10-Q 1 a2211601z10-q.htm 10-Q

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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 10-Q

(Mark One)    

ý

 

Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended September 30, 2012

OR

o

 

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 ý    No o

        Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ý    No o

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

Large accelerated filer o   Accelerated filer ý   Non-accelerated filer o
(Do not check if a
smaller reporting company)
  Smaller reporting company o

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

        As of October 31, 2012, there were 14,457,066 units of the registrant's Common Limited Partner Units outstanding.

   


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TABLE OF CONTENTS

 
   
  Page No.  

Part I. Financial Information

 

Item 1.

 

Unaudited Consolidated Financial Statements

    3  

 

Consolidated balance sheets as of September 30, 2012 and December 31, 2011

    5  

 

Consolidated statements of comprehensive income for the three and nine months ended September 30, 2012 and 2011

    6  

 

Consolidated statements of partners' equity for the year ended December 31, 2011 and nine months ended September 30, 2012

    7  

 

Consolidated statements of cash flows for the three and nine months ended September 30, 2012 and 2011

    8  

 

Notes to consolidated financial statements

    9  

Item 2.

 

Management's Discussion and Analysis of Financial Condition and Results of Operations

    36  

Item 3.

 

Quantitative and Qualitative Disclosures about Market Risk

    50  

Item 4.

 

Controls and Procedures

    51  

Part II. Other Information

 

Item 1A.

 

Risk Factors

    52  

Item 2.

 

Unregistered Sales of Equity Securities and Use of Proceeds

    54  

Item 6.

 

Exhibits

    54  

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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS

        This Quarterly Report contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, including the following:

    certain statements, including possible or assumed future results of operations, in "Management's Discussion and Analysis of Financial Condition and Results of Operations;"

    any statements contained herein regarding the prospects for our business or any of our services;

    any statements preceded by, followed by or that include the words "may," "seeks," "believes," "expects," "anticipates," "intends," "continues," "estimates," "plans," "targets," "predicts," "attempts," "is scheduled," or similar expressions; and

    other statements contained herein regarding matters that are not historical facts.

        Our business and results of operations are subject to risks and uncertainties, many of which are beyond our ability to control or predict. Because of these risks and uncertainties, actual results may differ materially from those expressed or implied by forward-looking statements, and investors are cautioned not to place undue reliance on such statements, which speak only as of the date thereof. Important factors that could cause actual results to differ materially from our expectations and may adversely affect our business and results of operations, include, but are not limited to those risk factors set forth in this report in Part II. Other Information under the heading "Item 1A. Risk Factors."


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 nine months ended September 30, 2012 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, 2011, together with our discussion and analysis of financial condition and results of operations, included in our Annual Report on Form 10-K/A, Amendment No. 1, filed on May 3, 2012 with the Securities and Exchange Commission (File No. 001-32505).

        TransMontaigne Partners L.P. is a holding company with the following active wholly-owned operating subsidiaries during the three and nine months ended September 30, 2012:

    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.

    TMOC Corp.

    TLP Operating Finance Corp.

    TPME L.L.C.

    TLP Mex L.L.C.

    Penn Octane de Mexico, S. de R.L. de C.V.

    Termatsal, S. de R.L. de C.V.

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    Tergas, S. de R.L. de C.V.

        The above omits non-operating subsidiaries that, considered in the aggregate, do not constitute significant subsidiaries as of September 30, 2012. We do not have off-balance-sheet arrangements (other than operating leases) or special-purpose entities.

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TransMontaigne Partners L.P. and subsidiaries

Consolidated balance sheets (unaudited)

(Dollars in thousands)

 
  September 30,
2012
  December 31,
2011
 

ASSETS

             

Current assets:

             

Cash and cash equivalents

  $ 6,938   $ 7,138  

Trade accounts receivable, net

    4,896     4,271  

Due from affiliates

    4,410     3,906  

Other current assets

    4,863     22,768  
           

Total current assets

    21,107     38,083  

Property, plant and equipment, net

    428,082     431,782  

Goodwill

    8,739     8,716  

Investment in joint venture

    25,836     25,875  

Other assets, net

    8,485     9,648  
           

  $ 492,249   $ 514,104  
           

LIABILITIES AND PARTNERS' EQUITY

             

Current liabilities:

             

Trade accounts payable

  $ 6,125   $ 7,936  

Accrued liabilities

    20,273     19,924  
           

Total current liabilities

    26,398     27,860  

Other liabilities

    11,419     14,368  

Long-term debt

    102,000     120,000  
           

Total liabilities

    139,817     162,228  
           

Partners' equity:

             

Common unitholders (14,457,066 units issued and outstanding at September 30, 2012 and December 31, 2011)

    296,237     296,052  

General partner interest (2% interest with 295,042 equivalent units outstanding at September 30, 2012 and December 31, 2011)

    56,638     56,490  

Accumulated other comprehensive loss

    (443 )   (666 )
           

Total partners' equity

    352,432     351,876  
           

  $ 492,249   $ 514,104  
           

   

See accompanying notes to consolidated financial statements.

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TransMontaigne Partners L.P. and subsidiaries

Consolidated statements of comprehensive income (unaudited)

(In thousands, except per unit amounts)

 
  Three months ended
September 30,
  Nine months ended
September 30,
 
 
  2012   2011   2012   2011  

Revenue:

                         

External customers

  $ 11,292   $ 10,802   $ 34,102   $ 34,534  

Affiliates

    27,582     26,283     82,047     78,519  
                   

Total revenue

    38,874     37,085     116,149     113,053  
                   

Operating costs and expenses and other:

                         

Direct operating costs and expenses

    (16,170 )   (16,490 )   (46,323 )   (48,703 )

Direct general and administrative expenses

    (1,204 )   (1,060 )   (3,607 )   (3,240 )

Allocated general and administrative expenses

    (2,695 )   (2,616 )   (8,085 )   (7,849 )

Allocated insurance expense

    (897 )   (823 )   (2,692 )   (2,468 )

Reimbursement of bonus awards

    (313 )   (313 )   (938 )   (938 )

Depreciation and amortization

    (7,112 )   (6,873 )   (20,982 )   (20,733 )

Gain on disposition of assets

                9,576  

Equity in earnings (loss) of joint venture

    217     (285 )   652     (52 )
                   

Total operating costs and expenses and other

    (28,174 )   (28,460 )   (81,975 )   (74,407 )
                   

Operating income

    10,700     8,625     34,174     38,646  

Other income (expenses):

                         

Interest expense

    (692 )   (670 )   (2,021 )   (1,694 )

Foreign currency transaction gain (loss)

    32     (102 )   58     (65 )

Amortization of deferred financing costs

    (187 )   (187 )   (562 )   (867 )
                   

Total other expenses, net

    (847 )   (959 )   (2,525 )   (2,626 )
                   

Net earnings

    9,853     7,666     31,649     36,020  

Other comprehensive income—foreign currency translation adjustments

    130     (366 )   223     (233 )
                   

Comprehensive income

  $ 9,983   $ 7,300   $ 31,872   $ 35,787  
                   

Net earnings

  $ 9,853   $ 7,666   $ 31,649   $ 36,020  

Less—earnings allocable to general partner interest including incentive distribution rights

    (1,328 )   (1,007 )   (3,888 )   (3,213 )
                   

Net earnings allocable to limited partners

  $ 8,525   $ 6,659   $ 27,761   $ 32,807  
                   

Net earnings per limited partner unit—basic

  $ 0.59   $ 0.46   $ 1.92   $ 2.27  
                   

Net earnings per limited partner unit—diluted

  $ 0.59   $ 0.46   $ 1.92   $ 2.27  
                   

Weighted average limited partner units outstanding—basic

    14,442     14,442     14,442     14,442  
                   

Weighted average limited partner units outstanding—diluted

    14,447     14,453     14,447     14,454  
                   

   

See accompanying notes to consolidated financial statements.

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TransMontaigne Partners L.P. and subsidiaries

Consolidated statements of partners' equity (unaudited)

Year ended December 31, 2011 and nine months ended September 30, 2012

(In thousands, except unit amounts)

 
  Common
unitholders
  General
partner
interest
  Accumulated
other
comprehensive
loss
  Total  

Balance December 31, 2010

  $ 289,632   $ 55,533   $ (349 ) $ 344,816  

Distributions to unitholders

    (35,575 )   (3,926 )       (39,501 )

Deferred equity-based compensation related to restricted phantom units

    419             419  

Purchase of 13,652 common units by our long-term incentive plan and from affiliate

    (529 )           (529 )

Acquisition of Pensacola Terminal from TransMontaigne Inc. in exchange for $12.8 million

        468         468  

Issuance of 11,392 common units by our long-term incentive plan due to vesting of restricted phantom units

                 

Net earnings for year ended December 31, 2011

    42,105     4,415         46,520  

Other comprehensive loss

            (317 )   (317 )
                   

Balance December 31, 2011

    296,052     56,490     (666 )   351,876  

Distributions to unitholders

    (27,506 )   (3,740 )       (31,246 )

Deferred equity-based compensation related to restricted phantom units

    321             321  

Purchase of 10,991 common units by our long-term incentive plan and from affiliate

    (391 )           (391 )

Issuance of 11,980 common units by our long-term incentive plan due to vesting of restricted phantom units

                 

Net earnings for nine months ended September 30, 2012

    27,761     3,888         31,649  

Other comprehensive income

            223     223  
                   

Balance September 30, 2012

  $ 296,237   $ 56,638   $ (443 ) $ 352,432  
                   

   

See accompanying notes to consolidated financial statements.

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TransMontaigne Partners L.P. and subsidiaries

Consolidated statements of cash flows (unaudited)

(In thousands)

 
  Three months ended
September 30,
  Nine months ended
September 30,
 
 
  2012   2011   2012   2011  

Cash flows from operating activities:

                         

Net earnings

  $ 9,853   $ 7,666   $ 31,649   $ 36,020  

Adjustments to reconcile net earnings to net cash provided by operating activities:

                         

Depreciation and amortization

    7,112     6,873     20,982     20,733  

Gain on disposition of assets

                (9,576 )

Equity in loss (earnings) of joint venture

    (217 )   285     (652 )   52  

Distributions received from joint venture

    361     657     1,192     657  

Deferred equity-based compensation

    114     107     321     312  

Amortization of deferred financing costs

    187     187     562     867  

Unrealized gain on derivative instrument

                (1,250 )

Amortization of deferred revenue

    (1,173 )   (1,134 )   (3,451 )   (3,372 )

Amounts due under long-term terminaling services agreements, net

    179     (119 )   447     (414 )

Changes in operating assets and liabilities:

                         

Trade accounts receivable, net

    397     (1,347 )   (597 )   1,406  

Due from affiliates

    (726 )   (229 )   (84 )   2,032  

Other current assets

    1,712     1,099     (79 )   1,851  

Trade accounts payable

    695     (1,979 )   (1,973 )   (4,431 )

Due to affiliates

        (74 )       (111 )

Accrued liabilities

    4,186     1,534     337     2,778  
                   

Net cash provided by operating activities

    22,680     13,526     48,654     47,554  
                   

Cash flows from investing activities:

                         

Acquisition of terminal facilities

                (12,781 )

Additions to investment in the BOSTCO project

        (3,894 )       (7,005 )

Additions to property, plant and equipment—expansion of facilities

    (4,987 )   (2,613 )   (12,853 )   (12,048 )

Additions to property, plant and equipment—maintain existing facilities

    (1,296 )   (1,527 )   (3,932 )   (4,749 )

Contributions to joint venture

    (500 )   (21 )   (500 )   (1,021 )

Proceeds in return for contribution of assets to joint venture

                25,593  

Proceeds from sale of assets

            18,000      
                   

Net cash provided by (used in) investing activities

    (6,783 )   (8,055 )   715     (12,011 )
                   

Cash flows from financing activities:

                         

Borrowings of debt under credit facility

    10,000     11,000     44,500     61,843  

Repayments of debt under credit facility

    (14,500 )   (6,500 )   (62,500 )   (63,843 )

Deferred debt issuance costs

                (3,575 )

Distributions paid to unitholders

    (10,604 )   (9,976 )   (31,246 )   (29,471 )

Purchase of common units by our long-term incentive plan and from affiliate

    (276 )   (308 )   (391 )   (475 )
                   

Net cash used in financing activities

    (15,380 )   (5,784 )   (49,637 )   (35,521 )
                   

Increase (decrease) in cash and cash equivalents

    517     (313 )   (268 )   22  

Foreign currency translation effect on cash

    56     (137 )   68     (105 )

Cash and cash equivalents at beginning of period

    6,365     5,720     7,138     5,353  
                   

Cash and cash equivalents at end of period

  $ 6,938   $ 5,270   $ 6,938   $ 5,270  
                   

Supplemental disclosure of cash flow information:

                         

Cash paid for interest

  $ 679   $ 670   $ 2,046   $ 3,671  
                   

   

See accompanying notes to consolidated financial statements.

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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. ("Partners") was formed in February 2005 as a Delaware master limited partnership initially to own and operate refined petroleum products terminaling and transportation facilities. We conduct our operations primarily in the United States along the Gulf Coast, in the Southeast, in Brownsville, Texas, along the Mississippi and Ohio rivers, and in the Midwest. We provide integrated terminaling, storage, transportation and related services for companies engaged in the trading, distribution and marketing of refined petroleum products, crude oil, chemicals, fertilizers and other liquid products, including TransMontaigne Inc. and Morgan Stanley Capital Group Inc.

        We are controlled by our general partner, TransMontaigne GP L.L.C. ("TransMontaigne GP"), which is a wholly-owned subsidiary of TransMontaigne Inc. Effective September 1, 2006, Morgan Stanley Capital Group Inc. ("Morgan Stanley Capital Group"), a wholly-owned subsidiary of Morgan Stanley, purchased all of the issued and outstanding capital stock of TransMontaigne Inc. Morgan Stanley Capital Group is the principal commodities trading arm of Morgan Stanley. As a result of Morgan Stanley's acquisition of TransMontaigne Inc., Morgan Stanley became the indirect owner of our general partner. At September 30, 2012, TransMontaigne Inc. and Morgan Stanley have a significant interest in our partnership through their indirect ownership of a 21.6% limited partner interest, a 2% general partner interest and the incentive distribution rights.

