under our revolving credit facility bear interest either (i) at a rate of LIBOR plus a margin ranging from 1.75% to 2.75% depending on the total leverage ratio then in effect, or (ii) at the base rate plus a margin ranging from 0.75% to 1.75% depending on the total leverage ratio then in effect. We also pay a commitment fee on the unused amount of commitments, ranging from 0.375% to 0.5% per annum, depending on the total leverage ratio then in effect. Our obligations under our revolving credit facility are secured by a first priority security interest in favor of the lenders in the majority of our assets, including our investments in unconsolidated affiliates. For the six months ended June 30, 2018 and 2017, the weighted average interest rate on borrowings under our revolving credit facility was approximately 4.7% and 3.4%, respectively. At June 30, 2018 and December 31, 2017, our outstanding borrowings under our revolving credit facility were $286.3 million and $593.2 million, respectively. At both June 30, 2018 and December 31, 2017 our outstanding letters of credit were $0.4 million.

We have an effective universal shelf‑registration statement and prospectus on Form S‑3 with the Securities and Exchange Commission (“SEC”) that expires in September 2019. In February 2018, we and TLP Finance Corp., our 100% owned subsidiary, used the shelf registration statement to issue senior notes that were guaranteed on a senior unsecured basis by each of our 100% owned domestic subsidiaries that guarantee obligations under our revolving credit facility. In the future, we may issue additional debt or equity securities pursuant to that registration statement. TransMontaigne Partners L.P. has no independent assets or operations unrelated to its investments in its consolidated subsidiaries. TLP Finance Corp. has no assets or operations. Our operations are conducted by subsidiaries of TransMontaigne Partners L.P. through our 100% owned operating company subsidiary, TransMontaigne Operating Company L.P. Each of TransMontaigne Operating Company L.P.s’ and our other 100% owned domestic subsidiaries (other than TLP Finance Corp., whose sole purpose is to act as co‑issuer of any debt securities) may guarantee any future debt securities we issue. We expect that any guarantees associated with future debt securities will be full and unconditional and joint and several, subject to certain automatic customary releases, including sale, disposition, or transfer of the capital stock or substantially all of the assets of a subsidiary guarantor, exercise of legal defeasance option or covenant defeasance option, and designation of a subsidiary guarantor as unrestricted in accordance with the indenture. There are no significant restrictions on the ability of TransMontaigne Partners L.P. or any guarantor to obtain funds from its subsidiaries by dividend or loan. None of the assets of TransMontaigne Partners L.P. or a guarantor represent restricted net assets pursuant to the guidelines established by the SEC.

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PARTNERS' EQUITY

6 Months Ended

Jun. 30, 2018

PARTNERS' EQUITY

PARTNERS' EQUITY

(13) PARTNERS’ EQUITY

The number of units outstanding is as follows:

		General
	Common	partner
	units	equivalent units
Units outstanding at December 31, 2017	16,177,353	330,150
Issuance of common units pursuant to our savings and retention program	44,798	—
Contribution of cash by TransMontaigne GP to maintain its 2% general partner interest	—	905
Units outstanding at June 30, 2018	16,222,151	331,055

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EQUITY-BASED COMPENSATION

6 Months Ended

Jun. 30, 2018

EQUITY-BASED COMPENSATION

EQUITY-BASED COMPENSATION

(14) EQUITY-BASED COMPENSATION

Long-term incentive plan. The TLP Management Services long-term incentive plan reserves 750,000 common units to be granted as awards under the plan, with such amount subject to adjustment as provided for under the terms of the plan if there is a change in our common units, such as a unit split or other reorganization. The common units authorized to be granted under the TLP Management Services long-term incentive plan are registered pursuant to a registration statement on Form S-8.

The TLP Management Services long‑term incentive plan is administered by the compensation committee of the board of directors of our general partner and is used for grants of units to the independent directors of our general partner. The grants to the independent directors of our general partner under the TLP Management Services long-term incentive plan are immediately vested and not subject to forfeiture. Accordingly, there are no long-term incentive plan grants outstanding as of June 30, 2018.

Generally accepted accounting principles require us to measure the cost of board member services received in exchange for an award of equity instruments based on the grant‑date fair value of the award. That cost is recognized over the vesting period on a straight line basis during which a board member is required to provide services in exchange for the award with the costs being accelerated upon the occurrence of accelerated vesting events, such as a change in control of our general partner. 

For awards to the independent directors of our general partner, equity-based compensation of approximately $140,000 is included in equity-based compensation expense for both the six months ended June 30, 2018 and 2017.

Savings and retention program. TLP Management Services savings and retention programis intended to constitute a program under, and be subject to, the TLP Management Services long-term incentive plan described above. The savings and retention program is used for awards to employees of TLP Management Services who provide services to the Partnership.

The restricted phantom units awarded and accrued under the savings and retention program are subject to forfeiture until the vesting date. Recipients have distribution equivalent rights from the date of grant that accrue additional restricted phantom units equivalent to the value of quarterly distributions paid by us on each of our outstanding common units. Recipients of restricted phantom units under the savings and retention program do not have voting rights.

The purpose of the savings and retention program is to provide for the reward and retention of participants by providing them with bonus awards that vest over future service periods. Awards under the program generally become vested as to 50% of a participant’s annual award as of the first day of the month that falls closest to the second anniversary of the grant date, and the remaining 50% as of the first day of the month that falls closest to the third anniversary of the grant date, subject to earlier vesting upon a participant’s attainment of the age and length of service thresholds, retirement, death or disability, involuntary termination without cause, or termination of a participant’s employment following a change in control of the Partnership, our general partner or TLP Management Services, as specified in the program.

A person will satisfy the age and length of service thresholds of the program upon the attainment of the earliest of (a) age sixty, (b) age fifty five and ten years of service as an officer of TLP Management Services or any of its affiliates or predecessors, or (c) age fifty and twenty years of service as an employee of TLP Management Services or any of its affiliates or predecessors.

Under the omnibus agreement we have agreed to reimburse the owner of TransMontaigne GP for bonus awards made to key employees under the savings and retention program, provided the compensation committee and the conflicts committee of our general partner approve the annual awards granted under the program (see Note 2 of Notes to consolidated financial statements). We have the option to provide the reimbursement in either a cash payment or the delivery of our common units to the savings and retention program or alternatively directly to the award recipients, with the reimbursement made in accordance with the underlying vesting and payment schedule of the savings and retention program. Our reimbursement for the bonus awards is reduced for forfeitures and is increased for the value of quarterly distributions accrued under the distribution equivalent rights. We have the intent and ability to settle our reimbursement for the bonus awards in our common units, and accordingly, we account for the bonus awards as an equity award.

Given that we do not have any employees to provide corporate and support services and instead we contract for such services under the omnibus agreement, generally accepted accounting principles require us to classify the savings and retention program awards as a non-employee award and measure the cost of services received in exchange for an award of equity instruments based on the vesting‑date fair value of the award. That cost, or an estimate of that cost in the case of unvested restricted phantom units, is recognized over the period during which services are provided in exchange for the award. As of June 30, 2018, there was approximately $1.9 million of total unrecognized equity-based compensation expense related to unvested restricted phantom units, which is expected to be recognized over the remaining weighted average period of 1.73 years.

For bonus awards to employees of TLP Management Services, approximately $2.3 million and $2.0 million is included in equity-based compensation expense for the six months ended June 30, 2018 and 2017, respectively. 

Activity related to our equity-based awards granted under the savings and retention program for services performed under the omnibus agreement for the six months ended June 30, 2018 is as follows:

		Weighted			Weighted
		average			average
	Vested	price		Unvested	price
Restricted phantom units outstanding at December 31, 2017	91,877	$	38.91	54,244	$	38.81
Issuance of units	(44,798)	$	37.75	—	$	—
Units withheld for settlement of withholding taxes	(16,822)	$	37.59	—	$	—
Unit accrual for distributions paid	3,371	$	37.53	2,447	$	37.56
Vesting of units	18,970	$	36.61	(18,970)	$	36.61
Grant of units	46,362	$	35.23	33,097	$	35.23
Forfeiture of units	—	$	—	(809)	$	35.23
Restricted phantom units outstanding at June 30, 2018	98,960	$	38.52	70,009	$	38.22
Vested and expected to vest at June 30, 2018	168,969	$	38.40

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NET EARNINGS PER LIMITED PARTNER UNIT

6 Months Ended

Jun. 30, 2018

NET EARNINGS PER LIMITED PARTNER UNIT

NET EARNINGS PER LIMITED PARTNER UNIT

(15) NET EARNINGS PER LIMITED PARTNER UNIT

The following table reconciles net earnings to net earnings allocable to limited partners and sets forth the computation of basic and diluted net earnings per limited partner unit (in thousands, except per unit amounts):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
Net earnings	$	9,460	$	14,478	$	21,634	$	27,432
Less:
Distributions payable on behalf of incentive distribution rights		(3,758)		(2,873)		(7,353)		(5,509)
Distributions payable on behalf of general partner interest		(263)		(244)		(522)		(483)
Earnings allocable to general partner interest less than distributions payable to general partner interest		149		12		237		44
Earnings allocable to general partner interest including incentive distribution rights		(3,872)		(3,105)		(7,638)		(5,948)
Net earnings allocable to limited partners per the consolidated statements of operations	$	5,588	$	11,373	$	13,996	$	21,484
Basic weighted average units		16,327		16,260		16,310		16,253
Diluted weighted average units		16,356		16,279		16,345		16,271
Net earnings per limited partner unit—basic	$	0.34	$	0.70	$	0.86	$	1.32
Net earnings per limited partner unit—diluted	$	0.34	$	0.70	$	0.86	$	1.32

Pursuant to our partnership agreement we are required to distribute available cash (as defined by our partnership agreement) as of the end of the reporting period. Such distributions are declared within 45 days after period end. The following table sets forth the distribution declared per common unit attributable to the periods indicated:

	Distribution
January 1, 2017 through March 31, 2017	$	0.725
April 1, 2017 through June 30, 2017	$	0.740
July 1, 2017 through September 30, 2017	$	0.755
October 1, 2017 through December 31, 2017	$	0.770
January 1, 2018 through March 31, 2018	$	0.785
April 1, 2018 through June 30, 2018	$	0.795

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2018

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES

(16) COMMITMENTS AND CONTINGENCIES

Contract commitments.  At June 30, 2018, we have contractual commitments of approximately $38.0 million for the supply of services, labor and materials related to capital projects that currently are under development. We expect that these contractual commitments will be paid within the next twelve months.

Operating leases.  We lease property and equipment under non‑cancelable operating leases. At June 30, 2018, future minimum lease payments under these non‑cancelable operating leases are as follows (in thousands):

Years ending December 31:
2018 (remainder of the year)	$	1,534
2019		3,409
2020		2,047
2021		1,929
2022		978
Thereafter		4,276
	$	14,173

Included in the above non‑cancelable operating lease commitments are amounts for property rentals that we have sublet under non‑cancelable sublease agreements or have reimbursement agreements with affiliates, for which we expect to receive minimum rentals of approximately $7.8 million in future periods.