(b)   Basis of presentation and use of estimates

        Our accounting and financial reporting policies conform to accounting principles and practices generally accepted in the United States of America. The accompanying consolidated financial statements include the accounts of TransMontaigne Partners L.P., a Delaware limited partnership, 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 September 30, 2012, our results of operations for the three and nine months ended September 30, 2012 and 2011 and our cash flows for the three and nine months ended September 30, 2012 and 2011.

        The preparation of financial statements in conformity with generally accepted accounting principles 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 involve complex analyses: useful lives of our plant and equipment, accrued environmental obligations and determining the fair value of our reporting units when analyzing goodwill. 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.

        The accompanying consolidated financial statements include allocated general and administrative charges from TransMontaigne Inc. for indirect corporate overhead to cover costs of functions such as legal, accounting, treasury, engineering, environmental safety, information technology, and other

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (Continued)

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

corporate services (see Note 2 of Notes to consolidated financial statements). The allocated general and administrative expenses were approximately $2.7 million and $2.6 million for the three months ended September 30, 2012 and 2011, respectively. The allocated general and administrative expenses were approximately $8.1 million and $7.8 million for the nine months ended September 30, 2012 and 2011, respectively. The accompanying consolidated financial statements also include allocated insurance charges from TransMontaigne Inc. for insurance premiums to cover costs of insuring activities such as property, casualty, pollution, automobile, directors' and officers' liability, and other insurable risks. The allocated insurance charges were approximately $0.9 million and $0.8 million for the three months ended September 30, 2012 and 2011, respectively. The allocated insurance charges were approximately $2.7 million and $2.5 million for the nine months ended September 30, 2012 and 2011, respectively. The accompanying consolidated financial statements also include reimbursement of bonus awards paid to TransMontaigne Services Inc. towards bonus awards granted by TransMontaigne Services Inc. to certain key officers and employees who provide services to Partners that vest over future periods. The reimbursement of bonus awards was approximately $0.3 million for each of the three months ended September 30, 2012 and 2011. The reimbursement of bonus awards was approximately $0.9 million for each of the nine months ended September 30, 2012 and 2011.

(c)   Accounting for terminal and pipeline operations

        In connection with our terminal and pipeline operations, we utilize the accrual method of accounting for revenue and expenses. We generate revenue in our terminal and pipeline operations from terminaling services fees, transportation fees, management fees and cost reimbursements, fees from other ancillary services and gains from the sale of refined products. Terminaling services revenue is recognized ratably over the term of the agreement for storage fees and minimum revenue commitments that are fixed at the inception of the agreement and when product is delivered to the customer for fees based on a rate per barrel throughput; transportation revenue is recognized when the product has been delivered to the customer at the specified delivery location; management fee revenue and cost reimbursements are recognized as the services are performed or as the costs are incurred; ancillary service revenue is recognized as the services are performed; and gains from the sale of refined products are recognized when the title to the product is transferred.

        Pursuant to terminaling services agreements with certain of our throughput customers, we are entitled to the volume of product gained resulting from differences in the measurement of product volumes received and distributed at our terminaling facilities. Consistent with recognized industry practices, measurement differentials occur as the result of the inherent variances in measurement devices and methodology. We recognize as revenue the net proceeds from the sale of the product gained. For the three months ended September 30, 2012 and 2011, we recognized revenue of approximately $4.1 million and $3.8 million, respectively, for net product gained. Within these amounts, approximately $3.4 million and $3.4 million, respectively, were pursuant to terminaling services agreements with affiliate customers. For the nine months ended September 30, 2012 and 2011, we recognized revenue of approximately $12.5 million and $13.2 million, respectively, for net product gained. Within these amounts, approximately $10.5 million and $11.9 million, respectively, were pursuant to terminaling services agreements with affiliate customers.

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (Continued)

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

(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)    Investment in joint venture

        Effective as of April 1, 2011, we entered into a joint venture with P.M.I. Services North America Inc. ("PMI"), an indirect subsidiary of Petroleos Mexicanos ("Pemex"), the Mexican state-owned petroleum company, at our Brownsville, Texas terminal. We contributed approximately 1.5 million barrels of light petroleum product storage capacity, as well as related ancillary facilities, to the joint venture, also known as Frontera Brownsville LLC or "Frontera", in exchange for a cash payment of approximately $25.6 million and a 50% ownership interest. PMI acquired a 50% ownership interest in Frontera for a cash payment of approximately $25.6 million. We operate the Frontera assets under an operations and reimbursement agreement executed between us and Frontera. All significant decisions affecting the business are decided by PMI and us based upon our respective 50% ownership interests.

        We account for our investment in Frontera, 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 fair value on the acquisition date, increased by our proportionate share of any earnings and additional capital contributions and decreased by our proportionate share of any losses and distributions received from Frontera. We evaluate our equity method investment 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 an impairment, we would record a charge to earnings to adjust the carrying amount to fair value.

(g)   Environmental obligations

        We accrue for environmental costs that relate to existing conditions caused by past operations when estimable (see Note 9 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.

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (Continued)

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

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 (i.e., likely to occur).

        TransMontaigne Inc. agreed to indemnify us against certain potential environmental claims, losses and expenses that were identified on or before December 31, 2011 and that are associated with the ownership or operation of the Brownsville and River terminals prior to December 31, 2006, up to a maximum liability not to exceed $15.0 million for this indemnification obligation (see Note 2 of Notes to consolidated financial statements). TransMontaigne Inc. has agreed to indemnify us against certain potential environmental claims, losses and expenses that are identified on or before December 31, 2012 and that are associated with the ownership or operation of the Southeast terminals prior to December 31, 2007, up to a maximum liability not to exceed $15.0 million for this indemnification obligation (see Note 2 of Notes to consolidated financial statements). TransMontaigne Inc. has agreed to indemnify us against certain potential environmental claims, losses and expenses that are identified on or before March 1, 2016 and that are associated with the ownership or operation of the Pensacola terminal prior to March 1, 2011, up to a maximum liability not to exceed $2.5 million for this indemnification obligation (see Note 2 of Notes to consolidated financial statements).

(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.

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Notes to consolidated financial statements (unaudited) (Continued)

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

(i)    Equity-based compensation plan

        Generally accepted accounting principles require us to measure the cost of services received in exchange for an award of equity instruments based on the grant-date fair value of the award. That cost will be recognized over the period during which a board member or employee is required to provide service in exchange for the award. We are required to estimate the number of equity instruments that are expected to vest in measuring the total compensation cost to be recognized over the related service period. Compensation cost is recognized over the service period on a straight-line basis.

(j)    Foreign currency translation and transactions

        The functional currency of Partners and its U.S.-based subsidiaries is the U.S. Dollar. The functional currency of our foreign subsidiaries, including Penn Octane de Mexico, S. de R.L. de C.V., Termatsal, S. de R.L. de C.V., and Tergas, S. de R.L. de C.V., is the Mexican Peso. The assets and liabilities of our foreign subsidiaries are translated at period-end rates of exchange, and revenue and expenses are translated at average exchange rates prevailing for the period. The resulting translation adjustments, net of related income taxes, are recorded as a component of other comprehensive income in the consolidated statements of comprehensive income. Gains and losses from the remeasurement of foreign currency transactions (transactions denominated in a currency other than the entity's functional currency) are included in other income (expenses) in the consolidated statements of comprehensive income.

(k)   Accounting for derivative instruments

        Generally accepted accounting principles require us to recognize all derivative instruments at fair value in the consolidated balance sheet as assets or liabilities. Changes in the fair value of our derivative instruments are recognized as a component of net earnings unless specific hedge accounting criteria are met.

        We did not have any derivative instruments during the three and nine months ended September 30, 2012. During the nine months ended September 30, 2011, our derivative instruments were limited to an interest rate swap agreement with a notional amount of $150.0 million. Our interest rate swap agreement expired in June 2011. The interest rate swap reduced our cash exposure to changes in interest rates by converting variable interest rates to fixed interest rates. Pursuant to the terms of the interest rate swap agreement, we paid a fixed rate of approximately 2.2% and received an interest payment based on the one-month LIBOR. The net difference to be paid or received under the interest rate swap agreement was settled monthly and was recognized as an adjustment to interest expense. During the three and nine months ended September 30, 2011, we recognized net payments to the counterparty in the amount of $nil and approximately $1.3 million, respectively.

        At the time we entered into the interest rate swap we did not designate it as a hedge, and therefore the change in the fair value of our interest rate swap is included in the consolidated statements of comprehensive income. During the three and nine months ended September 30, 2011, we recognized unrealized gains in the amount of $nil and approximately $1.3 million, respectively, related to the estimated change in the fair value of the interest rate swap, which was recorded as a reduction to interest expense. The fair value of our interest rate swap was determined using a pricing model based on the LIBOR swap rate and other observable market data. The fair value was determined after considering the potential impact of collateralization, adjusted to reflect nonperformance risk. Our fair

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Notes to consolidated financial statements (unaudited) (Continued)

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

value measurement of our interest rate swap utilized Level 2 inputs as defined by generally accepted accounting principles.

(l)    Income taxes

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

        Partners is a taxable entity under certain U.S. state jurisdictions, primarily Texas. Certain of our Mexican subsidiaries are corporations for Mexican tax purposes and, therefore, are subject to Mexican federal and provincial income taxes.

        Partners accounts for U.S. state income taxes and Mexican federal and provincial income taxes under the asset and liability method pursuant to generally accepted accounting principles. Currently, Mexican federal and provincial income taxes and U.S. state income taxes are not material.

(m)  Net earnings per limited partner unit

        Generally accepted accounting principles address the computation of earnings per limited partnership unit for master limited partnerships that consist of publicly traded common units held by limited partners, a general partner interest, and incentive distribution rights that are accounted for as equity interests. Partners' incentive distribution rights are owned by our general partner. Distributions are declared from available cash (as defined by our partnership agreement) and the incentive distribution rights are not entitled to distributions other than from available cash. Any excess of distributions over earnings are allocated to the limited partners and general partner interest based on their respective sharing of losses specified in the partnership agreement, which is based on their ownership percentages of 98% and 2%, respectively. Incentive distribution rights do not share in losses under our partnership agreement. The earnings allocable to the general partner interest for the period represents distributions attributable to the period on behalf of the general partner interest and any incentive distribution rights less the excess of distributions over earnings allocated to the limited partners (see Note 15 of Notes to consolidated financial statements). Basic earnings per limited partner unit are computed by dividing net earnings allocable to limited partners by the weighted average number of limited partnership units outstanding during the period, excluding restricted phantom units. Diluted earnings per limited partner unit are computed by dividing net earnings allocable to limited partners by the weighted average number of limited partnership units outstanding during the period and, when dilutive, restricted phantom units. Net earnings allocable to limited partners are net of the earnings allocable to the general partner interest including incentive distribution rights.

(n)   Reclassification and correction of prior period amounts

        Certain prior period amounts have been changed. Within the financing activities section of the consolidated statements of cash flows for the three and nine months ended September 30, 2011, the net borrowings and repayments of debt under our credit facility have been corrected to reflect the gross amount of borrowings and the gross amount of repayments. In addition, within the consolidated statement of comprehensive income for the nine months ended September 30, 2011, the unrealized gain on our derivative instrument has been reclassified to interest expense. We did not have any

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Notes to consolidated financial statements (unaudited) (Continued)

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

derivative instruments during the three and nine months ended September 30, 2012 nor during the three months ended September 30, 2011. These changes in presentation had no impact on previously reported amounts of net earnings or partners' equity.

(2) TRANSACTIONS WITH AFFILIATES

        Constraints on expansion.    Morgan Stanley informed us in October 2011 that, for the foreseeable future, it does not expect to approve any "significant" acquisition or investment that we may propose. Morgan Stanley's decision is the result of the uncertain regulatory environment relating to Morgan Stanley's status as a financial holding company subject to the Bank Holding Company Act and consolidated supervision by the Board of Governors of the Federal Reserve System. Morgan Stanley indicated that it has not established a specific definition of what constitutes a "significant" investment and significance may be determined on either a quantitative or qualitative basis, depending on the facts and circumstances and relevant legal and regulatory considerations. Morgan Stanley has informed us they will review on a case by case basis each proposed transaction to determine its significance, whether an acquisition of, or investment in, assets or legal entities and that an acquisition of, or investment in, a minority interest or joint venture interest may be "significant" without respect to the size of the transaction. The practical effect of these limitations is to significantly constrain our ability to expand our asset base and operations through acquisitions from third parties. These constraints will reduce the potential for increasing our distributions to unitholders in the future. In addition, these constraints will limit additions to our capital assets primarily to additions and improvements that we construct or add to our existing facilities, although some acquisitions of assets from third parties may be possible to the extent approved by Morgan Stanley.

        Omnibus agreement.    We have an omnibus agreement with TransMontaigne Inc. that will expire in December 2014, unless extended. Under the omnibus agreement we pay TransMontaigne Inc. an administrative fee for the provision of various general and administrative services for our benefit. Effective January 1, 2012, the annual administrative fee payable to TransMontaigne Inc. is approximately $10.8 million. If we acquire or construct additional facilities, TransMontaigne Inc. will propose a revised administrative fee covering the provision of services for such additional facilities. If the conflicts committee of our general partner agrees to the revised administrative fee, TransMontaigne Inc. will provide services for the additional facilities pursuant to the agreement. The administrative fee includes expenses incurred by TransMontaigne Inc. to perform centralized corporate functions, such as legal, accounting, treasury, insurance administration and claims processing, health, safety and environmental, information technology, human resources, credit, payroll, taxes and engineering and other corporate services, to the extent such services are not outsourced by TransMontaigne Inc.

        The omnibus agreement further provides that we pay TransMontaigne Inc. an insurance reimbursement for premiums on insurance policies covering our facilities and operations. Effective January 1, 2012, the annual insurance reimbursement payable to TransMontaigne Inc. is approximately $3.6 million. We also reimburse TransMontaigne Inc. for direct operating costs and expenses that TransMontaigne Inc. incurs on our behalf, such as salaries of operational personnel performing services on-site at our terminals and pipelines and the cost of their employee benefits, including 401(k) and health insurance benefits.

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(2) TRANSACTIONS WITH AFFILIATES (Continued)

        We also agreed to reimburse TransMontaigne Inc. and its affiliates for a portion of the incentive payment grants to key employees of TransMontaigne Inc. and its affiliates under the TransMontaigne Services Inc. savings and retention plan, provided the compensation committee of our general partner determines that an adequate portion of the incentive payment grants are allocated to an investment fund indexed to the performance of our common units. For the year ending December 31, 2012, we have agreed to reimburse TransMontaigne Inc. and its affiliates approximately $1.3 million.

        The omnibus agreement provided us with a right of first offer to purchase all of TransMontaigne Inc.'s and its subsidiaries' right, title and interest in the Pensacola, Florida refined petroleum products terminal. We exercised this right effective March 1, 2011 and purchased the Pensacola terminal for cash consideration of approximately $12.8 million (see Note 3 of Notes to consolidated financial statements).

        The omnibus agreement also provides TransMontaigne Inc. a right of first refusal to purchase our assets, provided that TransMontaigne Inc. agrees to pay no less than 105% of the purchase price offered by the third party bidder. Before we enter into any contract to sell such terminal or pipeline facilities, we must give written notice of all material terms of such proposed sale to TransMontaigne Inc. TransMontaigne Inc. will then have the sole and exclusive option, for a period of 45 days following receipt of the notice, to purchase the subject facilities for no less than 105% of the purchase price on the terms specified in the notice.

        TransMontaigne Inc. also has a right of first refusal to contract for the use of any petroleum product storage capacity that (i) is put into commercial service after January 1, 2008, or (ii) was subject to a terminaling services agreement that expires or is terminated (excluding a contract renewable solely at the option of our customer), provided that TransMontaigne Inc. agrees to pay 105% of the fees offered by the third party customer.

        Environmental indemnification.    In connection with our acquisition of the Brownsville, Texas and River terminals, TransMontaigne Inc. agreed to indemnify us against potential environmental claims, losses and expenses that were identified on or before December 31, 2011, and that were associated with the ownership or operation of the Brownsville and River facilities prior to December 31, 2006. TransMontaigne Inc.'s maximum liability for this indemnification obligation is $15.0 million. TransMontaigne Inc. has no obligation to indemnify us for losses until such aggregate losses exceed $250,000. The deductible amount, cap amount and limitation of time for indemnification do not apply to any environmental liabilities known to exist as of December 31, 2006. TransMontaigne Inc. has no indemnification obligations with respect to environmental claims made as a result of additions to or modifications of environmental laws promulgated after December 31, 2006.

        In connection with our acquisition of the Southeast terminals, TransMontaigne Inc. agreed to indemnify us against potential environmental claims, losses and expenses that are identified on or before December 31, 2012, and that are associated with the ownership or operation of the Southeast terminals prior to December 31, 2007. Our environmental losses must first exceed $250,000 and TransMontaigne Inc.'s indemnification obligations are capped at $15.0 million. The deductible amount, cap amount and limitation of time for indemnification do not apply to any environmental liabilities known to exist as of December 31, 2007. TransMontaigne Inc. has no indemnification obligations with respect to environmental claims made as a result of additions to or modifications of environmental laws promulgated after December 31, 2007.

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Notes to consolidated financial statements (unaudited) (Continued)

(2) TRANSACTIONS WITH AFFILIATES (Continued)

        In connection with our acquisition of the Pensacola terminal, TransMontaigne Inc. agreed to indemnify us against potential environmental claims, losses and expenses that are identified on or before March 1, 2016, and that are associated with the ownership or operation of the Pensacola terminal prior to March 1, 2011. Our environmental losses must first exceed $200,000 and TransMontaigne Inc.'s indemnification obligations are capped at $2.5 million. The deductible amount, cap amount and limitation of time for indemnification do not apply to any environmental liabilities known to exist as of March 1, 2011. TransMontaigne Inc. has no indemnification obligations with respect to environmental claims made as a result of additions to or modifications of environmental laws promulgated after March 1, 2011.

        Terminaling services agreement—Florida terminals and Razorback pipeline system.    We have a terminaling services agreement with Morgan Stanley Capital Group relating to our Florida, Mt. Vernon, Missouri and Rogers, Arkansas terminals. Effective June 1, 2008, we amended the terminaling services agreement to include renewable fuels blending functionality at the Florida Terminals. The initial term of the agreement expires on May 31, 2014. After May 31, 2014, the terminaling services agreement will automatically renew for subsequent one-year periods, subject to either party's right to terminate with six months' notice prior to May 31, 2014 or the then-current renewal term. Under this agreement, Morgan Stanley Capital Group agreed to throughput a volume of refined product that will, at the fee and tariff schedule contained in the agreement, result in minimum throughput payments to us of approximately $37.0 million for the contract year ended May 31, 2012 (approximately $37.3 million for the contract year ending May 31, 2013); with stipulated annual increases in throughput payments each contract year thereafter. Morgan Stanley Capital Group's minimum annual throughput payment is reduced proportionately for any decrease in storage capacity due to out-of-service tank capacity.

        If a force majeure event occurs that renders performance impossible with respect to an asset for at least 30 consecutive days, Morgan Stanley Capital Group's obligations would be temporarily suspended with respect to that asset. If a force majeure event continues for 30 consecutive days or more and results in a diminution in the storage capacity we make available to Morgan Stanley Capital Group, Morgan Stanley Capital Group's minimum revenue commitment would be reduced proportionately for the duration of the force majeure event.

        Morgan Stanley Capital Group may not assign the terminaling services agreement without our consent. Upon termination of the agreement, Morgan Stanley Capital Group has a right of first refusal to enter into a new terminaling services agreement with us, provided they pay no less than 105% of the fees offered by any third party.

        Terminaling services agreement—Fisher Island terminal.    We have a terminaling services agreement with TransMontaigne Inc. that will expire on December 31, 2012. Under this agreement, TransMontaigne Inc. agreed to throughput at our Fisher Island terminal in the Gulf Coast region a volume of fuel oils that will, at the fee schedule contained in the agreement, result in minimum revenue to us of approximately $1.8 million for the contract year ending December 31, 2012. In exchange for its minimum throughput commitment, we agreed to provide TransMontaigne Inc. with approximately 185,000 barrels of fuel oil capacity.

        Revenue support agreement—Oklahoma City terminal.    We have a revenue support agreement with TransMontaigne Inc. that provides that in the event any current third-party terminaling services agreement should expire, TransMontaigne Inc. agrees to enter into a terminaling services agreement

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Notes to consolidated financial statements (unaudited) (Continued)

(2) TRANSACTIONS WITH AFFILIATES (Continued)

that will expire no earlier than November 1, 2012. The terminaling services agreement will provide that TransMontaigne Inc. agrees to throughput such volume of refined product as may be required to guarantee minimum revenue of approximately $0.8 million per year. If TransMontaigne Inc. fails to meet its minimum revenue commitment in any year, it must pay us the amount of any shortfall within 15 business days following receipt of an invoice from us. In exchange for TransMontaigne Inc.'s minimum revenue commitment, we will agree to provide TransMontaigne Inc. approximately 158,000 barrels of light oil storage capacity at our Oklahoma City terminal. TransMontaigne Inc.'s minimum revenue commitment currently is not in effect because a major oil company is under contract through January 31, 2014 for the utilization of the light oil storage capacity at the terminal.

        Terminaling services agreement—Cushing terminal.    In July 2011, we entered into a terminaling services agreement with Morgan Stanley Capital Group relating to our Cushing, Oklahoma facility that will expire in July 2019, subject to a five-year automatic renewal unless terminated by either party upon 180 days prior notice. In exchange for its minimum revenue commitment, we agreed to construct storage tanks and associated infrastructure to provide one million barrels of crude oil capacity. These capital projects were completed and placed into service on August 1, 2012. Under this agreement, Morgan Stanley Capital Group agreed to throughput a volume of crude oil products at our terminal that will, at the fee schedule contained in the agreement, result in minimum throughput payments to us of approximately $4.3 million for the one-year period following the in-service date of August 1, 2012 for the aforementioned capital projects, and for each contract year thereafter.

        If a force majeure event continues for 120 consecutive days or more and results in a diminution in the storage capacity we make available to Morgan Stanley Capital Group, Morgan Stanley Capital Group's minimum revenue commitment would be reduced proportionately for the duration of the force majeure event.

        Neither party may transfer or assign this agreement without the consent of the other party unless such assignment is to an affiliate or, in the case of Partners, a successor in interest to us or to the Cushing terminal.

        Terminaling and transportation services agreement—Brownsville LPG.    We have a terminaling and transportation services agreement with TransMontaigne Inc. relating to our Brownsville, Texas facilities that expired on March 31, 2011 and is continuing on a month to month basis, subject to either party's right to terminate with thirty days' prior notice. Under this agreement, TransMontaigne Inc. agreed to throughput at our Brownsville facilities certain minimum volumes of natural gas liquids that will result in minimum revenue to us of approximately $1.3 million per year. In exchange for TransMontaigne Inc.'s minimum throughput commitment, we agreed to provide TransMontaigne Inc. approximately 33,000 barrels of storage capacity at our Brownsville facilities.

        Terminaling services agreement—Matamoros LPG.    We had a terminaling services agreement with TransMontaigne Inc. relating to our natural gas liquids storage facility in Matamoros, Mexico that was terminated effective October 25, 2011. Under this agreement, TransMontaigne Inc. agreed to throughput a volume of natural gas liquids that resulted in minimum throughput payments to us of approximately $0.5 million in 2011. The storage capacity under this agreement is now under contract with a third party.

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Notes to consolidated financial statements (unaudited) (Continued)

(2) TRANSACTIONS WITH AFFILIATES (Continued)

        Operations and reimbursement agreement—Frontera.    Effective as of April 1, 2011, we entered into the Frontera joint venture in which we have a 50% ownership interest (see Note 3 of Notes to consolidated financial statements). In conjunction with us entering into the joint venture, we agreed to 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. For the three months ended September 30, 2012 and 2011, we recognized approximately $0.9 million and $0.6 million, respectively, of revenue related to this operations and reimbursement agreement. For the nine months ended September 30, 2012 and 2011, we recognized approximately $2.5 million and $1.2 million, respectively, of revenue related to this operations and reimbursement agreement.

        Terminaling services agreement—Southeast terminals.    We have a terminaling services agreement with Morgan Stanley Capital Group relating to our Southeast terminals. The terminaling services agreement commenced on January 1, 2008 and has a seven-year term expiring on December 31, 2014, subject to a seven-year renewal option at the election of Morgan Stanley Capital Group. Under this agreement, Morgan Stanley Capital Group agreed to throughput a volume of refined product at our Southeast terminals that will, at the fee schedule contained in the agreement, result in minimum throughput payments to us of approximately $35.4 million for the contract year ending December 31, 2012; with stipulated annual increases in throughput payments each contract year thereafter. Morgan Stanley Capital Group's minimum annual throughput payment is reduced proportionately for any decrease in storage capacity due to out-of-service tank capacity. In exchange for its minimum throughput commitment, we agreed to provide Morgan Stanley Capital Group approximately 8.9 million barrels of light oil storage capacity at our Southeast terminals. Under this agreement we also agreed to undertake certain capital projects to provide ethanol blending functionality at certain of our Southeast terminals with completion dates that extended through August 31, 2011. Upon the completion of each of the projects, Morgan Stanley Capital Group paid us a lump-sum ethanol blending fee that in total equaled approximately $22.5 million.

        If a force majeure event occurs that renders performance impossible with respect to an asset for at least 30 consecutive days, Morgan Stanley Capital Group's obligations would be temporarily suspended with respect to that asset. If a force majeure event continues for 30 consecutive days or more and results in a diminution in the storage capacity we make available to Morgan Stanley Capital Group, Morgan Stanley Capital Group's minimum revenue commitment would be reduced proportionately for the duration of the force majeure event.

        Morgan Stanley Capital Group may not assign the terminaling services agreement without our consent.

        Terminaling services agreement—Collins/Purvis terminal.    In January 2010, we entered into a terminaling services agreement with Morgan Stanley Capital Group relating to our Collins, Mississippi facility that will expire in June 2018, subject to one-year automatic renewals unless terminated by either party upon 180 days prior notice. In exchange for its minimum revenue commitment, we agreed to undertake certain capital projects to provide an additional 700,000 barrels of light oil capacity and other improvements at the Collins terminal. These capital projects were completed and placed into

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(2) TRANSACTIONS WITH AFFILIATES (Continued)

service in July 2011. Under this agreement, Morgan Stanley Capital Group has agreed to throughput a volume of light oil products at our terminal that will, at the fee schedule contained in the agreement, result in minimum throughput payments to us of approximately $4.1 million for the one-year period following the in-service date of July 2011 for the aforementioned capital projects, and for each contract year thereafter.

        If a force majeure event occurs that renders performance impossible with respect to an asset for at least 30 consecutive days, Morgan Stanley Capital Group's obligations would be temporarily suspended with respect to that asset. If a force majeure event continues for 30 consecutive days or more and results in a diminution in the storage capacity we make available to Morgan Stanley Capital Group, Morgan Stanley Capital Group's minimum revenue commitment would be reduced proportionately for the duration of the force majeure event.

        Neither party may transfer or assign this agreement without the consent of the other party unless such assignment is to an affiliate or, in the case of Partners, a successor in interest to us or to the Collins terminal.

(3) TERMINAL ACQUISITIONS AND DISPOSITIONS

        Contribution of certain Brownsville, Texas terminal assets to the Frontera joint venture.    Effective as of April 1, 2011, we entered into the Frontera joint venture with P.M.I. Services North America Inc. ("PMI"), an indirect subsidiary of Petroleos Mexicanos ("Pemex"), the Mexican state-owned petroleum company, at our Brownsville, Texas terminal. We contributed approximately 1.5 million barrels of light petroleum product storage capacity, as well as related ancillary facilities, to Frontera in exchange for a cash payment of approximately $25.6 million and a 50% ownership interest. PMI acquired a 50% ownership interest in Frontera for a cash payment of approximately $25.6 million. We operate the Frontera assets under an operations and reimbursement agreement executed between us and Frontera. We continue to own and operate approximately 0.9 million barrels of tankage in Brownsville independent of Frontera.