Rental expense under operating leases was approximately $0.5 million and $0.9 million for the three months ended June 30, 2018 and 2017, respectively, and $1.0 million and $1.7 million for the six months ended June 30, 2018 and 2017, respectively.

Legal proceedings. We are party to various legal, regulatory and other matters arising from the day-to-day operations of our business that may result in claims against us. While the ultimate impact of any proceedings cannot be predicted with certainty, our management believes that the resolution of any of our pending legal proceedings will not have a material adverse effect on our business, financial position, results of operations or cash flows. 

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DISCLOSURES ABOUT FAIR VALUE

6 Months Ended

Jun. 30, 2018

DISCLOSURES ABOUT FAIR VALUE

DISCLOSURES ABOUT FAIR VALUE

(17) DISCLOSURES ABOUT FAIR VALUE

“GAAP” defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. GAAP also establishes a fair value hierarchy that prioritizes the use of higher‑level inputs for valuation techniques used to measure fair value. The three levels of the fair value hierarchy are: (1) Level 1 inputs, which are quoted prices (unadjusted) in active markets for identical assets or liabilities; (2) Level 2 inputs, which are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly; and (3) Level 3 inputs, which are unobservable inputs for the asset or liability.

The fair values of the following financial instruments represent our best estimate of the amounts that would be received to sell those assets or that would be paid to transfer those liabilities in an orderly transaction between market participants at that date. Our fair value measurements maximize the use of observable inputs. However, in situations where there is little, if any, market activity for the asset or liability at the measurement date, the fair value measurement reflects our judgments about the assumptions that market participants would use in pricing the asset or liability based on the best information available in the circumstances. The following methods and assumptions were used to estimate the fair value of financial instruments at June 30, 2018 and December 31, 2017.

Cash equivalents.  The carrying amount approximates fair value because of the short‑term maturity of these instruments. The fair value is categorized in Level 1 of the fair value hierarchy.

Derivative instruments.  The carrying amount of our interest rate swaps was determined using a pricing model based on the LIBOR swap rate and other observable market data. The fair value is categorized in Level 2 of the fair value hierarchy.

Debt. The carrying amount of our revolving credit facility debt approximates fair value since borrowings under the facility bear interest at current market interest rates. The carrying value of our publicly traded senior notes approximates fair value as of June 30, 2018 and December 31, 2017. The fair value of our publicly traded senior notes is based on the prices of those senior notes at June 30, 2018 and December 31, 2017. The fair value is categorized in Level 2 of the fair value hierarchy.

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REVENUE FROM CONTRACTS WITH CUSTOMERS

6 Months Ended

Jun. 30, 2018

REVENUE FROM CONTRACTS WITH CUSTOMERS

REVENUE FROM CONTRACTS WITH CUSTOMERS

(18) REVENUE FROM CONTRACTS WITH CUSTOMERS

The majority of our terminaling service agreements contain firm commitments for minimum revenue streams and are accounted for in accordance with ASC 840, Leases (“ASC 840 revenue”). The remainder is recognized in accordance with ASC 606, Revenue From Contracts With Customers (“ASC 606 revenue”).

The following table provides details of our revenue disaggregated by category of revenue (in thousands):    

	Three months ended		Six months ended
	June 30,		June 30,
	2018		2018
Terminaling services fees:
Firm commitments (ASC 840 revenue)	$	39,149	$	77,855
Firm commitments (ASC 606 revenue)		3,549		6,976
Total firm commitments revenue		42,698		84,831
Ancillary revenue (ASC 606 revenue)		9,680		20,738
Total terminaling services fees		52,378		105,569
Pipeline transportation fees (ASC 840 revenue)		794		1,663
Management fees (ASC 606 revenue)		2,172		4,556
Total revenue	$	55,344	$	111,788

The following table includes our estimated revenue associated with our firm commitments under our terminaling services fees which is expected to be recognized as ASC 606 revenue in the specified period related to the future performance obligations as of the end of the reporting period (in thousands):

Estimated Future ASC 606 Revenue by Segment

			Midwest
			Terminals and
	Gulf Coast		Pipeline			Brownsville		River		Southeast		West Coast
	Terminals		System			Terminals		Terminals		Terminals		Terminals		Total
Remainder of 2018	$	2,060	$	—	$	—	$	578	$	—	$	3,040	$	5,678
2019		721		—		—		1,039		—		1,594		3,354
2020		—		—		—		1,039		—		125		1,164
2021		—		—		—		519		—		—		519
Thereafter		—		—		—		—		—		—		—
Total estimated ASC 606 revenue	$	2,781	$	—	$	—	$	3,175	$	—	$	4,759	$	10,715

Our ASC 606 revenue, for purposes of the tabular presentation above, excludes estimates of future rate changes due to changes in indices or contractually negotiated rate escalations and is generally limited to contracts that have minimum payment arrangements. The balances include the full amount of our customer commitments accounted for as ASC 606 revenue as of June 30, 2018 through the expiration of the related contracts. The balances disclosed exclude all performance obligations for which the original expected term is one year or less, the term of the contract with the customer is open and cannot be estimated, the contract includes options for future purchases or the consideration is variable.

Estimated revenue in the table above excludes revenue arrangements accounted for in accordance with ASC 840 in the amount of $77.3 million for the remainder of 2018, $124.2 million for 2019, $103.3 million for 2020, $78.5 million for 2021 and $59.9 million thereafter.

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BUSINESS SEGMENTS

6 Months Ended

Jun. 30, 2018

BUSINESS SEGMENTS

BUSINESS SEGMENTS

(19) BUSINESS SEGMENTS

We provide integrated terminaling, storage, transportation and related services to companies engaged in the trading, distribution and marketing of refined petroleum products, crude oil, chemicals, fertilizers and other liquid products. Our chief operating decision maker is our general partner’s chief executive officer. Our general partner’s chief executive officer reviews the financial performance of our business segments using disaggregated financial information about “net margins” for purposes of making operating decisions and assessing financial performance. “Net margins” is composed of revenue less direct operating costs and expenses. Accordingly, we present “net margins” for each of our business segments: (i) Gulf Coast terminals, (ii) Midwest terminals and pipeline system, (iii) Brownsville terminals, (iv) River terminals, (v) Southeast terminals and (vi) West Coast terminals.

The financial performance of our business segments is as follows (in thousands):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
Gulf Coast Terminals:
Terminaling services fees	$	16,465	$	15,533	$	32,638	$	31,540
Management fees		86		263		183		546
Revenue		16,551		15,796		32,821		32,086
Direct operating costs and expenses		(5,413)		(5,426)		(11,245)		(10,980)
Net margins		11,138		10,370		21,576		21,106
Midwest Terminals and Pipeline System:
Terminaling services fees		2,405		2,465		4,824		4,868
Pipeline transportation fees		433		433		866		866
Revenue		2,838		2,898		5,690		5,734
Direct operating costs and expenses		(743)		(693)		(1,455)		(1,405)
Net margins		2,095		2,205		4,235		4,329
Brownsville Terminals:
Terminaling services fees		1,977		2,505		4,043		4,972
Pipeline transportation fees		361		1,363		797		2,646
Management fees		1,892		1,614		3,996		3,538
Revenue		4,230		5,482		8,836		11,156
Direct operating costs and expenses		(2,135)		(2,582)		(4,176)		(5,454)
Net margins		2,095		2,900		4,660		5,702
River Terminals:
Terminaling services fees		2,589		2,740		5,343		5,410
Revenue		2,589		2,740		5,343		5,410
Direct operating costs and expenses		(1,805)		(1,535)		(3,641)		(3,185)
Net margins		784		1,205		1,702		2,225
Southeast Terminals:
Terminaling services fees		19,510		18,263		39,749		35,460
Management fees		194		185		377		368
Revenue		19,704		18,448		40,126		35,828
Direct operating costs and expenses		(5,714)		(5,748)		(12,333)		(11,471)
Net margins		13,990		12,700		27,793		24,357
West Coast Terminals:
Terminaling services fees		9,432		—		18,972		—
Revenue		9,432		—		18,972		—
Direct operating costs and expenses		(3,465)		—		(6,570)		—
Net margins		5,967		—		12,402		—
Total net margins		36,069		29,380		72,368		57,719
General and administrative expenses		(4,619)		(4,080)		(9,600)		(8,051)
Insurance expenses		(1,271)		(1,002)		(2,517)		(2,008)
Equity-based compensation expense		(441)		(352)		(2,458)		(2,169)
Depreciation and amortization		(13,160)		(8,792)		(24,968)		(17,497)
Earnings from unconsolidated affiliates		2,444		2,120		5,333		4,680
Operating income		19,022		17,274		38,158		32,674
Other expenses		(9,562)		(2,796)		(16,524)		(5,242)
Net earnings	$	9,460	$	14,478	$	21,634	$	27,432

Supplemental information about our business segments is summarized below (in thousands):

	Three months ended June 30, 2018
			Midwest
			Terminals and
	Gulf Coast		Pipeline		Brownsville		River		Southeast		West Coast
	Terminals		System		Terminals		Terminals		Terminals		Terminals		Total
Revenue:
External customers	$	14,480	$	2,838	$	2,336	$	2,589	$	19,704	$	9,432	$	51,379
Frontera		—		—		1,894		—		—		—		1,894
Associated Asphalt, LLC		2,071		—		—		—		—		—		2,071
Revenue	$	16,551	$	2,838	$	4,230	$	2,589	$	19,704	$	9,432	$	55,344
Capital expenditures	$	1,814	$	35	$	2,024	$	345	$	9,152	$	2,082	$	15,452
Identifiable assets	$	122,011	$	20,488	$	42,507	$	48,710	$	221,539	$	274,479	$	729,734
Cash and cash equivalents														390
Investments in unconsolidated affiliates														231,767
Deferred issuance costs														6,364
Other														6,567
Total assets													$	974,822

	Three months ended June 30, 2017
			Midwest
			Terminals and
	Gulf Coast		Pipeline		Brownsville		River		Southeast		West Coast
	Terminals		System		Terminals		Terminals		Terminals		Terminals		Total
Revenue:
External customers	$	15,796	$	2,898	$	3,968	$	2,740	$	18,448	$	—	$	43,850
Frontera		—		—		1,514		—		—		—		1,514
Revenue	$	15,796	$	2,898	$	5,482	$	2,740	$	18,448	$	—	$	45,364
Capital expenditures	$	1,059	$	45	$	228	$	652	$	17,161	$	—	$	19,145

	Six months ended June 30, 2018
			Midwest
			Terminals and
	Gulf Coast		Pipeline		Brownsville		River		Southeast		West Coast
	Terminals		System		Terminals		Terminals		Terminals		Terminals		Total
Revenue:
External customers	$	28,538	$	5,690	$	4,824	$	5,343	$	40,126	$	18,972	$	103,493
Frontera		—		—		4,012		—		—		—		4,012
Associated Asphalt, LLC		4,283		—		—		—		—		—		4,283
Revenue	$	32,821	$	5,690	$	8,836	$	5,343	$	40,126	$	18,972	$	111,788
Capital expenditures	$	3,180	$	336	$	2,467	$	892	$	12,435	$	2,645	$	21,955

	Six months ended June 30, 2017
			Midwest
			Terminals and
	Gulf Coast		Pipeline		Brownsville		River		Southeast		West Coast
	Terminals		System		Terminals		Terminals		Terminals		Terminals		Total
Revenue:
External customers	$	32,086	$	5,734	$	7,872	$	5,410	$	35,828	$	—	$	86,930
Frontera		—		—		3,284		—		—		—		3,284
Revenue	$	32,086	$	5,734	$	11,156	$	5,410	$	35,828	$	—	$	90,214
Capital expenditures	$	2,586	$	267	$	372	$	1,046	$	24,374	$	—	$	28,645

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SUBSEQUENT EVENTS

6 Months Ended

Jun. 30, 2018

SUBSEQUENT EVENTS.