        The assets contributed to Frontera constitute a business that we no longer control. We accounted for the deconsolidation of these assets by recognizing a gain on disposition of assets of approximately $9.6 million in the second quarter of 2011. The gain was measured as the difference between the carrying amount of the contributed assets and the aggregate of the cash we received and the fair value of the 50% interest we retained in Frontera. At the time of our contribution of assets to Frontera, the carrying amount of the contributed assets was approximately $41.6 million and consisted of the following as of April 1, 2011 (in thousands):

Other current assets

  $ 98  

Property, plant and equipment, net

    33,244  

Goodwill

    7,481  

Other assets, net—customer relationships, net

    787  
       

Total carrying amount

  $ 41,610  
       

        We account for our investment in Frontera, 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

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Notes to consolidated financial statements (unaudited) (Continued)

(3) TERMINAL ACQUISITIONS AND DISPOSITIONS (Continued)

investment was initially recorded at approximately $25.6 million, which was the fair value of our 50% ownership interest on April 1, 2011.

        Acquisition of Pensacola terminal.    Effective as of March 1, 2011, we acquired from TransMontaigne Inc. its Pensacola, Florida refined petroleum products terminal with approximately 270,000 barrels of aggregate active storage capacity for a cash payment of approximately $12.8 million. The Pensacola terminal provides integrated terminaling services principally to a third party customer. The acquisition of the Pensacola terminal from TransMontaigne Inc. has been recorded at carryover basis in a manner similar to a reorganization of entities under common control. As TransMontaigne Inc. controls our general partner, the difference between the consideration we paid to TransMontaigne Inc. and the carryover basis of the net assets purchased has been reflected in the accompanying consolidated balance sheet and statement of partners' equity as an increase to the general partner's equity interest. The accompanying consolidated financial statements include the assets, liabilities and results of operations of the Pensacola Terminal from March 1, 2011.

        The carryover basis in the assets and liabilities of the Pensacola terminal as of March 1, 2011 was as follows (in thousands):

Cash and cash equivalents

  $ 1  

Other current assets

    61  

Property, plant and equipment, net

    13,232  

Accrued liabilities

    (45 )
       

Total carryover basis

  $ 13,249  
       

(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, and in the Midwest. We have a concentration of trade receivable balances due from companies engaged in the trading, distribution and marketing of refined products and crude oil and the United States government. 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. We maintain allowances for potentially uncollectible accounts receivable.

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

 
  September 30,
2012
  December 31,
2011
 

Trade accounts receivable

  $ 5,096   $ 4,471  

Less allowance for doubtful accounts

    (200 )   (200 )
           

  $ 4,896   $ 4,271  
           

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(4) CONCENTRATION OF CREDIT RISK AND TRADE ACCOUNTS RECEIVABLE (Continued)

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

 
  Three
months
ended
September 30,
  Nine
months
ended
September 30,
 
 
  2012   2011   2012   2011  

Morgan Stanley Capital Group

    64 %   65 %   64 %   64 %

(5) OTHER CURRENT ASSETS

        Other current assets are as follows (in thousands):

 
  September 30, 2012   December 31, 2011  

Amounts due from insurance companies

  $ 2,845   $ 2,695  

Amounts due from the sale of the BOSTCO project

        18,000  

Additive detergent

    1,699     1,812  

Deposits and other assets

    319     261  
           

  $ 4,863   $ 22,768  
           

        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 September 30, 2012 and December 31, 2011, we have recognized amounts due from insurance companies of approximately $2.8 million and $2.7 million, respectively, representing our best estimate of our probable insurance recoveries. During the three and nine months ended September 30, 2012, we received reimbursements from insurance companies of approximately $0.4 million and $1.1 million, respectively. During the three and nine months ended September 30, 2012, we increased our estimate of insurance recoveries approximately $1.2 million and $1.2 million, respectively, to reflect a change in our estimate of our future environmental remediation costs (see Note 9 of Notes to consolidated financial statements).

        Amounts due from the sale of the BOSTCO project.    On December 29, 2011 we sold our remaining interest in the BOSTCO project for $18 million and a transferrable purchase option to buy back into the project at any time prior to January 20, 2013. The BOSTCO project constitutes the development of a 6.1 million barrel black oil storage terminal on the Houston Ship Channel. At this time we are unable to predict whether we will be able to exercise the purchase option or be able to sell the option. Accordingly, no amount for the value of this option has been reflected in our financial statements due to the uncertainty surrounding this gain contingency. The $18 million in cash consideration was received on January 3, 2012 and, accordingly, has been reflected as amounts due at December 31, 2011.

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Notes to consolidated financial statements (unaudited) (Continued)

(6) PROPERTY, PLANT AND EQUIPMENT, NET

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

 
  September 30,
2012
  December 31,
2011
 

Land

  $ 52,652   $ 52,641  

Terminals, pipelines and equipment

    547,699     524,346  

Furniture, fixtures and equipment

    1,588     1,507  

Construction in progress

    2,475     8,745  
           

    604,414     587,239  

Less accumulated depreciation

    (176,332 )   (155,457 )
           

  $ 428,082   $ 431,782  
           

(7) GOODWILL

        Goodwill is as follows (in thousands):

 
  September 30,
2012
  December 31,
2011
 

Brownsville terminals (includes approximately $52 and $75, respectively, of foreign currency translation adjustments)

  $ 8,739   $ 8,716  

        The acquisition of the Brownsville terminals from TransMontaigne Inc. has been recorded at TransMontaigne Inc.'s carryover basis in a manner similar to a reorganization of entities under common control. TransMontaigne Inc.'s carryover basis in the Brownsville terminals is derived from the application of pushdown accounting associated with Morgan Stanley Capital Group's acquisition of TransMontaigne Inc. on September 1, 2006. Goodwill represents the excess of Morgan Stanley Capital Group's aggregate purchase price over the fair value of the identifiable assets acquired attributable to the Brownsville terminals.

        Included in the Brownsville terminals' operating segment are the results of the Mexican LPG operations. The adjusted purchase price for the acquisition of the Mexican LPG operations from Rio Vista Energy Partners L.P. was allocated to the identifiable assets and liabilities acquired based upon the estimated fair value of the assets and liabilities as of the acquisition date. Goodwill of approximately $1.5 million was recorded and represents the excess of our adjusted purchase price over the fair value of the identifiable assets acquired attributable to the Mexican LPG operations.

        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 17 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.

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Notes to consolidated financial statements (unaudited) (Continued)

(8) OTHER ASSETS, NET

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

 
  September 30,
2012
  December 31,
2011
 

Amounts due under long-term terminaling services agreements:

             

External customers

  $ 660   $ 760  

Morgan Stanley Capital Group

    3,798     4,146  
           

    4,458     4,906  

Deferred financing costs, net of accumulated amortization of $1,123 and $561, respectively

    2,557     3,119  

Customer relationships, net of accumulated amortization of $1,232 and $1,080, respectively

    1,198     1,350  

Deposits and other assets

    272     273  
           

  $ 8,485   $ 9,648  
           

        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 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 term of the respective agreements. At September 30, 2012 and December 31, 2011, we have recognized revenue in excess of the minimum payments that are due through those respective dates under the long-term terminaling services agreements resulting in an asset of approximately $4.5 million and $4.9 million, respectively.

        Deferred financing costs.    Deferred financing costs are amortized using the effective interest method over the term of the related credit facility (see Note 11 of Notes to consolidated financial statements).

        Customer relationships.    Our acquisitions from TransMontaigne Inc. have been recorded at TransMontaigne Inc.'s carryover basis in a manner similar to a reorganization of entities under common control. Other assets, net include the carryover basis of certain customer relationships at our River terminals. The carryover basis of the customer relationships is being amortized on a straight-line basis over twelve years.

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Notes to consolidated financial statements (unaudited) (Continued)

(9) ACCRUED LIABILITIES

        Accrued liabilities are as follows (in thousands):

 
  September 30,
2012
  December 31,
2011
 

Customer advances and deposits:

             

External customers

  $ 1,412   $ 1,364  

Morgan Stanley Capital Group

    6,408     6,378  
           

    7,820     7,742  

Accrued property taxes

    3,394     558  

Accrued environmental obligations

    3,331     2,887  

Interest payable

    38     48  

Rebate due to Morgan Stanley Capital Group

    2,369     5,877  

Accrued expenses and other

    3,321     2,812  
           

  $ 20,273   $ 19,924  
           

        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 September 30, 2012 and December 31, 2011, we have billed and collected from certain of our customers approximately $7.8 million and $7.7 million, respectively, in advance of the terminaling services being provided.

        Accrued environmental obligations.    At September 30, 2012 and December 31, 2011, we have accrued environmental obligations of approximately $3.3 million and $2.9 million, respectively, representing our best estimate of our remediation obligations. During the three and nine months ended September 30, 2012, we made payments of approximately $0.2 million and $0.7 million, respectively, towards our environmental remediation obligations. During the three and nine months ended September 30, 2012, we increased our remediation obligations by approximately $1.4 million and $1.1 million, respectively, to reflect a change in our estimate of our future environmental remediation costs. 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.

        Rebate due to Morgan Stanley Capital Group.    Pursuant to our terminaling services agreement related to the Southeast terminals, we agreed to rebate to Morgan Stanley Capital Group 50% of the proceeds we receive annually in excess of $4.2 million from the sale of product gains at our Southeast terminals. At September 30, 2012 and December 31, 2011, we have accrued a liability due to Morgan Stanley Capital Group of approximately $2.4 million and $5.9 million, respectively. In March 2012, we paid Morgan Stanley Capital Group approximately $5.9 million for the rebate due to Morgan Stanley Capital Group for the year ended December 31, 2011.

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Notes to consolidated financial statements (unaudited) (Continued)

(10) OTHER LIABILITIES

        Other liabilities are as follows (in thousands):

 
  September 30,
2012
  December 31,
2011
 

Advance payments received under long-term terminaling services agreements

  $ 1,120   $ 1,121  

Deferred revenue—ethanol blending fees and other projects

    10,299     13,247  
           

  $ 11,419   $ 14,368  
           

        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 September 30, 2012 and December 31, 2011, we have received advance minimum payments in excess of revenue recognized under these long-term terminaling services agreements resulting in a liability of approximately $1.1 million and $1.1 million, respectively.

        Deferred revenue—ethanol blending fees and other projects.    Pursuant to agreements with Morgan Stanley Capital Group, we agreed to undertake certain capital projects that primarily pertain to providing ethanol blending functionality at certain of our Southeast terminals and other projects. Upon completion of the projects, Morgan Stanley Capital Group and others have paid us lump-sum amounts that will be recognized as revenue on a straight-line basis over the remaining term of the agreements. At September 30, 2012 and December 31, 2011, we have unamortized deferred revenue of approximately $10.3 million and $13.2 million, respectively, for completed projects. During the three and nine months ended September 30, 2012, we recorded deferred revenue of approximately $0.1 million and $0.6 million, respectively, for completed projects. During the three months ended September 30, 2012 and 2011, we recognized revenue on a straight-line basis of approximately $1.2 million and $1.1 million, respectively, for completed projects. During the nine months ended September 30, 2012 and 2011, we recognized revenue on a straight-line basis of approximately $3.5 million and $3.4 million, respectively, for completed projects.

(11) LONG-TERM DEBT

        On March 9, 2011, we entered into an amended and restated senior secured credit facility, or credit facility. The credit facility replaced in its entirety the senior secured credit facility that was in place as of December 31, 2010. The credit facility provides for a maximum borrowing line of credit equal to the lesser of (i) $250 million and (ii) 4.75 times Consolidated EBITDA (as defined: $354.3 million at September 30, 2012). In addition, at our request, the revolving loan commitment can be increased up to an additional $100 million, in the aggregate, without the approval of the lenders, but subject to the approval of the administrative agent and the receipt of additional commitments from one or more lenders. We may elect to have loans under the credit facility bear interest either (i) at a rate of LIBOR plus a margin ranging from 2% to 3% depending on the total leverage ratio then in effect, or (ii) at the base rate plus a margin ranging from 1% to 2% 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 the

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Notes to consolidated financial statements (unaudited) (Continued)

(11) LONG-TERM DEBT (Continued)

credit facility are secured by a first priority security interest in favor of the lenders in the majority of our assets.

        The terms of the 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 "permitted JV investments" which may not exceed $125 million in the aggregate and subject to us having at least $50 million in "liquidity" before and after giving effect to such joint venture investment. The principal balance of loans and any accrued and unpaid interest are due and payable in full on the maturity date, March 9, 2016.

        The 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 the credit facility are (i) a total leverage ratio test (not to exceed 4.75 times), (ii) a senior secured leverage ratio test (not to exceed 3.75 times) in the event we issue senior unsecured notes, and (iii) a minimum interest coverage ratio test (not less than 3.0 times). We were in compliance with all of the covenants under the credit facility as of September 30, 2012.

        For the three months ended September 30, 2012 and 2011, the weighted average interest rate on borrowings under the credit facility was approximately 2.2% and 2.2%, respectively. For the nine months ended September 30, 2012 and 2011, the weighted average interest rate on borrowings under the applicable credit facility was approximately 2.3% and 3.6%, respectively. At September 30, 2012 and December 31, 2011, our outstanding borrowings under the credit facility were $102 million and $120 million, respectively. At September 30, 2012 and December 31, 2011, our outstanding letters of credit were $nil at both dates.

(12) PARTNERS' EQUITY

        The number of units outstanding is as follows:

 
  Common units   General partner units  

Units outstanding at December 31, 2011 and September 30, 2012

    14,457,066     295,042  

        At September 30, 2012 and December 31, 2011, common units outstanding include approximately 15,900 and 16,900 common units, respectively, held on behalf of TransMontaigne Services Inc.'s long-term incentive plan.

(13) LONG-TERM INCENTIVE PLAN

        TransMontaigne GP is our general partner and manages our operations and activities. TransMontaigne GP is an indirect wholly owned subsidiary of TransMontaigne Inc. TransMontaigne Services Inc. is an indirect wholly owned subsidiary of TransMontaigne Inc. TransMontaigne

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Notes to consolidated financial statements (unaudited) (Continued)

(13) LONG-TERM INCENTIVE PLAN (Continued)

Services Inc. employs the personnel who provide support to TransMontaigne Inc.'s operations, as well as our operations. TransMontaigne Services Inc. adopted a long-term incentive plan for its employees and consultants and the independent directors of our general partner. The long-term incentive plan currently permits the grant of awards covering an aggregate of 1,816,745 units, which amount will automatically increase on an annual basis by 2% of the total outstanding common and subordinated units, if any, at the end of the preceding fiscal year. At September 30, 2012, 1,583,933 units are available for future grant under the long-term incentive plan. Ownership in the awards is subject to forfeiture until the vesting date, but recipients have distribution and voting rights from the date of grant. Pursuant to the terms of the long-term incentive plan, all restricted phantom units and restricted common units vest upon a change in control of TransMontaigne Inc. The long-term incentive plan is administered by the compensation committee of the board of directors of our general partner. TransMontaigne GP purchases outstanding common units on the open market for purposes of making grants of restricted phantom units to independent directors of our general partner.

        TransMontaigne GP, on behalf of the long-term incentive plan, has purchased 5,100 and 6,110 common units pursuant to the program during the nine months ended September 30, 2012 and 2011, respectively. In addition to the foregoing purchases, upon the vesting of 10,000 restricted phantom units on August 10, 2012 and 2011, we purchased 5,891 and 5,892 common units, respectively, from TransMontaigne Services Inc. for the purpose of delivering these units to Charles L. Dunlap, the Chief Executive Officer ("CEO") of our general partner. These units were granted to Mr. Dunlap on August 10, 2009 under the long-term incentive plan. The amount of the units purchased for delivery to Mr. Dunlap varies based upon the funding of the related withholding taxes.

        Information about restricted phantom unit activity for the year ended December 31, 2011 and the nine months ended September 30, 2012 is as follows:

 
  Available for
future grant
  Restricted
phantom
units
  NYSE
closing
price
 

Units outstanding at December 31, 2010

    1,008,523     44,500        

Automatic increase in units available for future grant on January 1, 2011

    289,141            

Grant on March 31, 2011

    (8,000 )   8,000   $ 36.33  

Vesting on March 31, 2011

        (5,500 ) $ 36.33  

Vesting on August 10, 2011

        (10,000 ) $ 32.29  

Units withheld for taxes on August 10, 2011

    4,108            
                 

Units outstanding at December 31, 2011

    1,293,772     37,000        

Automatic increase in units available for future grant on January 1, 2012

    289,141            

Grant on March 31, 2012

    (8,000 )   8,000   $ 34.76  

Vesting on March 31, 2012

        (6,500 ) $ 34.76  

Units withheld for taxes on March 31, 2012

    411            

Units forfeited on July 18, 2012

    4,500     (4,500 )      

Vesting on August 10, 2012

        (10,000 ) $ 36.48  

Units withheld for taxes on August 10, 2012

    4,109            
                 

Units outstanding at September 30, 2012

    1,583,933     24,000        
                 

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Notes to consolidated financial statements (unaudited) (Continued)

(13) LONG-TERM INCENTIVE PLAN (Continued)

        On March 31, 2012 and 2011, TransMontaigne Services Inc. granted 8,000 and 8,000 restricted phantom units, respectively, to the independent directors of our general partner. Over their respective four-year vesting periods, we will recognize deferred equity-based compensation of approximately $0.3 million and $0.3 million, associated with the March 2012 and March 2011 grants, respectively.

        Deferred equity-based compensation of approximately $114,000 and $107,000 is included in direct general and administrative expenses for the three months ended September 30, 2012 and 2011, respectively. Deferred equity-based compensation of approximately $321,000 and $312,000 is included in direct general and administrative expenses for the nine months ended September 30, 2012 and 2011, respectively.

        On July 18, 2012, Mr. Henry M. Kuchta forfeited the vesting of 4,500 restricted phantom units as a result of his resignation as a member of the board of directors of our general partner.

        Effective August 10, 2009, Charles L. Dunlap was appointed to serve as CEO of our general partner and President and CEO of TransMontaigne Inc. In connection with his appointments, on August 10, 2009, TransMontaigne Services Inc. granted Mr. Dunlap 40,000 restricted phantom units under the long-term incentive plan. In accordance with the long-term incentive plan, because Mr. Dunlap continues to provide services to our general partner as an employee, the restricted phantom units previously granted to Mr. Dunlap for his services as an independent member of the board of directors of our general partner remain in effect and continue to vest in accordance with the four-year vesting schedule applicable for the grants to our independent directors. Over the respective four-year vesting period, we will recognize deferred equity-based compensation of approximately $1.0 million associated with the August 2009 grant.

(14) COMMITMENTS AND CONTINGENCIES

        Contract commitments.    At September 30, 2012, we have contractual commitments of approximately $10.7 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 during the remainder of the year ending December 31, 2012.

        Operating leases.    We lease property and equipment under non-cancelable operating leases that extend through August 2030. At September 30, 2012, future minimum lease payments under these non-cancelable operating leases are as follows (in thousands):

Years ending December 31:
  Property and
equipment
 

2012 (remainder of the year)

  $ 376  

2013

    1,483  

2014

    1,502  

2015

    1,515  

2016

    1,539  

Thereafter

    4,838  
       

  $ 11,253  
       

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Notes to consolidated financial statements (unaudited) (Continued)

(14) COMMITMENTS AND CONTINGENCIES (Continued)

        Included in the above non-cancelable operating lease commitments are amounts for property rentals that we have sublet under non-cancelable sublease agreements, for which we expect to receive minimum rentals of approximately $2.1 million in future periods.

        Rental expense under operating leases was approximately $0.4 million and $0.3 million for the three months ended September 30, 2012 and 2011, respectively. Rental expense under operating leases was approximately $1.0 million and $0.9 million for the nine months ended September 30, 2012 and 2011, respectively.

(15) NET EARNINGS PER LIMITED PARTNER UNIT

        The following table reconciles net earnings to net earnings allocable to limited partners (in thousands):

 
  Three months ended
September 30,
  Nine months ended
September 30,
 
 
  2012   2011   2012   2011  

Net earnings

  $ 9,853   $ 7,666   $ 31,649   $ 36,020  

Less:

                         

Distributions payable on behalf of incentive distribution rights

    (1,154 )   (871 )   (3,320 )   (2,472 )

Distributions payable on behalf of general partner interest

    (189 )   (183 )   (564 )   (546 )

Earnings allocable to the general partner interest less than (in excess of) distributions payable to the general partner interest

    15     47     (4 )   (195 )
                   

Earnings allocable to general partner interest including incentive distribution rights

    (1,328 )   (1,007 )   (3,888 )   (3,213 )
                   

Net earnings allocable to limited partners

  $ 8,525   $ 6,659   $ 27,761   $ 32,807  
                   

        Earnings allocated to the general partner interest include amounts attributable to the incentive distribution rights. 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 net earnings allocated to the general partner interest in the consolidated statements of partners' equity reflect the earnings allocation included in the table above.

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Notes to consolidated financial statements (unaudited) (Continued)

(15) NET EARNINGS PER LIMITED PARTNER UNIT (Continued)

        The following table sets forth the distribution declared per common unit attributable to the periods indicated:

 
  Distribution  

January 1, 2011 through March 31, 2011

  $ 0.61  

April 1, 2011 through June 30, 2011

  $ 0.62  

July 1, 2011 through September 30, 2011

  $ 0.62  

October 1, 2011 through December 31, 2011

  $ 0.63  

January 1, 2012 through March 31, 2012

  $ 0.63  

April 1, 2012 through June 30, 2012

  $ 0.64  

July 1, 2012 through September 30, 2012

  $ 0.64  

        The following table reconciles the computation of basic and diluted weighted average units (in thousands):

 
  Three months ended
September 30,
  Nine months ended
September 30,
 
 
  2012   2011   2012   2011  

Basic weighted average units

    14,442     14,442     14,442     14,442  

Dilutive effect of restricted phantom units

    5     11     5     12  
                   

Diluted weighted average units

    14,447     14,453     14,447     14,454  
                   

        For the three and nine months ended September 30, 2012, we included the dilutive effect of approximately 2,000, 10,000 and 1,500 restricted phantom units granted March 31, 2010, August 10, 2009 and March 31, 2009, respectively, in the computation of diluted earnings per limited partner unit because the average closing market price of our common units exceeded the related remaining deferred compensation per unvested restricted phantom units. For the three and nine months ended September 30, 2011, we included the dilutive effect of approximately 8,000, 4,500, 20,000, 3,000, 500 and 1,000 restricted phantom units granted March 31, 2011, March 31, 2010, August 10, 2009, March 31, 2009, July 18, 2008 and March 31, 2008, respectively, in the computation of diluted earnings per limited partner unit because the average closing market price of our common units exceeded the related remaining deferred compensation per unvested restricted phantom units.

        We exclude potentially dilutive securities from our computation of diluted earnings per limited partner unit when their effect would be anti-dilutive. For the three and nine months ended September 30, 2012, we excluded the dilutive effect of approximately 6,000 and 4,500 restricted phantom units granted March 31, 2012 and March 31, 2011, respectively, in the computation of diluted earnings per limited partner unit because the related remaining deferred compensation per unvested restricted phantom units exceeded the average closing market price of our common units for the period.

(16) DISCLOSURES ABOUT FAIR VALUE

        Generally accepted accounting principles defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. Generally accepted accounting principles also establishes a fair value hierarchy that prioritizes the use of higher-level inputs for

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Notes to consolidated financial statements (unaudited) (Continued)

(16) DISCLOSURES ABOUT FAIR VALUE (Continued)

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 September 30, 2012 and December 31, 2011.

        Cash and cash equivalents, trade receivables and trade accounts payable.    The carrying amount approximates fair value because of the short-term maturity of these instruments.

        Debt.    The carrying amount under our credit facility approximates fair value since borrowings under the facility bear interest at current market interest rates.

(17) 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 CEO. Our general partner's CEO 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 and (v) Southeast terminals.

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Notes to consolidated financial statements (unaudited) (Continued)

(17) BUSINESS SEGMENTS (Continued)

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

 
  Three months ended
September 30,
  Nine months ended
September 30,
 
 
  2012   2011   2012   2011  

Gulf Coast Terminals:

                         

Terminaling services fees, net

  $ 11,959   $ 11,730   $ 35,871   $ 34,786  

Other

    2,302     1,781     7,822     7,423  
                   

Revenue

    14,261     13,511     43,693     42,209  

Direct operating costs and expenses

    (5,407 )   (5,191 )   (15,452 )   (15,780 )
                   

Net margins

    8,854     8,320     28,241     26,429  
                   

Midwest Terminals and Pipeline System:

                         

Terminaling services fees, net

    1,605     949     3,415     2,836  

Pipeline transportation fees

    463     504     1,451     1,427  

Other

    947     413     2,671     1,521  
                   

Revenue

    3,015     1,866     7,537     5,784  

Direct operating costs and expenses

    (551 )   (534 )   (1,328 )   (1,424 )
                   

Net margins

    2,464     1,332     6,209     4,360  
                   

Brownsville Terminals:

                         

Terminaling services fees, net

    1,576     1,602     4,481     7,556  

Pipeline transportation fees

    805     565     2,543     1,815  

Other

    2,201     2,034     6,224     5,862  
                   

Revenue

    4,582     4,201     13,248     15,233  

Direct operating costs and expenses

    (3,232 )   (3,185 )   (8,006 )   (9,731 )
                   

Net margins

    1,350     1,016     5,242     5,502  
                   

River Terminals:

                         

Terminaling services fees, net

    3,292     3,171     9,913     9,078  

Other

    173     183     751     321  
                   

Revenue

    3,465     3,354     10,664     9,399  

Direct operating costs and expenses

    (2,113 )   (2,311 )   (6,764 )   (5,802 )
                   

Net margins

    1,352     1,043     3,900     3,597  
                   

Southeast Terminals:

                         

Terminaling services fees, net

    11,735     11,584     35,097     33,062  

Other

    1,816     2,569     5,910     7,366  
                   

Revenue

    13,551     14,153     41,007     40,428  

Direct operating costs and expenses

    (4,867 )   (5,269 )   (14,773 )   (15,966 )
                   

Net margins

    8,684     8,884     26,234     24,462  
                   

Total net margins

    22,704     20,595     69,826     64,350  

Direct general and administrative expenses

    (1,204 )   (1,060 )   (3,607 )   (3,240 )

Allocated general and administrative expenses

    (2,695 )   (2,616 )   (8,085 )   (7,849 )

Allocated insurance expense

    (897 )   (823 )   (2,692 )   (2,468 )

Reimbursement of bonus awards

    (313 )   (313 )   (938 )   (938 )

Depreciation and amortization

    (7,112 )   (6,873 )   (20,982 )   (20,733 )

Gain on disposition of assets

                9,576  

Equity in earnings (loss) of joint venture

    217     (285 )   652     (52 )
                   

Operating income

    10,700     8,625     34,174     38,646  

Other expenses, net

    (847 )   (959 )   (2,525 )   (2,626 )
                   

Net earnings

  $ 9,853   $ 7,666   $ 31,649   $ 36,020  
                   

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (Continued)

(17) BUSINESS SEGMENTS (Continued)

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

 
  Three months ended September 30, 2012  
 
  Gulf Coast
Terminals
  Midwest
Terminals and
Pipeline System
  Brownsville
Terminals
  River
Terminals
  Southeast
Terminals
  Total  

Revenue:

                                     

External customers

  $ 3,758   $ 645   $ 2,530   $ 3,461   $ 898   $ 11,292  

Morgan Stanley Capital Group

    10,035     2,370         4     12,641     25,050  

Frontera

            930             930  

TransMontaigne Inc. 