SUBSEQUENT EVENTS

(20) SUBSEQUENT EVENTS

ArcLight buyout offer.    On July 9, 2018 the board of directors of TransMontaigne GP L.L.C. received a non-binding proposal from affiliates of ArcLight, directed to the conflicts committee of our general partner, pursuant to which ArcLight would acquire through a subsidiary all common units of the Partnership that ArcLight and its affiliates do not already own in exchange for $38.00 per common unit. If approved, the transaction would be effected through a merger of the Partnership with a subsidiary of ArcLight.

The transaction, as proposed, is subject to a number of contingencies, including ArcLight’s completion of due diligence, the approval of the conflicts committee, the approval by holders of a majority of the outstanding common units of the Partnership and the satisfaction of any conditions to the consummation of a transaction set forth in any definitive agreement concerning the transaction. There can be no assurance that definitive documentation will be executed or that any transaction will materialize.

Quarterly distribution.  On July 17, 2018, we announced a distribution of $0.795 per unit for the period from April 1, 2018 through June 30, 2018. This distribution was paid on August 8, 2018 to unitholders of record on July 31, 2018. 

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Jun. 30, 2018

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Nature of business

(a) Nature of business

TransMontaigne Partners L.P. (“we,” “us,” “our,” “the Partnership”) was formed in February 2005 as a Delaware limited partnership. We provide integrated terminaling, storage, transportation and related services for companies engaged in the trading, distribution and marketing of light refined petroleum products, heavy refined petroleum products, crude oil, chemicals, fertilizers and other liquid products. We conduct our operations in the United States along the Gulf Coast, in the Midwest, in Houston and Brownsville, Texas, along the Mississippi and Ohio rivers, in the Southeast and along the West Coast.

We are controlled by our general partner, TransMontaigne GP L.L.C. (“TransMontaigne GP”), which as of February 1, 2016 is a wholly‑owned indirect subsidiary of ArcLight Energy Partners Fund VI, L.P. (“ArcLight”). 

Basis of presentation and use of estimates

(b) Basis of presentation and use of estimates

Our accounting and financial reporting policies conform to accounting principles generally accepted in the United States of America (“GAAP”). The accompanying consolidated financial statements include the accounts of TransMontaigne Partners L.P. and its controlled subsidiaries. Investments where we do not have the ability to exercise control, but do have the ability to exercise significant influence, are accounted for using the equity method of accounting. All inter‑company accounts and transactions have been eliminated in the preparation of the accompanying consolidated financial statements. The accompanying consolidated financial statements include all adjustments (consisting of normal and recurring accruals) considered necessary to present fairly our financial position as of June 30, 2018 and December 31, 2017 and our results of operations for the three and six months ended June 30, 2018 and 2017.Certain reclassifications of previously reported amounts have been made to conform to the current year presentation.

The preparation of financial statements in conformity with “GAAP” requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenue and expenses during the reporting periods. The following estimates, in management’s opinion, are subjective in nature, require the exercise of judgment, and/or involve complex analyses: business combination estimates and assumptions, useful lives of our plant and equipment and accrued environmental obligations. Changes in these estimates and assumptions will occur as a result of the passage of time and the occurrence of future events. Actual results could differ from these estimates.

Accounting for terminal and pipeline operations

(c) Accounting for terminal and pipeline operations

Effective January 1, 2018, we adopted Accounting Standards Codification (“ASC”) Topic 606, Revenue from Contracts with Customers (“ASC 606”), applying the modified retrospective transition method, which required us to apply the new standard to (i) all new revenue contracts entered into after January 1, 2018, and (ii) revenue contracts which were not completed as of January 1, 2018. ASC 606 replaces existing revenue recognition requirements in GAAP and requires entities to recognize revenue at an amount that reflects the consideration to which we expect to be entitled in exchange for transferring goods or services to a customer. ASC 606 also requires certain disclosures regarding qualitative and quantitative information regarding the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The adoption of ASC 606 did not result in a transition adjustment nor did it have an impact on the timing or amount of our revenue recognition (See Note 18 of Notes to consolidated financial statements).

The adoption of ASC 606 did not result in changes to our accounting for trade accounts receivable (see Note 4 of Notes to consolidated financial statements), contract assets or contract liabilities. We recognize contract assets in situations where revenue recognition under ASC 606 occurs prior to billing the customer based on our rights under the contract. Contract assets are transferred to accounts receivable when the rights become unconditional. At June 30, 2018, we did not have any contract assets related to ASC 606.

Contract liabilities primarily relate to consideration received from customers in advance of completing the performance obligation. A performance obligation is a promise in a contract to transfer goods or services to the customer. We recognize contract liabilities under these arrangements as revenue once all contingencies or potential performance obligations have been satisfied by the (i) performance of services or (ii) expiration of the customer’s rights under the contract. Short-term contract liabilities include customer advances and deposits (see Note 10 of Notes to consolidated financial statements). Long-term contract liabilities include deferred revenue related to ethanol blending fees and other projects (See Note 11 of Notes to consolidated financial statements).

We generate revenue from terminaling services fees, pipeline transportation fees and management fees. Under ASC 606, we recognize revenue over time or at a point in time, depending on the nature of the performance obligations contained in the respective contract with our customer. The contract transaction price is allocated to each performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. The majority of our revenue is recognized pursuant to ASC guidance other than ASC 606. The following is an overview of our significant revenue streams, including a description of the respective performance obligations and related method of revenue recognition. 

Terminaling services fees. Our terminaling services agreements are structured as either throughput agreements or storage agreements. Our throughput agreements contain provisions that require our customers to make minimum payments, which are based on contractually established minimum volumes of throughput of the customer’s product at our facilities, over a stipulated period of time. Due to this minimum payment arrangement, we recognize a fixed amount of revenue from the customer over a certain period of time, even if the customer throughputs less than the minimum volume of product during that period. In addition, if a customer throughputs a volume of product exceeding the minimum volume, we would recognize additional revenue on this incremental volume. Our storage agreements require our customers to make minimum payments based on the volume of storage capacity available to the customer under the agreement, which results in a fixed amount of recognized revenue. We refer to the fixed amount of revenue recognized pursuant to our terminaling services agreements as being “firm commitments.” The majority of our firm commitments under our terminaling services agreements are accounted for in accordance with ASC 840, Leases (“ASC 840 revenue”). The remainder is recognized in accordance with ASC 606 (“ASC 606 revenue”) where the minimum payment arrangement in each contract is a single performance obligation that is primarily satisfied over time through the contract term. 

Revenue recognized in excess of firm commitments and revenue recognized based solely on the volume of product distributed or injected are referred to as ancillary. The ancillary revenue associated with terminaling services include volumes of product throughput that exceed the contractually established minimum volumes,  injection fees based on the volume of product injected with additive compounds, heating and mixing of stored products, product transfer, railcar handling, butane blending, proceeds from the sale of product gains, wharfage and vapor recovery. The revenue generated by these services is primarily considered optional purchases to acquire additional services or variable consideration that is required to be estimated under ASC 606 for any uncertainty that is not resolved in the period of the service. We account for the majority of ancillary revenue at individual points in time when the services are delivered to the customer. Our ancillary revenue is recognized in accordance with ASC 606.

Pipeline transportation fees. We earn pipeline transportation fees at our Diamondback pipeline either based on the volume of product transported or under capacity reservation agreements. Revenue associated with the capacity reservation is recognized ratably over the respective term, regardless of whether the capacity is actually utilized. We earn pipeline transportation fees at our Razorback pipeline based on an allocation of the aggregate fees charged under the capacity agreement with our customer who has contracted for 100% of our Razorback system. For the six months ended June 30, 2018, pipeline transportation revenue is primarily accounted for in accordance with ASC 840.

Management fees. We manage and operate certain tank capacity at our Port Everglades South terminal for a major oil company and receive a reimbursement of its proportionate share of operating and maintenance costs. We manage and operate the Frontera joint venture and receive a management fee based on our costs incurred. We also currently manage and operate for an affiliate of PEMEX, Mexico’s state-owned petroleum company, a bi-directional products pipeline connected to our Brownsville terminal facility and receive a management fee. We manage and operate rail sites at certain Southeast terminals on behalf of a major oil company and receive reimbursement for operating and maintenance costs. Management fee revenue is recognized at individual points in time as the services are performed or as the costs are incurred and is primarily accounted for in accordance with ASC 606.

Cash and cash equivalents

(d) Cash and cash equivalents

We consider all short‑term investments with a remaining maturity of three months or less at the date of purchase to be cash equivalents.

Property, plant and equipment

(e) Property, plant and equipment

Depreciation is computed using the straight‑line method. Estimated useful lives are 15 to 25 years for terminals and pipelines and 3 to 25 years for furniture, fixtures and equipment. All items of property, plant and equipment are carried at cost. Expenditures that increase capacity or extend useful lives are capitalized. Repairs and maintenance are expensed as incurred.

We evaluate long‑lived assets for impairment whenever events or changes in circumstances indicate that the carrying value of an asset group may not be recoverable based on expected undiscounted future cash flows attributable to that asset group. If an asset group is impaired, the impairment loss to be recognized is the excess of the carrying amount of the asset group over its estimated fair value.

Investments in unconsolidated affiliates

(f) Investments in unconsolidated affiliates

We account for our investments in unconsolidated affiliates, which we do not control but do have the ability to exercise significant influence over, using the equity method of accounting. Under this method, the investment is recorded at acquisition cost, increased by our proportionate share of any earnings and additional capital contributions and decreased by our proportionate share of any losses, distributions received and amortization of any excess investment. Excess investment is the amount by which our total investment exceeds our proportionate share of the book value of the net assets of the investment entity. We evaluate our investments in unconsolidated affiliates for impairment whenever events or circumstances indicate there is a loss in value of the investment that is other than temporary. In the event of impairment, we would record a charge to earnings to adjust the carrying amount to estimated fair value.

Environmental obligations

(g) Environmental obligations

We accrue for environmental costs that relate to existing conditions caused by past operations when probable and reasonably estimable (see Note 10 of Notes to consolidated financial statements). Environmental costs include initial site surveys and environmental studies of potentially contaminated sites, costs for remediation and restoration of sites determined to be contaminated and ongoing monitoring costs, as well as fines, damages and other costs, including direct legal costs. Liabilities for environmental costs at a specific site are initially recorded, on an undiscounted basis, when it is probable that we will be liable for such costs, and a reasonable estimate of the associated costs can be made based on available information. Such an estimate includes our share of the liability for each specific site and the sharing of the amounts related to each site that will not be paid by other potentially responsible parties, based on enacted laws and adopted regulations and policies. Adjustments to initial estimates are recorded, from time to time, to reflect changing circumstances and estimates based upon additional information developed in subsequent periods. Estimates of our ultimate liabilities associated with environmental costs are difficult to make with certainty due to the number of variables involved, including the early stage of investigation at certain sites, the lengthy time frames required to complete remediation, technology changes, alternatives available and the evolving nature of environmental laws and regulations. We periodically file claims for insurance recoveries of certain environmental remediation costs with our insurance carriers under our comprehensive liability policies (see Note 5 of Notes to consolidated financial statements).

We recognize our insurance recoveries as a credit to income in the period that we assess the likelihood of recovery as being probable.

In connection with our previous acquisitions of certain terminals from TransMontaigne LLC, a wholly owned subsidiary of NGL Energy Partners LP and the previous owner of our general partner, TransMontaigne LLC agreed to indemnify us against certain potential environmental claims, losses and expenses at those terminals. Pursuant to the acquisition agreements for each of the Florida (except Pensacola) and Midwest terminals, the Southeast terminals, the Brownsville and the River terminals, and the Pensacola, Florida Terminal, TransMontaigne LLC is obligated to indemnify us against environmental claims, losses and expenses that were associated with the ownership or operation of the terminals prior to the purchase by the Partnership. In each acquisition agreement, TransMontaigne LLC’s maximum indemnification liability is subject to a specified time period for indemnification, cap on indemnification and satisfaction of a deductible amount before indemnification, in each case subject to certain exceptions, limitations and conditions specified therein. TransMontaigne LLC has no indemnification obligations with respect to environmental claims made as a result of additions to or modifications of environmental laws promulgated after certain specified dates.

The environmental indemnification obligations of TransMontaigne LLC to us remain in place and were not affected by ArcLight’s acquisition of our general partner on February 1, 2016.  

Asset retirement obligations

(h) Asset retirement obligations

Asset retirement obligations are legal obligations associated with the retirement of long‑lived assets that result from the acquisition, construction, development or normal use of the asset. Generally accepted accounting principles require that the fair value of a liability related to the retirement of long‑lived assets be recorded at the time a legal obligation is incurred. Once an asset retirement obligation is identified and a liability is recorded, a corresponding asset is recorded, which is depreciated over the remaining useful life of the asset. After the initial measurement, the liability is adjusted to reflect changes in the asset retirement obligation. If and when it is determined that a legal obligation has been incurred, the fair value of any liability is determined based on estimates and assumptions related to retirement costs, future inflation rates and interest rates. Our long‑lived assets consist of above‑ground storage facilities and underground pipelines. We are unable to predict if and when these long‑lived assets will become completely obsolete and require dismantlement. We have not recorded an asset retirement obligation, or corresponding asset, because the future dismantlement and removal dates of our long‑lived assets is indeterminable and the amount of any associated costs are believed to be insignificant. Changes in our assumptions and estimates may occur as a result of the passage of time and the occurrence of future events.

Equity based compensation

(i) Equity-based compensation

Generally accepted accounting principles require us to measure the cost of services received in exchange for an award of equity instruments based on the measurement‑date fair value of the award. That cost is recognized during the period services are provided in exchange for the award (see Note 14 of Notes to consolidated financial statements).

Accounting for derivative instruments

(j) Accounting for derivative instruments

Generally accepted accounting principles require us to recognize all derivative instruments at fair value in the consolidated balance sheets as assets or liabilities (see Notes 5 and 9 of Notes to consolidated financial statements). Changes in the fair value of our derivative instruments are recognized in earnings.

At June 30, 2018 and December 31, 2017, our derivative instruments were limited to interest rate swap agreements with an aggregate notional amount of $50.0 million and $125.0 million, respectively. At June 30, 2018 the remaining derivative instrument expires March 11, 2019. Pursuant to the terms of the interest rate swap agreements, we paid a blended fixed rate of approximately 0.97% and 1.01% for the six months ended June 30, 2018 and the year ended December 31, 2017, respectively, and received interest payments based on the one-month LIBOR. The net difference to be paid or received under the interest rate swap agreements is settled monthly and is recognized as an adjustment to interest expense. The fair value of our interest rate swap agreements are determined using a pricing model based on the LIBOR swap rate and other observable market data.

Income taxes

(k) Income taxes

No provision for U.S. federal income taxes has been reflected in the accompanying consolidated financial statements because we are treated as a partnership for federal income tax purposes. As a partnership, all income, gains, losses, expenses, deductions and tax credits generated by us flow through to our unitholders.

Net earnings per limited partner unit

(l) Net earnings per limited partner unit

Net earnings allocable to the limited partners, for purposes of calculating net earnings per limited partner unit, are calculated under the two-class method and accordingly are net of the earnings allocable to the general partner interest and distributions payable to any restricted phantom units granted under our equity-based compensation plans that participate in our distributions. The earnings allocable to the general partner interest include the distributions of available cash (as defined by our partnership agreement) attributable to the period to the general partner interest, net of adjustments for the general partner’s share of undistributed earnings, and the incentive distribution rights. Undistributed earnings are the difference between the earnings and the distributions attributable to the period. Undistributed earnings are allocated to the limited partners and general partner interest based on their respective sharing of earnings or losses specified in the partnership agreement, which is based on their ownership percentages of 98% and 2%, respectively. The incentive distribution rights are not allocated a portion of the undistributed earnings given they are not entitled to distributions other than from available cash. Further, the incentive distribution rights do not share in losses under our partnership agreement. Basic net earnings per limited partner unit is computed by dividing net earnings allocable to the limited partners by the weighted average number of limited partner units outstanding during the period. Diluted net earnings per limited partner unit is computed by dividing net earnings allocable to the limited partners by the weighted average number of limited partner units outstanding during the period and any potential dilutive securities outstanding during the period.

Comprehensive Income

(m)   Comprehensive income

Entities that report items of other comprehensive income have the option to present the components of net earnings and comprehensive income in either one continuous financial statement, or two consecutive financial statements. As the Partnership has no components of comprehensive income other than net earnings, no statement of comprehensive income has been presented.

Recent accounting pronouncements

(n) Recent accounting pronouncements

Effective January 1, 2018 we adopted ASU 2016-15, Statement of Cash Flows: Classification of Certain Cash Receipt and Cash Payments. This ASU requires changes in the presentation of certain items, including but not limited to debt prepayment or debt extinguishment costs; contingent consideration payments made after a business combination; proceeds from the settlement of insurance claims; proceeds from the settlement of corporate-owned life insurance policies and distributions received from equity method investees. The adoption of this ASU did not have a material impact on our unaudited consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02, Leases. The objective of this update is to improve financial reporting about leasing transactions. ASU 2016-02 is effective for annual reporting periods beginning after December 15, 2018, including interim periods within that reporting period. We are currently evaluating the potential impact that the adoption will have on our disclosures and financial statements. Additionally, we are in the process of evaluating and designing the necessary changes to our business processes and controls to support recognition and disclosure under the new standard. As part of our evaluation process we have established an implementation team and are in the process of implementing a third-party supported lease accounting system to facilitate the accounting and financial reporting requirements.

In January 2017, the FASB issued ASU 2017-04, Intangibles-Goodwill and Other: Simplifying the Test for Goodwill Impairment, to simplify the accounting for goodwill impairment by eliminating step 2 from the goodwill impairment test. ASU 2017-04 is effective for annual reporting periods beginning after December 15, 2019, including interim periods within that reporting period. We are currently evaluating the potential impact that the adoption will have on our disclosures and financial statements.

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BUSINESS COMBINATION AND TERMINAL ACQUISITION AND DISPOSITION (Tables)

6 Months Ended

Jun. 30, 2018

West Coast terminals

Schedule of purchase price and assessment of the fair value of the assets acquired and liabilities assumed

The purchase price and final assessment of the fair value of the assets acquired and liabilities assumed in the business combination were as follows (in thousands):

Other current assets	$	1,037
Property, plant and equipment		228,000
Goodwill		943
Customer relationships		47,000
Total assets acquired		276,980
Environmental obligation		220
Total liabilities assumed		220
Allocated purchase price	$	276,760

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CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE (Tables)

6 Months Ended

Jun. 30, 2018

CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE

Schedule of trade accounts receivable, net (in thousands)

Trade accounts receivable, net consists of the following (in thousands):

	June 30,		December 31,
	2018		2017
Trade accounts receivable	$	12,458	$	11,128
Less allowance for doubtful accounts		(294)		(111)
	$	12,164	$	11,017

Schedule of customer who accounted for at least 10% of consolidated revenue

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
NGL Energy Partners LP	23	%	27	%	23	%	26	%
RaceTrac Petroleum Inc.	12	%	13	%	12	%	12	%
Castleton Commodities International LLC	9	%	13	%	10	%	13	%

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OTHER CURRENT ASSETS (Tables)

6 Months Ended

Jun. 30, 2018

OTHER CURRENT ASSETS

Schedule of other current assets (in thousands)

Other current assets are as follows (in thousands):

	June 30,		December 31,
	2018		2017
Prepaid insurance	$	2,761	$	4,151
Amounts due from insurance companies		1,755		1,981
Additive detergent		1,216		1,715
Unrealized gain on derivative instrument		449		—
Deposits and other assets		1,797		12,807
	$	7,978	$	20,654

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PROPERTY, PLANT AND EQUIPMENT, NET (Tables)

6 Months Ended

Jun. 30, 2018

PROPERTY, PLANT AND EQUIPMENT, NET

Schedule of property, plant and equipment, net (in thousands)

Property, plant and equipment, net is as follows (in thousands):

	June 30,		December 31,
	2018		2017
Land	$	83,451	$	83,310
Terminals, pipelines and equipment		912,245		885,429
Furniture, fixtures and equipment		4,860		4,430
Construction in progress		19,481		21,575
		1,020,037		994,744
Less accumulated depreciation		(363,276)		(339,691)
	$	656,761	$	655,053

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GOODWILL (Tables)

6 Months Ended

Jun. 30, 2018

GOODWILL

Schedule of goodwill (in thousands)

Goodwill is as follows (in thousands):

	June 30,		December 31,
	2018		2017
Brownsville terminals	$	8,485	$	8,485
West Coast terminals		943		943
	$	9,428	$	9,428

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INVESTMENTS IN UNCONSOLIDATED AFFILIATES (Tables)

6 Months Ended

Jun. 30, 2018

INVESTMENTS IN UNCONSOLIDATED AFFILIATES

Summary of investments in unconsolidated affiliates

The following table summarizes our investments in unconsolidated affiliates:

	Percentage of				Carrying value
	ownership				(in thousands)
	June 30,		December 31,		June 30,		December 31,
	2018		2017		2018		2017
BOSTCO	42.5	%	42.5	%	$	207,627	$	209,373
Frontera	50	%	50	%		24,140		23,808
Total investments in unconsolidated affiliates					$	231,767	$	233,181

Schedule of earnings from investments in unconsolidated affiliates (in thousands)

Earnings from investments in unconsolidated affiliates was as follows (in thousands):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
BOSTCO	$	1,848	$	1,275	$	3,839	$	2,981
Frontera		596		845		1,494		1,699
Total earnings from investments in unconsolidated affiliates	$	2,444	$	2,120	$	5,333	$	4,680

Schedule of additional capital investments in unconsolidated affiliates (in thousands)

Additional capital investments in unconsolidated affiliates was as follows (in thousands):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
BOSTCO	$	—	$	145	$	—	$	145
Frontera		114		—		1,264		2,000
Additional capital investments in unconsolidated affiliates	$	114	$	145	$	1,264	$	2,145

Schedule of cash distributions received from unconsolidated affiliates (in thousands)

Cash distributions received from unconsolidated affiliates was as follows (in thousands):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
BOSTCO	$	3,491	$	3,319	$	5,585	$	6,398
Frontera		1,330		1,227		2,426		2,497
Cash distributions received from unconsolidated affiliates	$	4,821	$	4,546	$	8,011	$	8,895

Summary of financial information of unconsolidated affiliates (in thousands)

The summarized financial information of our unconsolidated affiliates is as follows (in thousands):

Balance sheets:

	BOSTCO				Frontera
	June 30,		December 31,		June 30,		December 31,
	2018		2017		2018		2017
Current assets	$	20,794	$	24,976	$	5,720	$	5,649
Long-term assets		460,308		469,348		44,613		44,292
Current liabilities		(7,590)		(17,550)		(1,922)		(2,147)
Long-term liabilities		(1,314)		—		(131)		(178)
Net assets	$	472,198	$	476,774	$	48,280	$	47,616

Statements of operations:

	BOSTCO				Frontera
	Three months ended				Three months ended
	June 30,				June 30,
	2018		2017		2018		2017
Revenue	$	16,908	$	17,028	$	6,009	$	5,198
Expenses		(11,515)		(13,628)		(4,817)		(3,508)
Net earnings	$	5,393	$	3,400	$	1,192	$	1,690

	BOSTCO				Frontera
	Six months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
Revenue	$	33,735	$	33,658	$	11,921	$	10,591
Expenses		(24,064)		(25,866)		(8,933)		(7,193)
Net earnings	$	9,671	$	7,792	$	2,988	$	3,398

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OTHER ASSETS, NET (Tables)

6 Months Ended

Jun. 30, 2018

OTHER ASSETS, NET

Schedule of other assets, net (in thousands)

Other assets, net are as follows (in thousands):

	June 30,		December 31,
	2018		2017
Customer relationships, net of accumulated amortization of $3,679 and $2,294, respectively	$	45,751	$	47,136
Revolving credit facility unamortized deferred issuance costs, net of accumulated amortization of $6,807 and $5,984, respectively		6,364		6,778
Amounts due under long-term terminaling services agreements		439		460
Unrealized gain on derivative instruments		—		576
Deposits and other assets		289		288
	$	52,843	$	55,238

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ACCRUED LIABILITIES (Tables)

6 Months Ended

Jun. 30, 2018

ACCRUED LIABILITIES

Schedule of accrued liabilities (in thousands)

Accrued liabilities are as follows (in thousands):

	June 30,		December 31,
	2018		2017
Customer advances and deposits	$	8,540	$	10,265
Accrued property taxes		4,277		1,381
Accrued environmental obligations		1,836		1,855
Interest payable		7,960		982
Accrued expenses and other		4,063		2,943
	$	26,676	$	17,426

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OTHER LIABILITIES (Tables)

6 Months Ended

Jun. 30, 2018

OTHER LIABILITIES

Schedule of other liabilities (in thousands)

Other liabilities are as follows (in thousands):

	June 30,		December 31,
	2018		2017
Advance payments received under long-term terminaling services agreements	$	1,782	$	1,599
Deferred revenue—ethanol blending fees and other projects		1,755		2,034
	$	3,537	$	3,633

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LONG-TERM DEBT (Tables)

6 Months Ended

Jun. 30, 2018

LONG-TERM DEBT

Summary of long term debt

Long-term debt is as follows (in thousands):

	June 30,		December 31,
	2018		2017
Revolving credit facility due in 2022	$	286,300	$	593,200
6.125% senior notes due in 2026		300,000		—
Senior notes unamortized deferred issuance costs, net of accumulated amortization of $301 and $nil, respectively		(7,777)		—
	$	578,523	$	593,200

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PARTNERS' EQUITY (Tables)

6 Months Ended

Jun. 30, 2018

PARTNERS' EQUITY

Schedule of number of units outstanding

		General
	Common	partner
	units	equivalent units
Units outstanding at December 31, 2017	16,177,353	330,150
Issuance of common units pursuant to our savings and retention program	44,798	—
Contribution of cash by TransMontaigne GP to maintain its 2% general partner interest	—	905
Units outstanding at June 30, 2018	16,222,151	331,055

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EQUITY-BASED COMPENSATION (Tables)

6 Months Ended

Jun. 30, 2018

TransMontaigne LLC-related party

Schedule of long-term incentive plan activity

		Weighted			Weighted
		average			average
	Vested	price		Unvested	price
Restricted phantom units outstanding at December 31, 2017	91,877	$	38.91	54,244	$	38.81
Issuance of units	(44,798)	$	37.75	—	$	—
Units withheld for settlement of withholding taxes	(16,822)	$	37.59	—	$	—
Unit accrual for distributions paid	3,371	$	37.53	2,447	$	37.56
Vesting of units	18,970	$	36.61	(18,970)	$	36.61
Grant of units	46,362	$	35.23	33,097	$	35.23
Forfeiture of units	—	$	—	(809)	$	35.23
Restricted phantom units outstanding at June 30, 2018	98,960	$	38.52	70,009	$	38.22
Vested and expected to vest at June 30, 2018	168,969	$	38.40

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NET EARNINGS PER LIMITED PARTNER UNIT (Tables)

6 Months Ended

Jun. 30, 2018

NET EARNINGS PER LIMITED PARTNER UNIT

Schedule of reconciliation of net earnings to net earnings allocable to limited partners (in thousands)

The following table reconciles net earnings to net earnings allocable to limited partners and sets forth the computation of basic and diluted net earnings per limited partner unit (in thousands, except per unit amounts):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
Net earnings	$	9,460	$	14,478	$	21,634	$	27,432
Less:
Distributions payable on behalf of incentive distribution rights		(3,758)		(2,873)		(7,353)		(5,509)
Distributions payable on behalf of general partner interest		(263)		(244)		(522)		(483)
Earnings allocable to general partner interest less than distributions payable to general partner interest		149		12		237		44
Earnings allocable to general partner interest including incentive distribution rights		(3,872)		(3,105)		(7,638)		(5,948)
Net earnings allocable to limited partners per the consolidated statements of operations	$	5,588	$	11,373	$	13,996	$	21,484
Basic weighted average units		16,327		16,260		16,310		16,253
Diluted weighted average units		16,356		16,279		16,345		16,271
Net earnings per limited partner unit—basic	$	0.34	$	0.70	$	0.86	$	1.32
Net earnings per limited partner unit—diluted	$	0.34	$	0.70	$	0.86	$	1.32

Schedule of distribution declared per common unit attributable to the periods

	Distribution
January 1, 2017 through March 31, 2017	$	0.725
April 1, 2017 through June 30, 2017	$	0.740
July 1, 2017 through September 30, 2017	$	0.755
October 1, 2017 through December 31, 2017	$	0.770
January 1, 2018 through March 31, 2018	$	0.785
April 1, 2018 through June 30, 2018	$	0.795

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COMMITMENTS AND CONTINGENCIES (Tables)

6 Months Ended

Jun. 30, 2018

COMMITMENTS AND CONTINGENCIES

Schedule of future minimum lease payments under non-cancelable operating leases (in thousands)

At June 30, 2018, future minimum lease payments under these non‑cancelable operating leases are as follows (in thousands):

Years ending December 31:
2018 (remainder of the year)	$	1,534
2019		3,409
2020		2,047
2021		1,929
2022		978
Thereafter		4,276
	$	14,173

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REVENUE FROM CONTRACTS WITH CUSTOMERS (Tables)

6 Months Ended

Jun. 30, 2018

REVENUE FROM CONTRACTS WITH CUSTOMERS

Revenue disaggregated by category

The following table provides details of our revenue disaggregated by category of revenue (in thousands):    

	Three months ended		Six months ended
	June 30,		June 30,
	2018		2018
Terminaling services fees:
Firm commitments (ASC 840 revenue)	$	39,149	$	77,855
Firm commitments (ASC 606 revenue)		3,549		6,976
Total firm commitments revenue		42,698		84,831
Ancillary revenue (ASC 606 revenue)		9,680		20,738
Total terminaling services fees		52,378		105,569
Pipeline transportation fees (ASC 840 revenue)		794		1,663
Management fees (ASC 606 revenue)		2,172		4,556
Total revenue	$	55,344	$	111,788

Schedule of estimated future ASC 606 revenue by segment

			Midwest
			Terminals and
	Gulf Coast		Pipeline			Brownsville		River		Southeast		West Coast
	Terminals		System			Terminals		Terminals		Terminals		Terminals		Total
Remainder of 2018	$	2,060	$	—	$	—	$	578	$	—	$	3,040	$	5,678
2019		721		—		—		1,039		—		1,594		3,354
2020		—		—		—		1,039		—		125		1,164
2021		—		—		—		519		—		—		519
Thereafter		—		—		—		—		—		—		—
Total estimated ASC 606 revenue	$	2,781	$	—	$	—	$	3,175	$	—	$	4,759	$	10,715

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BUSINESS SEGMENTS (Tables)

6 Months Ended

Jun. 30, 2018

BUSINESS SEGMENTS

Schedule of information related to financial performance of business segments (in thousands)

The financial performance of our business segments is as follows (in thousands):