    468         1,122         12     1,602  
                           

Total revenue

  $ 14,261   $ 3,015   $ 4,582   $ 3,465   $ 13,551   $ 38,874  
                           

Capital expenditures

  $ 172   $ 4,629   $ 343   $ 558   $ 581   $ 6,283  
                           

Identifiable assets

  $ 138,281   $ 26,366   $ 49,939   $ 60,155   $ 181,770   $ 456,511  
                           

    Cash and cash equivalents     6,938  

    Investment in joint venture     25,836  

    Deferred financing costs     2,557  

    Other     407  
                                     

   

Total assets

  $ 492,249  
                                     

 

 
  Three months ended September 30, 2011  
 
  Gulf Coast
Terminals
  Midwest
Terminals and
Pipeline System
  Brownsville
Terminals
  River
Terminals
  Southeast
Terminals
  Total  

Revenue:

                                     

External customers

  $ 3,667   $ 537   $ 2,544   $ 3,333   $ 721   $ 10,802  

Morgan Stanley Capital Group

    9,381     1,329         21     13,419     24,150  

Frontera

            632             632  

TransMontaigne Inc. 

    463         1,025         13     1,501  
                           

Total revenue

  $ 13,511   $ 1,866   $ 4,201   $ 3,354   $ 14,153   $ 37,085  
                           

Capital expenditures

  $ 186   $ 228   $ 215   $ 616   $ 2,895   $ 4,140  
                           

Identifiable assets

  $ 144,597   $ 12,247   $ 51,304   $ 59,408   $ 192,026   $ 459,582  
                           

    Cash and cash equivalents     5,270  

    Investment in joint venture     25,905  

    Investment in the BOSTCO project     22,139  

    Deferred financing costs     3,306  

    Other     342  
                                     

   

Total assets

  $ 516,544  
                                     

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TransMontaigne Partners L.P. and subsidiaries

Notes to consolidated financial statements (unaudited) (Continued)

(17) BUSINESS SEGMENTS (Continued)

 

 
  Nine months ended September 30, 2012  
 
  Gulf Coast
Terminals
  Midwest
Terminals and
Pipeline System
  Brownsville
Terminal
  River
Terminals
  Southeast
Terminals
  Total  

Revenue:

                                     

External customers

  $ 11,519   $ 2,121   $ 7,303   $ 10,646   $ 2,513   $ 34,102  

Morgan Stanley Capital Group

    30,771     5,416         18     38,456     74,661  

Frontera

            2,484             2,484  

TransMontaigne Inc. 

    1,403         3,461         38     4,902  
                           

Total revenue

  $ 43,693   $ 7,537   $ 13,248   $ 10,664   $ 41,007   $ 116,149  
                           

Capital expenditures

  $ 743   $ 11,172   $ 945   $ 2,445   $ 1,480   $ 16,785  
                           

Identifiable assets

  $ 138,281   $ 26,366   $ 49,939   $ 60,155   $ 181,770   $ 456,511  
                           

 

 
  Nine months ended September 30, 2011  
 
  Gulf Coast
Terminals
  Midwest
Terminals and
Pipeline System
  Brownsville
Terminal
  River
Terminals
  Southeast
Terminals
  Total  

Revenue:

                                     

External customers

  $ 10,456   $ 1,771   $ 10,795   $ 9,326   $ 2,186   $ 34,534  

Morgan Stanley Capital Group

    30,374     4,013         73     38,203     72,663  

Frontera

            1,234             1,234  

TransMontaigne Inc. 

    1,379           3,204           39     4,622  
                           

Total revenue

  $ 42,209   $ 5,784   $ 15,233   $ 9,399   $ 40,428   $ 113,053  
                           

Capital expenditures

  $ 806   $ 233   $ 1,379   $ 1,408   $ 12,971   $ 16,797  
                           

Identifiable assets

  $ 144,597   $ 12,247   $ 51,304   $ 59,408   $ 192,026   $ 459,582  
                           

(18) SUBSEQUENT EVENT

        On October 15, 2012, we announced a distribution of $0.64 per unit for the period from July 1, 2012 through September 30, 2012, payable on November 6, 2012 to unitholders of record on October 31, 2012.

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

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, 2011, included in our Annual Report on Form 10-K/A, Amendment No. 1, filed on May 3, 2012 (see Note 1 of Notes to consolidated financial statements). 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: useful lives of our plant and equipment, accrued environmental obligations and determining the fair value of our reporting units when analyzing goodwill. 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.

SIGNIFICANT DEVELOPMENTS DURING THE THREE MONTHS ENDED SEPTEMBER 30, 2012

        On July 16, 2012, we announced a distribution of $0.64 per unit for the period from April 1, 2012 through June 30, 2012, payable on August 7, 2012 to unitholders of record on July 31, 2012.

        On July 18, 2012, Mr. Henry M. Kuchta resigned from the board of directors of our general partner and from the audit and conflicts committees of our general partner. In his letter of resignation, Mr. Kuchta indicated that there were no disagreements between himself and Partners or the board of directors of our general partner regarding Partners' operations, policies or practices.

        As of August 1, 2012 we completed the construction of one million barrels of crude oil storage tankage in Cushing, Oklahoma. As previously disclosed, we have entered into a long-term terminaling services agreement with Morgan Stanley Capital Group for the use of this facility. Under this agreement, Morgan Stanley Capital Group agreed to throughput a volume of crude oil at our Cushing, Oklahoma terminal that will, at the fee schedule contained in the agreement, result in minimum throughput payments to us of approximately $4.3 million for each one-year period following the in-service date of August 1, 2012 through July 31, 2019.

SUBSEQUENT EVENT

        On October 15, 2012, we announced a distribution of $0.64 per unit for the period from July 1, 2012 through September 30, 2012, payable on November 6, 2012 to unitholders of record on October 31, 2012.

RESULTS OF OPERATIONS—THREE MONTHS ENDED SEPTEMBER 30, 2012 AND 2011

        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

 
  Three months
ended
September 30,
 
 
  2012   2011  

Terminaling services fees, net

  $ 30,167   $ 29,036  

Pipeline transportation fees

    1,268     1,069  

Management fees and reimbursed costs

    1,531     1,126  

Other

    5,908     5,854  
           

Revenue

  $ 38,874   $ 37,085  
           

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

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


Total Revenue by Business Segment

 
  Three months
ended
September 30,
 
 
  2012   2011  

Gulf Coast terminals

  $ 14,261   $ 13,511  

Midwest terminals and pipeline system

    3,015     1,866  

Brownsville terminals

    4,582     4,201  

River terminals

    3,465     3,354  

Southeast terminals

    13,551     14,153  
           

Revenue

  $ 38,874   $ 37,085  
           

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

        Terminaling services fees, net.    Pursuant to terminaling services agreements with our customers, which range from one month to seven years in duration, we generate fees by distributing and storing products for our customers. Terminaling services fees, net include throughput fees based on the volume of product distributed from the facility, injection fees based on the volume of product injected with

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additive compounds and storage fees based on a rate per barrel of storage capacity per month. The terminaling services fees, net by business segments were as follows (in thousands):


Terminaling Services Fees, Net, by Business Segment

 
  Three months
ended
September 30,
 
 
  2012   2011  

Gulf Coast terminals

  $ 11,959   $ 11,730  

Midwest terminals and pipeline system

    1,605     949  

Brownsville terminals

    1,576     1,602  

River terminals

    3,292     3,171  

Southeast terminals

    11,735     11,584  
           

Terminaling services fees, net

  $ 30,167   $ 29,036  
           

        The increase in terminaling services fees, net includes an increase of approximately $0.7 million resulting from newly constructed tank capacity placed into service during August of 2012 at our Cushing, Oklahoma facility in the Midwest region.

        Included in terminaling services fees, net for the three months ended September 30, 2012 and 2011 are fees recognized from agreements with Morgan Stanley Capital Group of approximately $20.5 million and $19.8 million, respectively, and TransMontaigne Inc. of approximately $0.8 million and $0.9 million, respectively.

        Our terminaling services agreements are structured as either throughput agreements or storage agreements. Most of our throughput agreements contain provisions that require our customers to throughput a minimum volume of product at our facilities over a stipulated period of time, which results in a fixed amount of revenue to be recognized by us. 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 revenue to be recognized by us. 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 "variable." The "firm commitments" and "variable" revenue included in terminaling services fees, net were as follows (in thousands):


Firm Commitments and Variable Revenue

 
  Three months
ended
September 30,
 
 
  2012   2011  

Firm commitments:

             

External customers

  $ 8,300   $ 7,907  

Affiliates

    21,345     20,752  
           

Total

    29,645     28,659  
           

Variable:

             

External customers

    562     450  

Affiliates

    (40 )   (73 )
           

Total

    522     377  
           

Terminaling services fees, net

  $ 30,167   $ 29,036  
           

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        At September 30, 2012, the remaining terms on the terminaling services agreements that generated "firm commitments" for the three months ended September 30, 2012 were as follows (in thousands):

 
  At
September 30,
2012
 

Remaining terms on terminaling services agreements that generated "firm commitments":

       

Less than 1 year remaining

  $ 4,039  

1 year or more, but less than 3 years remaining

    20,495  

3 years or more, but less than 5 years remaining

    3,356  

5 years or more remaining

    1,755  
       

Total firm commitments for the three months ended September 30, 2012

  $ 29,645  
       

        We have a terminaling services agreement with Valero Marketing and Supply Company, which we refer to as Valero, for approximately 1.1 million barrels of light refined product storage capacity (out of approximately 23.4 million barrels of active storage capacity across our system), in the aggregate, at our Cape Girardeau, Evansville, Greenville, Henderson, Owensboro and Paducah terminals that expires on April 1, 2013. In July 2012 we began preliminary discussions with Valero to renew the terminaling services agreement. At this time we are unsure what the outcome of these negotiations will be. See "Item 1A. Risk Factors" in our Annual Report on Form 10-K/A, Amendment No. 1, filed with the SEC on May 3, 2012, which sets forth important factors that could adversely affect our business and results of operations.

        Pipeline transportation fees.    We earn pipeline transportation fees at our Razorback pipeline and Diamondback pipeline based on the volume of product transported and the distance from the origin point to the delivery point. The Federal Energy Regulatory Commission regulates the tariffs on the Razorback pipeline and the Diamondback pipeline. The pipeline transportation fees by business segments were as follows (in thousands):


Pipeline Transportation Fees by Business Segment

 
  Three months
ended
September 30,
 
 
  2012   2011  

Gulf Coast terminals

  $   $  

Midwest terminals and pipeline system

    463     504  

Brownsville terminals

    805     565  

River terminals

         

Southeast terminals

         
           

Pipeline transportation fees

  $ 1,268   $ 1,069  
           

        Included in pipeline transportation fees for the three months ended September 30, 2012 and 2011 are fees charged to Morgan Stanley Capital Group of approximately $0.5 million and $0.5 million, respectively, and TransMontaigne Inc. of approximately $0.8 million and $0.6 million, respectively.

        Management fees and reimbursed costs.    We manage and operate for a major oil company certain tank capacity at our Port Everglades (South) terminal and receive reimbursement of their proportionate share of operating and maintenance costs. We manage and operate for an affiliate of Mexico's state-owned petroleum company a bi-directional products pipeline connected to our Brownsville, Texas

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terminal facility and receive a management fee and reimbursement of costs. Effective as of April 1, 2011, upon the formation of Frontera, we began providing operations and maintenance services to Frontera for a management fee based on our costs incurred. The management fees and reimbursed costs by business segments were as follows (in thousands):


Management Fees and Reimbursed Costs by Business Segment

 
  Three months
ended
September 30,
 
 
  2012   2011  

Gulf Coast terminals

  $ 65   $ 20  

Midwest terminals and pipeline system

         

Brownsville terminals

    1,466     1,106  

River terminals

         

Southeast terminals

         
           

Management fees and reimbursed costs

  $ 1,531   $ 1,126  
           

        Included in management fees and reimbursed costs for the three months ended September 30, 2012 and 2011 are fees charged to Frontera of approximately $0.9 million and $0.6 million, respectively.

        Other revenue.    We provide ancillary services including heating and mixing of stored products, product transfer services, railcar handling, wharfage fees and vapor recovery fees. Pursuant to terminaling services agreements with our throughput customers, we are entitled to the volume of product gained resulting from differences in the measurement of product volumes received and distributed at our terminaling facilities. Consistent with recognized industry practices, measurement differentials occur as the result of the inherent variances in measurement devices and methodology. We recognize as revenue the net proceeds from the sale of the product gained. Other revenue is composed of the following (in thousands):


Principal Components of Other Revenue

 
  Three months
ended
September 30,
 
 
  2012   2011  

Product gains, net

  $ 4,053   $ 3,833  

Steam heating fees

    700     1,016  

Product transfer services

    233     225  

Railcar handling

    152     166  

Other

    770     614  
           

Other revenue

  $ 5,908   $ 5,854  
           

        For the three months ended September 30, 2012 and 2011, we sold approximately 37,700 and 43,800 barrels, respectively, of product gained resulting from differences in the measurement of product volumes received and distributed at our terminaling facilities at average prices of $125 and $121 per barrel, respectively. Pursuant to our terminaling services agreement related to the Southeast terminals, we agreed to rebate to Morgan Stanley Capital Group 50% of the proceeds we receive annually in excess of $4.2 million from the sale of product gains at our Southeast terminals. For the three months ended September 30, 2012 and 2011, we accrued a liability due to Morgan Stanley Capital Group of approximately $0.7 million and $1.5 million, respectively.

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        Included in other revenue for the three months ended September 30, 2012 and 2011 are amounts charged to Morgan Stanley Capital Group of approximately $4.0 million and $3.9 million, respectively.