	Three months ended				Six months ended
	June 30,				June 30,
	2018		2017		2018		2017
Gulf Coast Terminals:
Terminaling services fees	$	16,465	$	15,533	$	32,638	$	31,540
Management fees		86		263		183		546
Revenue		16,551		15,796		32,821		32,086
Direct operating costs and expenses		(5,413)		(5,426)		(11,245)		(10,980)
Net margins		11,138		10,370		21,576		21,106
Midwest Terminals and Pipeline System:
Terminaling services fees		2,405		2,465		4,824		4,868
Pipeline transportation fees		433		433		866		866
Revenue		2,838		2,898		5,690		5,734
Direct operating costs and expenses		(743)		(693)		(1,455)		(1,405)
Net margins		2,095		2,205		4,235		4,329
Brownsville Terminals:
Terminaling services fees		1,977		2,505		4,043		4,972
Pipeline transportation fees		361		1,363		797		2,646
Management fees		1,892		1,614		3,996		3,538
Revenue		4,230		5,482		8,836		11,156
Direct operating costs and expenses		(2,135)		(2,582)		(4,176)		(5,454)
Net margins		2,095		2,900		4,660		5,702
River Terminals:
Terminaling services fees		2,589		2,740		5,343		5,410
Revenue		2,589		2,740		5,343		5,410
Direct operating costs and expenses		(1,805)		(1,535)		(3,641)		(3,185)
Net margins		784		1,205		1,702		2,225
Southeast Terminals:
Terminaling services fees		19,510		18,263		39,749		35,460
Management fees		194		185		377		368
Revenue		19,704		18,448		40,126		35,828
Direct operating costs and expenses		(5,714)		(5,748)		(12,333)		(11,471)
Net margins		13,990		12,700		27,793		24,357
West Coast Terminals:
Terminaling services fees		9,432		—		18,972		—
Revenue		9,432		—		18,972		—
Direct operating costs and expenses		(3,465)		—		(6,570)		—
Net margins		5,967		—		12,402		—
Total net margins		36,069		29,380		72,368		57,719
General and administrative expenses		(4,619)		(4,080)		(9,600)		(8,051)
Insurance expenses		(1,271)		(1,002)		(2,517)		(2,008)
Equity-based compensation expense		(441)		(352)		(2,458)		(2,169)
Depreciation and amortization		(13,160)		(8,792)		(24,968)		(17,497)
Earnings from unconsolidated affiliates		2,444		2,120		5,333		4,680
Operating income		19,022		17,274		38,158		32,674
Other expenses		(9,562)		(2,796)		(16,524)		(5,242)
Net earnings	$	9,460	$	14,478	$	21,634	$	27,432

Schedule of supplemental information about consolidated business segments (in thousands)

Supplemental information about our business segments is summarized below (in thousands):

	Three months ended June 30, 2018
			Midwest
			Terminals and
	Gulf Coast		Pipeline		Brownsville		River		Southeast		West Coast
	Terminals		System		Terminals		Terminals		Terminals		Terminals		Total
Revenue:
External customers	$	14,480	$	2,838	$	2,336	$	2,589	$	19,704	$	9,432	$	51,379
Frontera		—		—		1,894		—		—		—		1,894
Associated Asphalt, LLC		2,071		—		—		—		—		—		2,071
Revenue	$	16,551	$	2,838	$	4,230	$	2,589	$	19,704	$	9,432	$	55,344
Capital expenditures	$	1,814	$	35	$	2,024	$	345	$	9,152	$	2,082	$	15,452
Identifiable assets	$	122,011	$	20,488	$	42,507	$	48,710	$	221,539	$	274,479	$	729,734
Cash and cash equivalents														390
Investments in unconsolidated affiliates														231,767
Deferred issuance costs														6,364
Other														6,567
Total assets													$	974,822

	Three months ended June 30, 2017
			Midwest
			Terminals and
	Gulf Coast		Pipeline		Brownsville		River		Southeast		West Coast
	Terminals		System		Terminals		Terminals		Terminals		Terminals		Total
Revenue:
External customers	$	15,796	$	2,898	$	3,968	$	2,740	$	18,448	$	—	$	43,850
Frontera		—		—		1,514		—		—		—		1,514
Revenue	$	15,796	$	2,898	$	5,482	$	2,740	$	18,448	$	—	$	45,364
Capital expenditures	$	1,059	$	45	$	228	$	652	$	17,161	$	—	$	19,145

	Six months ended June 30, 2018
			Midwest
			Terminals and
	Gulf Coast		Pipeline		Brownsville		River		Southeast		West Coast
	Terminals		System		Terminals		Terminals		Terminals		Terminals		Total
Revenue:
External customers	$	28,538	$	5,690	$	4,824	$	5,343	$	40,126	$	18,972	$	103,493
Frontera		—		—		4,012		—		—		—		4,012
Associated Asphalt, LLC		4,283		—		—		—		—		—		4,283
Revenue	$	32,821	$	5,690	$	8,836	$	5,343	$	40,126	$	18,972	$	111,788
Capital expenditures	$	3,180	$	336	$	2,467	$	892	$	12,435	$	2,645	$	21,955

	Six months ended June 30, 2017
			Midwest
			Terminals and
	Gulf Coast		Pipeline		Brownsville		River		Southeast		West Coast
	Terminals		System		Terminals		Terminals		Terminals		Terminals		Total
Revenue:
External customers	$	32,086	$	5,734	$	7,872	$	5,410	$	35,828	$	—	$	86,930
Frontera		—		—		3,284		—		—		—		3,284
Revenue	$	32,086	$	5,734	$	11,156	$	5,410	$	35,828	$	—	$	90,214
Capital expenditures	$	2,586	$	267	$	372	$	1,046	$	24,374	$	—	$	28,645

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Property (Details)	6 Months Ended
	Jun. 30, 2018
Terminals and pipelines | Minimum
Property, plant and equipment
Estimated useful lives	15 years
Terminals and pipelines | Maximum
Property, plant and equipment
Estimated useful lives	25 years
Furniture, fixtures and equipment | Minimum
Property, plant and equipment
Estimated useful lives	3 years
Furniture, fixtures and equipment | Maximum
Property, plant and equipment
Estimated useful lives	25 years

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Taxes and Derivatives (Details) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Income taxes
Provision for U.S. federal income taxes	$ 0.0
Net earnings per limited partner unit
Limited partner interest (as a percent)	98.00%
General partner interest (as a percent)	2.00%	2.00%
Interest rate swap
Accounting for derivative instruments
Notional amount	$ 50.0	$ 125.0
Fixed interest rate paid (as a percent)	0.97%	1.01%

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TRANSACTIONS WITH AFFILIATES (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended		12 Months Ended
	May 13, 2018	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2018	Dec. 31, 2017
Transactions with affiliates
Insurance expense paid		$ 1,271	$ 1,002	$ 2,517	$ 2,008
Expense of insurance		4,619	4,080	9,600	8,051
Insurance expenses		1,271	1,002	$ 2,517	2,008
Omnibus agreement
Transactions with affiliates
Increase in administrative fee, (as a percent)				2.00%
Notice period for termination of service agreement				24 months
Omnibus agreement | Second amended and restated omnibus agreement
Transactions with affiliates
Administrative fee paid							$ 13,700
Omnibus agreement | Third amended and restated omnibus agreement
Transactions with affiliates
Administrative fee paid		$ 2,700	$ 3,200	$ 6,100	$ 6,100
Increase in administrative fee	$ 3,600
Omnibus agreement | Forecast | Third amended and restated omnibus agreement
Transactions with affiliates
Administrative fee paid						$ 8,400
Cost of Engineering and ESOH Groups						$ 8,900

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TRANSACTIONS WITH AFFILIATES - Agreements (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018 USD ($)	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) bbl	Jun. 30, 2017 USD ($)
June 2019 terminaling services agreement-Brownsville LLC | Frontera | Brownsville terminals
Transactions with affiliates
Notice period for termination of service agreement			90 days
Storage capacity agreed to be provided (in barrels) | bbl			301,000
Throughput revenue	$ 0.6	$ 0.4	$ 1.2	$ 0.8
June 2020 terminaling services agreement-Brownsville LLC | Frontera | Brownsville terminals
Transactions with affiliates
Notice period for termination of service agreement			180 days
Operations and reimbursement agreement-Frontera | Frontera
Transactions with affiliates
Ownership interest in joint venture (as a percent)	50.00%		50.00%
Revenue recognized	$ 1.3	1.1	$ 2.8	2.5
Terminaling services agreement- Gulf Coast Terminals | Associated Asphalt Marketing, LLC | Gulf Coast Terminals
Transactions with affiliates
Automatic renewal period of service agreement			2 years
Notice period for termination of service agreement			180 days
Storage capacity agreed to be provided (in barrels) | bbl			750,000
Throughput revenue	$ 2.1	$ 0.0	$ 4.3	$ 0.0

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BUSINESS COMBINATION AND TERMINAL ACQUISITION AND DISPOSITION - Business Combinations (Details) $ in Thousands, bbl in Millions	Dec. 15, 2017 USD ($) item bbl	Jun. 30, 2018 USD ($)	Dec. 31, 2017 USD ($)
Final purchase price and assessment of the fair value of the assets acquired and liabilities assumed in the business combination
Goodwill		$ 9,428	$ 9,428
West Coast terminals
Business Acquisition [Line Items]
Total purchase price	$ 276,800
Number of terminals | item	2
Number of storage tanks | item	64
Storage capacity (in barrels) | bbl	5.0
Final purchase price and assessment of the fair value of the assets acquired and liabilities assumed in the business combination
Other current assets	$ 1,037
Property, plant and equipment, net	228,000
Goodwill	943
Customer relationships	47,000
Total assets acquired	276,980
Environmental obligation	220
Total liabilities assumed	220
Allocated purchase price	$ 276,760

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CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Concentration of credit risk and trade accounts receivable
Contract revenue	$ 3,500		$ 3,500
Trade accounts receivable	12,458		12,458		$ 11,128
Less allowance for doubtful accounts	(294)		(294)		(111)
Trade accounts receivable, net	$ 12,164		$ 12,164		$ 11,017
NGL Energy Partners LP
Concentration of credit risk and trade accounts receivable
Percentage of total revenue generated by major customer	23.00%	27.00%	23.00%	26.00%
Castleton Commodities International LLC
Concentration of credit risk and trade accounts receivable
Percentage of total revenue generated by major customer	9.00%	13.00%	10.00%	13.00%
RaceTrac Petroleum Inc
Concentration of credit risk and trade accounts receivable
Percentage of total revenue generated by major customer	12.00%	13.00%	12.00%	12.00%

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OTHER CURRENT ASSETS (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended
	Dec. 31, 2017	Jun. 30, 2018
OTHER CURRENT ASSETS
Prepaid insurance	$ 4,151	$ 2,761
Amounts due from insurance companies	1,981	1,755
Additive detergent	1,715	1,216
Unrealized gain on derivative instrument		449
Deposits and other assets	12,807	1,797
Other current assets	20,654	7,978
Reimbursements from insurance companies		$ 200
Deposits paid	$ 10,200

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PROPERTY, PLANT AND EQUIPMENT, NET (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Property, plant and equipment, net
Property, plant and equipment, gross	$ 1,020,037	$ 994,744
Less accumulated depreciation	(363,276)	(339,691)
Property, plant and equipment, net	656,761	655,053
Land
Property, plant and equipment, net
Property, plant and equipment, gross	83,451	83,310
Terminals, pipelines and equipment
Property, plant and equipment, net
Property, plant and equipment, gross	912,245	885,429
Furniture, fixtures and equipment
Property, plant and equipment, net
Property, plant and equipment, gross	4,860	4,430
Construction in progress
Property, plant and equipment, net
Property, plant and equipment, gross	$ 19,481	$ 21,575

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GOODWILL (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Goodwill
Goodwill	$ 9,428	$ 9,428
Brownsville terminals
Goodwill
Goodwill	8,485	8,485
West Coast terminals
Goodwill
Goodwill	943	943
West Coast and Brownsville Terminals
Goodwill
Impairment charges	$ 0	$ 0

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INVESTMENTS IN UNCONSOLIDATED AFFILIATES (Details) $ in Thousands, bbl in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018 USD ($)	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) bbl	Jun. 30, 2017 USD ($)	Dec. 31, 2017 USD ($)
INVESTMENTS IN UNCONSOLIDATED AFFILIATES
Carrying value of investments in unconsolidated affiliates	$ 231,767		$ 231,767		$ 233,181
Earnings from unconsolidated affiliates	2,444	$ 2,120	5,333	$ 4,680
Additional capital investments in unconsolidated affiliates	114	145	1,264	2,145
Cash distributions received from unconsolidated affiliates	$ 4,821	4,546	$ 8,011	8,895
BOSTCO
INVESTMENTS IN UNCONSOLIDATED AFFILIATES
Storage capacity | bbl			7.1
Percentage of ownership	42.50%		42.50%		42.50%
Carrying value of investments in unconsolidated affiliates	$ 207,627		$ 207,627		$ 209,373
Excess investment	6,900		6,900		7,000
Earnings from unconsolidated affiliates	1,848	1,275	3,839	2,981
Additional capital investments in unconsolidated affiliates		145		145
Cash distributions received from unconsolidated affiliates	3,491	3,319	5,585	6,398
Balance sheets:
Current assets	20,794		20,794		24,976
Long-term assets	460,308		460,308		469,348
Current liabilities	(7,590)		(7,590)		(17,550)
Long-term liabilities	(1,314)		(1,314)
Net assets	472,198		472,198		$ 476,774
Statements of comprehensive income (loss):
Revenue	16,908	17,028	33,735	33,658
Expenses	(11,515)	(13,628)	(24,064)	(25,866)
Net earnings	$ 5,393	3,400	$ 9,671	7,792
Frontera
INVESTMENTS IN UNCONSOLIDATED AFFILIATES
Storage capacity | bbl			1.7
Percentage of ownership	50.00%		50.00%		50.00%
Carrying value of investments in unconsolidated affiliates	$ 24,140		$ 24,140		$ 23,808
Earnings from unconsolidated affiliates	596	845	1,494	1,699
Additional capital investments in unconsolidated affiliates	114		1,264	2,000
Cash distributions received from unconsolidated affiliates	1,330	1,227	2,426	2,497
Balance sheets:
Current assets	5,720		5,720		5,649
Long-term assets	44,613		44,613		44,292
Current liabilities	(1,922)		(1,922)		(2,147)
Long-term liabilities	(131)		(131)		(178)
Net assets	48,280		48,280		$ 47,616
Statements of comprehensive income (loss):
Revenue	6,009	5,198	11,921	10,591
Expenses	(4,817)	(3,508)	(8,933)	(7,193)
Net earnings	$ 1,192	$ 1,690	$ 2,988	$ 3,398
Class A Member Ownership Interest | BOSTCO
INVESTMENTS IN UNCONSOLIDATED AFFILIATES
Cash distributions, allocation percentage			96.50%
Class B Member Ownership Interest | BOSTCO
INVESTMENTS IN UNCONSOLIDATED AFFILIATES
Cash distributions, allocation percentage			3.50%

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OTHER ASSETS, NET (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
OTHER ASSETS, NET
Customer relationships, net of accumulated amortization of $3,679 and $2,294, respectively	$ 45,751	$ 47,136
Revolving credit facility unamortized deferred issuance costs, net of accumulated amortization of $6,807 and $5,984, respectively	6,364	6,778
Amounts due under long-term terminaling services agreements	439	460
Unrealized gain on derivative instruments		576
Deposits and other assets	289	288
Other assets, net	52,843	55,238
Accumulated amortization of customer relationships	3,679	2,294
Accumulated amortization of deferred financing costs	$ 6,807	$ 5,984
Amortization period of customer relationships	20 years

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ACCRUED LIABILITIES (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
ACCRUED LIABILITIES
Customer advances and deposits	$ 8,540	$ 10,265
Accrued property taxes	4,277	1,381
Accrued environmental obligations	1,836	1,855
Interest payable	7,960	982
Accrued expenses and other	4,063	2,943
Accrued liabilities	26,676	$ 17,426
Contract liabilities	400
Revenue recognized from contract liabilities	500
Increase in remediation obligations due to change in estimate	200
Accrued environmental obligations
Payments	$ 200

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OTHER LIABILITIES (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
OTHER LIABILITIES
Advance payments received under long-term terminaling services agreements	$ 1,782		$ 1,599
Deferred revenue-ethanol blending fees and other projects	1,755		2,034
Other liabilities	3,537		$ 3,633
Completed projects billed	900
Recognized revenue on a straight line basis for completed projects	1,200	$ 300
Contract liabilities	0
Revenue recognized from contract liabilities	$ 200

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LONG-TERM DEBT (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2018 USD ($)	Jun. 30, 2017	Feb. 12, 2018 USD ($)	Dec. 31, 2017 USD ($)
Long-term debt
Senior notes unamortized deferred issuance costs, net of accumulated amortization of $301 and $nil, respectively	$ (7,777)
Total long-term debt	578,523			$ 593,200
Accumulated amortization	$ 301			0
TLP Finance Corp
Long-term debt
Ownership interest in subsidiary (as a percent)	100.00%
TransMontaigne Operating Company L.P
Long-term debt
Ownership interest in subsidiary (as a percent)	100.00%
Amount of independent assets	$ 0
Amount of independent operations	0
Restricted net assets	0
6.125% senior notes due in 2026
Long-term debt
Total long-term debt	$ 300,000
Interest (as percent)			6.125%
Sale of senior notes			$ 300,000
Credit facility
Long-term debt
Weighted average interest rate on borrowings (as a percent)	4.70%	3.40%
Outstanding borrowings under credit facility	$ 286,300			593,200
Outstanding borrowings under letters of credit	$ 400			400
Credit facility | Minimum
Long-term debt
Commitment fee on unused amount of commitments (as a percent)	0.375%
Credit facility | Minimum | LIBOR
Long-term debt
Margin interest above reference rate (as a percent)	1.75%
Credit facility | Minimum | Base Rate
Long-term debt
Margin interest above reference rate (as a percent)	0.75%
Credit facility | Maximum
Long-term debt
Commitment fee on unused amount of commitments (as a percent)	0.50%
Credit facility | Maximum | LIBOR
Long-term debt
Margin interest above reference rate (as a percent)	2.75%
Credit facility | Maximum | Base Rate
Long-term debt
Margin interest above reference rate (as a percent)	1.75%
Revolving credit facility due March 13, 2022
Long-term debt
Total long-term debt	$ 286,300			$ 593,200
Maximum borrowing capacity	$ 850,000
Other investments as a percentage of consolidated net tangible assets	5.00%
Permitted JV investments subject to liquidity	$ 175,000
Revolving credit facility due March 13, 2022 | Maximum
Long-term debt
Leverage ratio	5.25
Senior secured leverage ratio	3.75
Interest coverage ratio	2.75

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PARTNERS' EQUITY (Details) - shares	6 Months Ended	12 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Changes in number of units outstanding
Issuance of common units pursuant to our savings and retention program (in units)		33,205
General partner interest (as a percent)	2.00%	2.00%
Partners' Capital Account, Units, Treasury Units Reissued		6,498
Common units
Changes in number of units outstanding
Units outstanding at the beginning of the period	16,177,353
Issuance of common units pursuant to our savings and retention program (in units)	44,798
Units outstanding at the end of the period	16,222,151	16,177,353
General partner interest
Changes in number of units outstanding
Units outstanding at the beginning of the period	330,150
Contribution of cash by TransMontaigne GP to maintain its 2% general partner interest	905
Units outstanding at the end of the period	331,055	330,150

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EQUITY-BASED COMPENSATION (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Additional disclosures
Equity-based compensation	$ 441,000	$ 352,000	$ 2,458,000	$ 2,169,000
TLP Management Services LLC
Additional disclosures
Equity-based compensation			$ 2,300,000	2,000,000
Restricted phantom units | TransMontaigne LLC-related party
Incentive plan activity
Units, unvested, outstanding at the beginning of the period			54,244
Unit accrual for distributions paid (in units)			2,447
Vesting (in units)			(18,970)
Grant (in units)			46,362
Units, unvested, outstanding at the end of the period	70,009		70,009
Outstanding at the beginning of the period (in dollars per unit)			$ 38.81
Units accrual for distributions paid (in dollars per unit)			37.56
Vesting (in dollars per unit)			36.61
Grant (in dollars per unit)			35.23
Outstanding at the end of the period (in dollars per unit)	$ 38.22		$ 38.22
Units outstanding at the beginning of the period (in units)			91,877
Issuance (in units)			(44,798)
Units withheld for settlement of withholding taxes (in units)			(16,822)
Unit accrual for distributions (in units)			3,371
Vesting (in units)			18,970
Grant (in units)			33,097.00
Forfeited (in units)			(809)
Units outstanding at the end of the period (in units)	98,960		98,960
Vested and expected to vest (in units)	168,969		168,969
Outstanding at the beginning of the period (in dollars per unit)			$ 38.91
Issuance (in dollars per unit)			37.75
Units withheld for settlement of withholding taxes (in dollars)			37.59
Unit accrual for distributions paid (in dollars per unit)			37.53
Vesting (in dollars per unit)			36.61
Grant (in dollars per unit)			35.23
Forfeited (in dollars per unit)			35.23
Outstanding at the end of the period (in dollars per unit)	$ 38.52		38.52
Vested and expected to vest (in dollars per unit)	$ 38.40		$ 38.40
Restricted phantom units | TLP Management Services LLC
Additional disclosures
Nonemployee service, unrecognized equity-based compensation expense	$ 1,900,000		$ 1,900,000
Expected term (in years)			1 year 8 months 23 days
Vesting (as a percent)			50.00%
Restricted phantom units | TLP Management Services LLC | Tranche One
Additional disclosures
Earlier vesting, age threshold (in years)			60 years
Restricted phantom units | TLP Management Services LLC | Tranche Two
Additional disclosures
Earlier vesting, age threshold (in years)			55 years
Earlier vesting, length of service threshold (in years)			10 years
Restricted phantom units | TLP Management Services LLC | Tranche Three
Additional disclosures
Earlier vesting, age threshold (in years)			50 years
Earlier vesting, length of service threshold (in years)			20 years
Long-term incentive plan
Long-term incentive plan
Authorized units	750,000		750,000
Additional disclosures
Equity-based compensation			$ 140,000	$ 140,000
Long-term incentive plan | Common units | TLP Management Services LLC
Incentive plan activity
Outstanding at the end of the period (in dollars per unit)	$ 0		$ 0