        The other revenue by business segments were as follows (in thousands):


Other Revenue by Business Segment

 
  Three months
ended
September 30,
 
 
  2012   2011  

Gulf Coast terminals

  $ 2,237   $ 1,761  

Midwest terminals and pipeline system

    947     413  

Brownsville terminals

    735     928  

River terminals

    173     183  

Southeast terminals

    1,816     2,569  
           

Other revenue

  $ 5,908   $ 5,854  
           


ANALYSIS OF COSTS AND EXPENSES

        The direct operating costs and expenses of our operations include the directly related wages and employee benefits, utilities, communications, maintenance and repairs, property taxes, rent, 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
September 30,
 
 
  2012   2011  

Wages and employee benefits

  $ 5,818   $ 5,362  

Utilities and communication charges

    1,582     1,779  

Repairs and maintenance

    4,156     5,689  

Office, rentals and property taxes

    1,700     1,619  

Vehicles and fuel costs

    302     317  

Environmental compliance costs

    926     987  

Other

    1,686     737  
           

Direct operating costs and expenses

  $ 16,170   $ 16,490  
           

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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
September 30,
 
 
  2012   2011  

Gulf Coast terminals

  $ 5,407   $ 5,191  

Midwest terminals and pipeline system

    551     534  

Brownsville terminals

    3,232     3,185  

River terminals

    2,113     2,311  

Southeast terminals

    4,867     5,269  
           

Direct operating costs and expenses

  $ 16,170   $ 16,490  
           

        Direct general and administrative expenses of our operations primarily include accounting and legal costs associated with annual and quarterly reports and tax return and Schedule K-1 preparation and distribution, independent director fees and deferred equity-based compensation. The direct general and administrative expenses were approximately $1.2 million and $1.1 million for the three months ended September 30, 2012 and 2011, respectively.

        Allocated general and administrative expenses include charges from TransMontaigne Inc. for indirect corporate overhead to cover 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. The allocated general and administrative expenses were approximately $2.7 million and $2.6 million for the three months ended September 30, 2012 and 2011, respectively.

        Allocated insurance expenses include charges from TransMontaigne Inc. for allocations of insurance premiums to cover costs of insuring activities such as property, casualty, pollution, automobile, directors' and officers' liability, and other insurable risks. The allocated insurance expenses were approximately $0.9 million and $0.8 million for the three months ended September 30, 2012 and 2011, respectively.

        The accompanying consolidated financial statements also include amounts paid to TransMontaigne Services Inc. as a partial reimbursement of bonus awards granted by TransMontaigne Services Inc. to certain key officers and employees who provide services to Partners that vest over future service periods. The reimbursements were approximately $0.3 million and $0.3 million for the three months ended September 30, 2012 and 2011, respectively.

        For the three months ended September 30, 2012 and 2011, depreciation and amortization expense was approximately $7.1 million and $6.9 million, respectively.

RESULTS OF OPERATIONS—NINE MONTHS ENDED SEPTEMBER 30, 2012 AND 2011

        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

 
  Nine months ended
September 30,
 
 
  2012   2011  

Terminaling services fees, net

  $ 88,777   $ 87,318  

Pipeline transportation fees

    3,994     3,242  

Management fees and reimbursed costs

    4,274     2,709  

Other

    19,104     19,784  
           

Revenue

  $ 116,149   $ 113,053  
           

        The aggregate revenue of each of our business segments was as follows (in thousands):


Total Revenue by Business Segment

 
  Nine months ended
September 30,
 
 
  2012   2011  

Gulf Coast terminals

  $ 43,693   $ 42,209  

Midwest terminals and pipeline system

    7,537     5,784  

Brownsville terminals

    13,248     15,233  

River terminals

    10,664     9,399  

Southeast terminals

    41,007     40,428  
           

Revenue

  $ 116,149   $ 113,053  
           

        Terminaling services fees, net.    Pursuant to terminaling services agreements with our customers, which range from one month to seven years in duration, we generate fees by distributing and storing products for our customers. Terminaling services fees, net include throughput fees based on the volume of product distributed from the facility, injection fees based on the volume of product injected with additive compounds and storage fees based on a rate per barrel of storage capacity per month. The terminaling services fees, net by business segments were as follows (in thousands):


Terminaling Services Fees, Net, by Business Segment

 
  Nine months ended
September 30,
 
 
  2012   2011  

Gulf Coast terminals

  $ 35,871   $ 34,786  

Midwest terminals and pipeline system

    3,415     2,836  

Brownsville terminals

    4,481     7,556  

River terminals

    9,913     9,078  

Southeast terminals

    35,097     33,062  
           

Terminaling services fees, net

  $ 88,777   $ 87,318  
           

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        The increase in terminaling services fees, net includes an increase of approximately $0.4 million from the acquisition of the Pensacola terminal on March 1, 2011 in the Gulf Coast region, an increase of approximately $0.7 million resulting from newly constructed tank capacity placed into service during August of 2012 at our Cushing, Oklahoma facility in the Midwest region, an increase of approximately $0.6 million from new business in our River region and an increase of approximately $1.8 million resulting from newly constructed tank capacity placed into service during July of 2011 at our Collins/Purvis complex in the Southeast region. This increase has been partially offset by decreases in terminaling service fees, net of approximately $2.5 million at our Brownsville terminals resulting from product storage capacity contributed to Frontera effective as of April 1, 2011.

        Included in terminaling services fees, net for the nine months ended September 30, 2012 and 2011 are fees recognized from agreements with Morgan Stanley Capital Group of approximately $60.4 million and $57.8 million, respectively, and TransMontaigne Inc. of approximately $2.4 million and $2.8 million, respectively.

        Our terminaling services agreements are structured as either throughput agreements or storage agreements. Most of our throughput agreements contain provisions that require our customers to throughput a minimum volume of product at our facilities over a stipulated period of time, which results in a fixed amount of revenue to be recognized by us. 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 revenue to be recognized by us. 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 "variable." The "firm commitments" and "variable" revenue included in terminaling services fees, net were as follows (in thousands):


Firm Commitments and Variable Revenue

 
  Nine months ended
September 30,
 
 
  2012   2011  

Firm commitments:

             

External customers

  $ 24,104   $ 24,839  

Affiliates

    62,788     60,617  
           

Total

    86,892     85,456  
           

Variable:

             

External customers

    1,985     1,991  

Affiliates

    (100 )   (129 )
           

Total

    1,885     1,862  
           

Terminaling services fees, net

  $ 88,777   $ 87,318  
           

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        At September 30, 2012, the remaining terms on the terminaling services agreements that generated "firm commitments" for the nine months ended September 30, 2012 were as follows (in thousands):

 
  At September 30, 2012  

Remaining terms on terminaling services agreements that generated "firm commitments":

       

Less than 1 year remaining

  $ 11,958  

1 year or more, but less than 3 years remaining

    61,405  

3 years or more, but less than 5 years remaining

    9,705  

5 years or more remaining

    3,824  
       

Total firm commitments for the nine months ended September 30, 2012

  $ 86,892  
       

        We have a terminaling services agreement with Valero Marketing and Supply Company, which we refer to as Valero, for approximately 1.1 million barrels of light refined product storage capacity (out of approximately 23.4 million barrels of active storage capacity across our system), in the aggregate, at our Cape Girardeau, Evansville, Greenville, Henderson, Owensboro and Paducah terminals that expires on April 1, 2013. In July 2012 we began preliminary discussions with Valero to renew the terminaling services agreement. At this time we are unsure what the outcome of these negotiations will be. See "Item 1A. Risk Factors" in our Annual Report on Form 10-K/A, Amendment No. 1, filed with the SEC on May 3, 2012, which sets forth important factors that could adversely affect our business and results of operations.

        Pipeline transportation fees.    We earn pipeline transportation fees at our Razorback pipeline and Diamondback pipeline based on the volume of product transported and the distance from the origin point to the delivery point. The Federal Energy Regulatory Commission regulates the tariffs on the Razorback pipeline and the Diamondback pipeline. The pipeline transportation fees by business segments were as follows (in thousands):


Pipeline Transportation Fees by Business Segment

 
  Nine months ended
September 30,
 
 
  2012   2011  

Gulf Coast terminals

  $   $  

Midwest terminals and pipeline system

    1,451     1,427  

Brownsville terminals

    2,543     1,815  

River terminals

         

Southeast terminals

         
           

Pipeline transportation fees

  $ 3,994   $ 3,242  
           

        Included in pipeline transportation fees for the nine months ended September 30, 2012 and 2011 are fees charged to Morgan Stanley Capital Group of approximately $1.5 million and $1.4 million, respectively, and TransMontaigne Inc. of approximately $2.5 million and $1.8 million, respectively.

        Management fees and reimbursed costs.    We manage and operate for a major oil company certain tank capacity at our Port Everglades (South) terminal and receive reimbursement of their proportionate share of operating and maintenance costs. We manage and operate for an affiliate of Mexico's state-owned petroleum company a bi-directional products pipeline connected to our Brownsville, Texas terminal facility and receive a management fee and reimbursement of costs. Effective as of April 1,

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2011, upon the formation of Frontera, we began providing operations and maintenance services to Frontera for a management fee based on our costs incurred. The management fees and reimbursed costs by business segments were as follows (in thousands):


Management Fees and Reimbursed Costs by Business Segment

 
  Nine months ended
September 30,
 
 
  2012   2011  

Gulf Coast terminals

  $ 153   $ 55  

Midwest terminals and pipeline system

         

Brownsville terminals

    4,121     2,654  

River terminals

         

Southeast terminals

         
           

Management fees and reimbursed costs

  $ 4,274   $ 2,709  
           

        Included in management fees and reimbursed costs for the nine months ended September 30, 2012 and 2011 are fees charged to Frontera of approximately $2.5 million and $1.2 million, respectively.

        Other revenue.    We provide ancillary services including heating and mixing of stored products, product transfer services, railcar handling, wharfage fees and vapor recovery fees. Pursuant to terminaling services agreements with our throughput customers, we are entitled to the volume of product gained resulting from differences in the measurement of product volumes received and distributed at our terminaling facilities. Consistent with recognized industry practices, measurement differentials occur as the result of the inherent variances in measurement devices and methodology. We recognize as revenue the net proceeds from the sale of the product gained. Other revenue is composed of the following (in thousands):


Principal Components of Other Revenue

 
  Nine months ended
September 30,
 
 
  2012   2011  

Product gains, net

  $ 12,515   $ 13,191  

Steam heating fees

    2,546     3,270  

Product transfer services

    715     878  

Railcar handling

    386     459  

Other

    2,942     1,986  
           

Other revenue

  $ 19,104   $ 19,784  
           

        For the nine months ended September 30, 2012 and 2011, we sold approximately 120,400 and 141,900 barrels, respectively, of product gained resulting from differences in the measurement of product volumes received and distributed at our terminaling facilities at average prices of $124 and $121 per barrel, respectively. Pursuant to our terminaling services agreement related to the Southeast terminals, we agreed to rebate to Morgan Stanley Capital Group 50% of the proceeds we receive annually in excess of $4.2 million from the sale of product gains at our Southeast terminals. For the nine months ended September 30, 2012 and 2011, we accrued a liability due to Morgan Stanley Capital Group of approximately $2.4 million and $4.0 million, respectively.

        Included in other revenue for the nine months ended September 30, 2012 and 2011 are amounts charged to Morgan Stanley Capital Group of approximately $12.8 million and $13.5 million, respectively.

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        The other revenue by business segments were as follows (in thousands):


Other Revenue by Business Segment

 
  Nine months ended
September 30,
 
 
  2012   2011  

Gulf Coast terminals

  $ 7,669   $ 7,368  

Midwest terminals and pipeline system

    2,671     1,521  

Brownsville terminals

    2,103     3,208  

River terminals

    751     321  

Southeast terminals

    5,910     7,366  
           

Other revenue

  $ 19,104   $ 19,784  
           


ANALYSIS OF COSTS AND EXPENSES

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


Direct Operating Costs and Expenses

 
  Nine months ended September 30,  
 
  2012   2011  

Wages and employee benefits

  $ 17,127   $ 16,712  

Utilities and communication charges

    5,272     6,016  

Repairs and maintenance

    12,947     15,109  

Office, rentals and property taxes

    5,072     5,105  

Vehicles and fuel costs

    953     1,068  

Environmental compliance costs

    2,104     2,967  

Other

    2,848     1,726  
           

Direct operating costs and expenses

  $ 46,323   $ 48,703  
           

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


Direct Operating Costs and Expenses by Business Segment

 
  Nine months ended September 30,  
 
  2012   2011  

Gulf Coast terminals

  $ 15,452   $ 15,780  

Midwest terminals and pipeline system

    1,328     1,424  

Brownsville terminals

    8,006     9,731  

River terminals

    6,764     5,802  

Southeast terminals

    14,773     15,966  
           

Direct operating costs and expenses

  $ 46,323   $ 48,703  
           

        The direct general and administrative expenses were approximately $3.6 million and $3.2 million for the nine months ended September 30, 2012 and 2011, respectively.

        The allocated general and administrative expenses were approximately $8.1 million and $7.8 million for the nine months ended September 30, 2012 and 2011, respectively.

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        The allocated insurance expenses were approximately $2.7 million and $2.5 million for the nine months ended September 30, 2012 and 2011, respectively.

        The reimbursement of bonus awards was approximately $0.9 million and $0.9 million for the nine months ended September 30, 2012 and 2011, respectively.

        For the nine months ended September 30, 2012 and 2011, depreciation and amortization expense was approximately $21.0 million and $20.7 million, respectively.

LIQUIDITY AND CAPITAL RESOURCES

        Our primary liquidity needs are to fund our working capital requirements, distributions to unitholders, approved capital projects and approved future expansion, development and acquisition opportunities. As a result of Morgan Stanley's October 2011 decision not to approve any "significant" acquisition or investment that we may propose for the foreseeable future, we anticipate that Morgan Stanley's decision will significantly constrain our ability to grow our business as we have previously disclosed we were seeking to do. We cannot currently predict how Morgan Stanley's decision and any such regulatory developments will otherwise affect Morgan Stanley's commodities business or the growth or development of our business, our financial condition or results of operations, or how significant any such effects could be. Further discussion of Morgan Stanley's current position with respect to approval of any proposed acquisitions and investments and the potential impact of such decision is set forth under the captions "Item 1.A. Risk Factors" and "Regulatory Matters" in Item 7 of our Annual Report on Form 10-K/A, Amendment No. 1, filed on May 3, 2012.