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NET EARNINGS PER LIMITED PARTNER UNIT (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended						6 Months Ended		12 Months Ended
	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
NET EARNINGS PER LIMITED PARTNER UNIT
Net earnings	$ 9,460				$ 14,478		$ 21,634	$ 27,432	$ 48,493
Less:
Distributions payable on behalf of incentive distribution rights	(3,758)				(2,873)		(7,353)	(5,509)
Distributions payable on behalf of general partner interest	(263)				(244)		(522)	(483)
Earnings allocable to general partner interest less than distributions payable to general partner interest	149				12		237	44
Earnings allocable to general partner interest including incentive distribution rights	(3,872)				(3,105)		(7,638)	(5,948)
Net earnings allocable to limited partners	$ 5,588				$ 11,373		$ 13,996	$ 21,484
Basic weighted average units	16,327				16,260		16,310	16,253
Diluted weighted average units	16,356				16,279		16,345	16,271
Net earnings per limited partner unit-basic (in dollars per unit)	$ 0.34				$ 0.70		$ 0.86	$ 1.32
Net earnings per limited partner unit-diluted (in dollars per unit)	0.34				0.70		$ 0.86	$ 1.32
Period for declaration of distribution, maximum							45 days
Distribution declared per common unit (in dollars per unit)	$ 0.795	$ 0.785	$ 0.770	$ 0.755	$ 0.740	$ 0.725

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COMMITMENTS AND CONTINGENCIES (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
COMMITMENTS AND CONTINGENCIES
Contractual commitments for supply of services, labor and materials	$ 38,000		$ 38,000
Future minimum lease payments under non-cancelable operating leases
2018 (remainder of the year)	1,534		1,534
2019	3,409		3,409
2020	2,047		2,047
2021	1,929		1,929
2022	978		978
Thereafter	4,276		4,276
Total	14,173		14,173
Expected minimum sublease rentals to be received	7,800		7,800
Rental expense under operating leases	$ 500	$ 900	$ 1,000	$ 1,700

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REVENUE FROM CONTRACTS WITH CUSTOMERS - Disaggregated (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Disaggregation of Revenue [Line Items]
Total revenue	$ 55,344	$ 45,364	$ 111,788	$ 90,214
Firm commitments (ASC 840 revenue)
Disaggregation of Revenue [Line Items]
Total revenue	39,149		77,855
Firm commitments (ASC 606 revenue)
Disaggregation of Revenue [Line Items]
Total revenue	3,549		6,976
Total firm commitments revenue
Disaggregation of Revenue [Line Items]
Total revenue	42,698		84,831
Ancillary revenue (ASC 606 revenue)
Disaggregation of Revenue [Line Items]
Total revenue	9,680		20,738
Total terminaling services fees
Disaggregation of Revenue [Line Items]
Total revenue	52,378		105,569
Pipeline transportation fees (ASC 840 revenue)
Disaggregation of Revenue [Line Items]
Total revenue	794		1,663
Management fees (ASC 606 revenue)
Disaggregation of Revenue [Line Items]
Total revenue	$ 2,172		$ 4,556

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REVENUE FROM CONTRACTS WITH CUSTOMERS - Contract Revenue (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2018 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	$ 10,715
Estimated revenue in accordance with ASC 840, remainder of 2018	77,300
Estimated revenue in accordance with ASC 840, 2019	124,200
Estimated revenue in accordance with ASC 840, 2020	103,300
Estimated revenue in accordance with ASC 840, 2021	78,500
Estimated revenue in accordance with ASC 840, therafter	59,900
Gulf Coast Terminals
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	2,781
River terminals
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	3,175
West Coast terminals
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	4,759
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	$ 5,678
Remaining Performance Obligation, Expected Timing of Satisfaction, Period	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-04-01 | Gulf Coast Terminals
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	$ 2,060
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-04-01 | River terminals
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	578
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-04-01 | West Coast terminals
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	3,040
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	$ 3,354
Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Gulf Coast Terminals
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	$ 721
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | River terminals
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	1,039
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | West Coast terminals
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	1,594
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	$ 1,164
Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | River terminals
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	$ 1,039
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | West Coast terminals
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	125
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	$ 519
Remaining Performance Obligation, Expected Timing of Satisfaction, Period	0 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | River terminals
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Performance Obligation	$ 519

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BUSINESS SEGMENTS (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2016
Segments of business
Total revenue	$ 55,344	$ 45,364	$ 111,788	$ 90,214
Direct operating costs and expenses	(19,275)	(15,984)	(39,420)	(32,495)
Net margins	36,069	29,380	72,368	57,719
General and administrative expenses	(4,619)	(4,080)	(9,600)	(8,051)
Insurance expenses	(1,271)	(1,002)	(2,517)	(2,008)
Equity-based compensation expense	(441)	(352)	(2,458)	(2,169)
Depreciation and amortization	(13,160)	(8,792)	(24,968)	(17,497)
Earnings from unconsolidated affiliates	2,444	2,120	5,333	4,680
Operating income	19,022	17,274	38,158	32,674
Other expenses	(9,562)	(2,796)	(16,524)	(5,242)
Net earnings	9,460	14,478	21,634	27,432	$ 48,493
Capital expenditures	15,452	19,145	21,955	28,645
Identifiable assets	729,734		729,734
Cash and cash equivalents	390	1,965	390	1,965	923	$ 937	$ 641	$ 593
Investments in unconsolidated affiliates	231,767		231,767		233,181
Deferred issuance costs	6,364		6,364		6,778
Other	6,567		6,567
TOTAL ASSETS	974,822		974,822		$ 987,003
External customers
Segments of business
Total revenue	51,379	43,850	103,493	86,930
Affiliates
Segments of business
Total revenue	3,965	1,514	8,295	3,284
Affiliates | Frontera
Segments of business
Total revenue	1,894	1,514	4,012	3,284
Affiliates | Associated Asphalt Marketing, LLC
Segments of business
Total revenue	2,071		4,283
Gulf Coast Terminals
Segments of business
Total revenue	16,551	15,796	32,821	32,086
Direct operating costs and expenses	(5,413)	(5,426)	(11,245)	(10,980)
Net margins	11,138	10,370	21,576	21,106
Capital expenditures	1,814	1,059	3,180	2,586
Identifiable assets	122,011		122,011
Gulf Coast Terminals | External customers
Segments of business
Total revenue	14,480	15,796	28,538	32,086
Gulf Coast Terminals | Affiliates | Associated Asphalt Marketing, LLC
Segments of business
Total revenue	2,071		4,283
Midwest Terminals and Pipeline System
Segments of business
Total revenue	2,838	2,898	5,690	5,734
Direct operating costs and expenses	(743)	(693)	(1,455)	(1,405)
Net margins	2,095	2,205	4,235	4,329
Capital expenditures	35	45	336	267
Identifiable assets	20,488		20,488
Midwest Terminals and Pipeline System | External customers
Segments of business
Total revenue	2,838	2,898	5,690	5,734
Brownsville terminals
Segments of business
Total revenue	4,230	5,482	8,836	11,156
Direct operating costs and expenses	(2,135)	(2,582)	(4,176)	(5,454)
Net margins	2,095	2,900	4,660	5,702
Capital expenditures	2,024	228	2,467	372
Identifiable assets	42,507		42,507
Brownsville terminals | External customers
Segments of business
Total revenue	2,336	3,968	4,824	7,872
Brownsville terminals | Affiliates | Frontera
Segments of business
Total revenue	1,894	1,514	4,012	3,284
River terminals
Segments of business
Total revenue	2,589	2,740	5,343	5,410
Direct operating costs and expenses	(1,805)	(1,535)	(3,641)	(3,185)
Net margins	784	1,205	1,702	2,225
Capital expenditures	345	652	892	1,046
Identifiable assets	48,710		48,710
River terminals | External customers
Segments of business
Total revenue	2,589	2,740	5,343	5,410
Southeast terminals
Segments of business
Total revenue	19,704	18,448	40,126	35,828
Direct operating costs and expenses	(5,714)	(5,748)	(12,333)	(11,471)
Net margins	13,990	12,700	27,793	24,357
Capital expenditures	9,152	17,161	12,435	24,374
Identifiable assets	221,539		221,539
Southeast terminals | External customers
Segments of business
Total revenue	19,704	18,448	40,126	35,828
West Coast terminals
Segments of business
Total revenue	9,432		18,972
Direct operating costs and expenses	(3,465)		(6,570)
Net margins	5,967		12,402
Capital expenditures	2,082		2,645
Identifiable assets	274,479		274,479
West Coast terminals | External customers
Segments of business
Total revenue	9,432		18,972
Terminaling services fees | Gulf Coast Terminals
Segments of business
Total revenue	16,465	15,533	32,638	31,540
Terminaling services fees | Midwest Terminals and Pipeline System
Segments of business
Total revenue	2,405	2,465	4,824	4,868
Terminaling services fees | Brownsville terminals
Segments of business
Total revenue	1,977	2,505	4,043	4,972
Terminaling services fees | River terminals
Segments of business
Total revenue	2,589	2,740	5,343	5,410
Terminaling services fees | Southeast terminals
Segments of business
Total revenue	19,510	18,263	39,749	35,460
Terminaling services fees | West Coast terminals
Segments of business
Total revenue	9,432		18,972
Total firm commitments revenue
Segments of business
Total revenue	42,698		84,831
Ancillary revenue (ASC 606 revenue)
Segments of business
Total revenue	9,680		20,738
Total terminaling services fees
Segments of business
Total revenue	52,378		105,569
Pipeline transportation fees (ASC 840 revenue)
Segments of business
Total revenue	794		1,663
Pipeline transportation fees (ASC 840 revenue) | Midwest Terminals and Pipeline System
Segments of business
Total revenue	433	433	866	866
Pipeline transportation fees (ASC 840 revenue) | Brownsville terminals
Segments of business
Total revenue	361	1,363	797	2,646
Management fees (ASC 606 revenue)
Segments of business
Total revenue	2,172		4,556
Management fees (ASC 606 revenue) | Gulf Coast Terminals
Segments of business
Total revenue	86	263	183	546
Management fees (ASC 606 revenue) | Brownsville terminals
Segments of business
Total revenue	1,892	1,614	3,996	3,538
Management fees (ASC 606 revenue) | Southeast terminals
Segments of business
Total revenue	$ 194	$ 185	$ 377	$ 368

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SUBSEQUENT EVENTS (Details) - $ / shares			3 Months Ended
	Aug. 08, 2018	Jul. 17, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Jul. 09, 2018
Subsequent Events
Distribution announced per unit (in dollars per unit)			$ 0.795	$ 0.785	$ 0.770	$ 0.755	$ 0.740	$ 0.725
Subsequent events
Subsequent Events
Distribution announced per unit (in dollars per unit)		$ 0.795
Distribution paid per unit (in dollars per unit)	$ 0.795
ArcLight | Common units | Subsequent events
Subsequent Events
Buyout offer amount (in dollars per unit)									$ 38.00