        We anticipate an increase in our repairs and maintenance expenses during the fourth quarter of 2012 across our terminaling and transportation facilities. We believe that we will be able to generate sufficient cash from operations in the future to fund our working capital requirements and our distributions to unitholders.

        We expect to initially fund our approved capital projects and our approved future expansion, development and acquisition opportunities, if any, with additional borrowings under our credit facility (see Note 11 of Notes to consolidated financial statements). After initially funding expenditures for approved capital projects and approved future expansion, development and acquisition opportunities, if any, with borrowings under our credit facility, we may raise funds through additional equity offerings and debt financings, which may include the issuance of senior unsecured notes. The proceeds of such equity offerings and debt financings may then be used to reduce our outstanding borrowings under our credit facility.

        Our capital expenditures for the nine months ended September 30, 2012 were approximately $16.8 million for terminal and pipeline facilities and assets to support these facilities. Management and the board of directors of our general partner have approved expansion capital projects that currently are or will be under construction with estimated completion dates that extend through 2013. At September 30, 2012, the remaining capital expenditures to complete the approved expansion capital projects are estimated to range from $3 million to $5 million. We expect to fund our expansion capital expenditures with additional borrowings under our credit facility.

        Future expansion, development and acquisition expenditures will depend on numerous factors, including approval by Morgan Stanley; the availability, economics and cost of appropriate acquisitions which we identify and evaluate; the economics, cost and required regulatory approvals with respect to the expansion and enhancement of existing systems and facilities; customer demand for the services we provide; local, state and federal governmental regulations; environmental compliance requirements; and the availability of debt financing and equity capital on acceptable terms.

        Amended and restated senior secured credit facility.    On March 9, 2011, we entered into an amended and restated senior secured credit facility, or credit facility. The credit facility provides for a maximum

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borrowing line of credit equal to the lesser of (i) $250 million and (ii) 4.75 times Consolidated EBITDA (as defined: $354.3 million at September 30, 2012). In addition, at our request, the revolving loan commitment can be increased up to an additional $100 million, in the aggregate, without the approval of the lenders, but subject to the approval of the administrative agent and the receipt of additional commitments from one or more lenders. We may elect to have loans under the credit facility bear interest either (i) at a rate of LIBOR plus a margin ranging from 2% to 3% depending on the total leverage ratio then in effect, or (ii) at the base rate plus a margin ranging from 1% to 2% 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 the credit facility are secured by a first priority security interest in favor of the lenders in the majority of our assets. At September 30, 2012, our outstanding borrowings under the credit facility were $102 million.

        The terms of the 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 "permitted JV investments" which may not exceed $125 million in the aggregate and subject to us having at least $50 million in "liquidity" before and after giving effect to such joint venture investment. The principal balance of loans and any accrued and unpaid interest are due and payable in full on the maturity date, March 9, 2016.

        The 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 the credit facility are (i) a total leverage ratio test (not to exceed 4.75 times), (ii) a senior secured leverage ratio test (not to exceed 3.75 times) in the event we issue senior unsecured notes, and (iii) a minimum interest coverage ratio test (not less than 3.0 times). These financial covenants are based on a defined financial performance measure within the credit facility known as "Consolidated EBITDA." The

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calculation of the "total leverage ratio" and "interest coverage ratio" contained in the credit facility is as follows (in thousands, except ratios):

 
  Three months ended    
 
 
  December 31, 2011   March 31, 2012   June 30, 2012   September 30, 2012   Twelve
months ended
September 30, 2012
 

Financial performance debt covenant test:

                               

Consolidated EBITDA for the total leverage ratio, as stipulated in the credit facility

  $ 18,509   $ 18,311   $ 19,662   $ 18,102   $ 74,584  

Consolidated funded indebtedness

                          $ 102,000  

Total leverage ratio

                            1.37x  

Consolidated EBITDA for the interest coverage ratio

  $ 18,509   $ 18,311   $ 19,662   $ 18,102   $ 74,584  

Consolidated interest expense, as stipulated in the credit facility

  $ 763   $ 681   $ 648   $ 692   $ 2,784  

Interest coverage ratio

                            26.79x  

Reconciliation of consolidated EBITDA to cash flows provided by operating activities:

                               

Consolidated EBITDA

  $ 18,509   $ 18,311   $ 19,662   $ 18,102   $ 74,584  

Consolidated interest expense

    (763 )   (681 )   (648 )   (692 )   (2,784 )

Amortization of deferred revenue

    (1,136 )   (1,144 )   (1,134 )   (1,173 )   (4,587 )

Amounts due under long-term terminaling services agreements, net

    (165 )   128     140     179     282  

Change in operating assets and liabilities

    2,092     (7,076 )   (1,584 )   6,264     (304 )
                       

Cash flows provided by operating activities

  $ 18,537   $ 9,538   $ 16,436   $ 22,680   $ 67,191  
                       

        If we were to fail either financial performance covenant, or any other covenant contained in the 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 the credit facility, and the lenders would be entitled to declare all outstanding borrowings immediately due and payable.

        We believe that our future cash expected to be provided by operating activities, available borrowing capacity under our credit facility, and our relationship with institutional lenders and equity investors should enable us to meet our committed capital and our essential liquidity requirements for the next twelve months.

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/A, Amendment No. 1, filed on May 3, 2012, 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/A, Amendment No. 1, for the year ended December 31, 2011.

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        Market risk is the risk of loss arising from adverse changes in market rates and prices. The principal market risk to which we are exposed is interest rate risk associated with borrowings under our credit facility. Borrowings under our credit facility bear interest at a variable rate based on LIBOR or the lender's base rate. At September 30, 2012, we had outstanding borrowings of $102 million under our credit facility. Based on the outstanding balance of our variable-interest-rate debt at September 30, 2012 and assuming market interest rates increase or decrease by 100 basis points, the potential annual increase or decrease in interest expense is approximately $1.0 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. Pursuant to our terminaling services agreement related to the Southeast terminals, we agreed to rebate to Morgan Stanley Capital Group 50% of the proceeds we receive annually in excess of $4.2 million from the sale of product gains at our Southeast terminals. 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 Morgan Stanley Capital Group and other marketing and distribution companies on a monthly basis; the sales price is based on industry indices.

        For the nine months ended September 30, 2012 and 2011, we sold approximately 120,400 and 141,900 barrels, respectively, of product gained resulting from differences in the measurement of product volumes received and distributed at our terminaling facilities at average prices of $124 and $121 per barrel, respectively.

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 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 September 30, 2012, pursuant to Rule 13a-15(b) under the Exchange Act. Based upon that evaluation, the Certifying Officers concluded that, as of September 30, 2012, 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.

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Part II. Other Information

ITEM 1A.    RISK FACTORS

        The following risk factors, discussed in more detail in "Item 1A. Risk Factors," in our Annual Report on Form 10-K/A, Amendment No. 1, filed on May 3, 2012, which risk factors are expressly incorporated into this report by reference, are important factors that could cause actual results to differ materially from our expectations and may adversely affect our business and results of operations, include, but are not limited to:

    a reduction in revenue from any of our significant customers upon which we rely for a substantial majority of our revenue;

    our ability to generate sufficient cash from operations to enable us to maintain or grow the amount of the quarterly distribution to our unitholders;

    failure by any of our significant customers to continue to engage us to provide services after the expiration of existing terminaling services agreements, or our failure to secure comparable alternative arrangements;

    a lack of access to new capital would impair our ability to expand our operations;

    the impact of Morgan Stanley's status as a bank holding company on its ability to conduct certain nonbanking activities or retain certain investments, including control of our general partner;

    our ability to grow our business will be severely constrained by Morgan Stanley's determination that it will not approve any "significant" acquisition or investment that we may propose for the foreseeable future;

    changes that Morgan Stanley may make in the manner it conducts its commodities business could materially and adversely affect our business;

    our debt levels and restrictions in our debt agreements that may limit our operational flexibility;

    the lack of availability of acquisition opportunities, constraints on our ability to make acquisitions, failure to successfully integrate acquired facilities and future performance of acquired facilities, could limit our ability to grow our business successfully and could adversely affect the price of our limited partnership units;

    a decrease in demand for products due to high prices, alternative fuel sources, new technologies or adverse economic conditions;

    the continued creditworthiness of, and performance by, our significant customers;

    competition from other terminals and pipelines that may be able to supply our significant customers with terminaling services on a more competitive basis;

    the ability of our significant customers to secure financing arrangements adequate to purchase their desired volume of product;

    the impact on our facilities or operations of extreme weather conditions, such as hurricanes, and other events, such as terrorist attacks or war and costs associated with environmental compliance and remediation;

    we may have to refinance our existing debt in unfavorable market conditions;

    the failure of our existing and future insurance policies to fully cover all risks incident to our business;

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    timing, cost and other economic uncertainties related to the construction of new tank capacity or facilities;

    the impact of current and future laws and governmental regulations, general economic, market or business conditions;

    the age and condition of many of our pipeline and storage assets may result in increased maintenance and remediation expenditures;

    conflicts of interest and the limited fiduciary duties of our general partner, which is indirectly controlled by Morgan Stanley Capital Group;

    cost reimbursements, which are determined by our general partner, and fees paid to our general partner and its affiliates for services will continue to be substantial;

    the control of our general partner being transferred to a third party without unitholder consent;

    our general partner's limited call right may require unitholders to sell their common units at an undesirable time or price;

    our ability to issue additional units without your approval would dilute your existing ownership interest;

    the possibility that our unitholders could be held liable under some circumstances for our obligations to the same extent as a general partner;

    our failure to avoid federal income taxation as a corporation or the imposition of state level taxation;

    constraints on our ability to make acquisitions and investments to increase our capital asset base may result in future declines in our tax depreciation;

    the impact of new IRS regulations or a challenge of our current allocation of income, gain, loss and deductions among our unitholders;

    unitholders will be required to pay taxes on their respective share of our taxable income regardless of the amount of cash distributions;

    investment in common partnership units by tax-exempt entities and non-United States persons raises tax issues unique to them;

    unitholders will likely be subject to state and local taxes and return filing requirements in states where they do not live as a result of investing in our units; and

    the sale or exchange of 50% or more of our capital and profits interests within a 12-month period would result in a deemed termination of our partnership for income tax purposes.

        There have been no material changes from risk factors as previously disclosed in our annual report on Form 10-K/A, Amendment No. 1, for the year ended December 31, 2011, filed on May 3, 2012.

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ITEM 2.    UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

        Purchases of securities.    The following table covers the purchases of our common units by, or on behalf of, Partners during the three months ended September 30, 2012 covered by this report.

Period
  Total
number of
common units
purchased
  Average price
paid per
common unit
  Total number of
common units
purchased as part of
publicly announced
plans or programs
  Maximum number of
common units that
may yet be purchased
under the plans or
programs
 

July

    575   $ 33.53     575     4,600  

August

    6,466   $ 36.44     575     4,025  

September

    575   $ 36.81     575     3,450  
                     

    7,616   $ 36.25     1,725        
                     

        During the three months ended September 30, 2012, we purchased 1,725 common units, with approximately $61,000 of aggregate market value, in the open market pursuant to a purchase program announced on May 7, 2007. The purchase program establishes the purchase, from time to time, of our outstanding common units for purposes of making subsequent grants of restricted phantom units under the TransMontaigne Services Inc. Long-Term Incentive Plan to independent directors of our general partner. There is no guarantee as to the exact number of common units that will be purchased under the purchase program, and the purchase program may be amended or discontinued at any time. Unless we choose to terminate the purchase program earlier, the purchase program terminates on the earlier to occur of March 31, 2013; our liquidation, dissolution, bankruptcy or insolvency; the public announcement of a tender or exchange offer for the common units; or a merger, acquisition, recapitalization, business combination or other occurrence of a "Change of Control" under the TransMontaigne Services Inc. Long-Term Incentive Plan. We currently anticipate purchasing in future periods up to approximately 3,450 common units, in the aggregate, through the purchase program's scheduled termination date of March 31, 2013.

        In addition to the foregoing purchases, on August 10, 2012, we purchased 5,891 common units from TransMontaigne Services Inc. for approximately $215,000 for the purpose of delivering these units to Charles L. Dunlap, the CEO of our general partner, upon the vesting of 10,000 restricted phantom units granted to Mr. Dunlap on August 10, 2009 under the Long-Term Incentive Plan.

ITEM 6.    EXHIBITS

        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 September 30, 2012, formatted in XBRL (eXtensible Business Reporting Language): (i) consolidated balance sheets, (ii) consolidated statements of comprehensive income, (iii) consolidated statements of partners' equity, (iv) consolidated statements of cash flows and (v) notes to the consolidated financial statements.

*
In accordance with Rule 406T of Regulation S-T, this information is "furnished" and not "filed" with this quarterly report for purposes of Sections 11 and 12 of the Securities Act of 1933 and Section 18 of the Securities and Exchange Act of 1934, or otherwise subject to the liability of such sections, and shall not be part of any registration statement or other document filed under the Securities Act or the Exchange Act, except as shall be expressly set forth by specific reference in such filing.

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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.

Date: November 6, 2012   TRANSMONTAIGNE PARTNERS L.P.
(Registrant)

 

 

TransMontaigne GP L.L.C., its General Partner

 

 

By:

 

/s/ CHARLES L. DUNLAP

Charles L. Dunlap
Chief Executive Officer

 

 

By:

 

/s/ FREDERICK W. BOUTIN

Frederick W. Boutin
Chief Financial Officer

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EXHIBIT INDEX

Exhibit
number
  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 September 30, 2012, formatted in XBRL (eXtensible Business Reporting Language): (i) consolidated balance sheets, (ii) consolidated statements of comprehensive income, (iii) consolidated statements of partners' equity, (iv) consolidated statements of cash flows and (v) notes to the consolidated financial statements.

*
In accordance with Rule 406T of Regulation S-T, this information is "furnished" and not "filed" with this quarterly report for purposes of Sections 11 and 12 of the Securities Act of 1933 and Section 18 of the Securities and Exchange Act of 1934, or otherwise subject to the liability of such sections, and shall not be part of any registration statement or other document filed under the Securities Act or the Exchange Act, except as shall be expressly set forth by specific reference in such filing.

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