ENGY Central Energy Partners LP (CE)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE A – ORGANIZATION

Central Energy Partners LP, formerly known as Rio Vista Energy Partners L.P. (“ Partnership ”), a Delaware limited partnership, was formed by Penn Octane Corporation (“ Penn Octane ”) on July 10, 2003 and was a wholly-owned subsidiary of Penn Octane until September 30, 2004, the date that Penn Octane completed a series of transactions that (i) transferred substantially all of its owned pipeline and terminal assets in Brownsville, Texas and Matamoros, Mexico and certain immaterial liabilities to Rio Vista Operating Partnership L.P. (“ RVOP ”) (ii) transferred Penn Octane’s 99.9% interest in RVOP to the Partnership and (iii) distributed all of its limited partnership interests (“ Common Units” ) in the Partnership to its common stockholders (“ Spin-Off ”), resulting in the Partnership becoming a separate public company. The Common Units represent 98% of the Partnership’s outstanding capital and 100% of the Partnership’s limited partnership interests. The General Partner is Central Energy GP LLC, formerly known as Rio Vista GP, LLC (“ General Partner ”) (see Note B — General Partner Interest) which holds the remaining 2% interest in the Partnership. The General Partner is entitled to receive distributions from the Partnership on its General Partner interest and additional incentive distributions (see Note H – Partners’ Capital — Distributions of Available Cash) as provided in the Partnership’s partnership agreement. The General Partner has sole responsibility for conducting the Partnership’s business and for managing the Partnership’s operations in accordance with the partnership agreement. Common Unitholders do not participate in the management of the Partnership. The General Partner does not receive a management fee in connection with its management of the Partnership’s business, but is entitled to be reimbursed for all direct and indirect expenses incurred on the Partnership’s behalf.

On November 17, 2010, the Partnership, Penn Octane and Central Energy, LP, as successor in interest to Central Energy LLC, completed the transactions contemplated by the terms of a Securities Purchase and Sale Agreement, as amended. At closing, the Partnership sold 12,724,019 Common Units to Central Energy, LP for $3,950,000 and Penn Octane sold 100% of the limited liability company interests in the General Partner (“ GP Interests ”) to Central Energy, LP for $150,000 (“ Sale ”). As a result, Penn Octane no longer has any interest in the General Partner or any control over the operations of the Partnership. On May 26, 2011, Central Energy, LP transferred the Newly Issued Common Units to its limited partners. In September 2011, Central Energy, LP transferred all of the GP Interests to its limited partners and the sole members of the general partner of Central Energy, LP. As a result, Central Energy, LP no longer holds any interest in the Partnership or the General Partner. Central’s strategy is to acquire midstream assets with a focus on gas transportation and services assets, including gas gathering, dehydration and compression systems, pipelines, fractionation and condensate stabilization facilities and related assets.

In July 2007, the Partnership acquired the business of Regional Enterprises, Inc. (“ Regional ”). The principal business of Regional is the storage, transportation and railcar trans-loading of bulk liquids, including hazardous chemicals and petroleum products owned by its customers. Regional’s principal facilities are located on the James River in Hopewell, Virginia, where it receives bulk chemicals and petroleum products from ships and barges into approximately 10 million gallons of available storage tanks for delivery throughout the mid-Atlantic region of the United States. Regional also receives product from a rail spur which is capable of receiving 15 rail cars at any one time for trans-loading of chemical and petroleum liquids for delivery throughout the mid-Atlantic region of the United States. Regional also operated a trans-loading facility in Johnson City, Tennessee, with 6 rail car slots until March 31, 2013. Regional also provides transportation services to customers for products which don’t originate at any of Regional’s terminal facilities.

The accompanying consolidated financial statements include the Partnership and its only operating subsidiary, Regional. The Partnership has two other subsidiaries that have no operations – RVOP (see Note H – Commitments and Contingencies – TransMontaigne Dispute) and Rio Vista Operating GP LLC. All significant intercompany accounts and transactions are eliminated. The Partnership and its consolidated subsidiaries are hereinafter referred to as “Central” and/or “Company”.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE A – ORGANIZATION – Continued

The unaudited consolidated balance sheet as of March 31, 2013, the unaudited consolidated statements of operations and statements of cash flows for the three months ended March 31, 2012 and 2013 and the unaudited consolidated statement of partners’ capital (deficit) for the three months ended March 31, 2013, have been prepared by Central without audit. In the opinion of management, the unaudited consolidated financial statements include all adjustments (which include only normal recurring adjustments) necessary to present fairly the unaudited consolidated financial position as of March 31, 2013, the unaudited consolidated results of operations and the unaudited consolidated statements of cash flows for the three months ended March 31, 2012 and 2013 and the unaudited consolidated statement of partners’ capital (deficit) for the three months ended March 31, 2013.

Certain information and footnote disclosures normally included in consolidated financial statements prepared in accordance with accounting principles generally accepted in the United States of America have been omitted pursuant to the rules and regulations of the Securities Exchange Commission, although Central believes that the disclosures made are adequate to make the information not misleading. These unaudited consolidated financial statements should be read in conjunction with the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2012 filed with the Securities and Exchange Commission.

Basis of Presentation

Certain reclassifications have been made to prior period balances to conform in the current presentation. All reclassifications have been consistently applied to the periods presented.

NOTE B – PARTNERS’ CAPITAL

General Partner Interest

The General Partner owns a 2% general partner interest in the Partnership. On November 17, 2010, the Partnership, Penn Octane and Central Energy, LP, as successor in interest to Central Energy LLC, completed the transactions contemplated by the terms of a Securities Purchase and Sale Agreement, as amended. At closing, the Partnership sold the 12,724,019 Common Units to Central Energy, LP and Penn Octane sold 100% of the limited liability company interests in the General Partner to Central Energy, LP for $150,000. As a result, Penn Octane no longer has any interest in the General Partner or any control over the operations of the Partnership.

In accordance with the terms of the limited partnership agreement of Central Energy, LP, it distributed all of the GP Interests in Central Energy GP LLC, the General Partner, to its limited partners in September 2011. Messrs. Imad K. Anbouba and Carter R. Montgomery, the sole members of Central Energy, LP’s general partner, each beneficially own 30.17% of the GP Interests. The Cushing Fund holds 25% of the GP Interests and the remaining interests are held by others, none representing more than 5% individually. The General Partner generally has unlimited liability for the obligations of the Partnership, such as its debts and environmental liabilities, except for those contractual obligations of the Partnership that are expressly made without recourse to the General Partner.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE B – PARTNERS’ CAPITAL - continued

Private Placement of Common Units

The Common Units represent limited partner interests in the Partnership. The holders of Common Units are entitled to participate in the Partnership’s distributions and exercise the rights or privileges available to limited partners under the Partnership Agreement. The holders of Common Units have only limited voting rights on matters affecting the Partnership. Holders of Common Units have no right to elect the General Partner or its directors on an annual or other continuing basis. Messrs. Anbouba and Montgomery and Cushing MLP Opportunity Fund I L.P., a Delaware limited partnership (the “ Cushing Fund ”) have the right to appoint the directors of the General Partner. Although the General Partner has a fiduciary duty to manage the Partnership in a manner beneficial to the Partnership and its Unitholders, the directors of the General Partner also have a fiduciary duty to manage the General Partner in a manner beneficial to Central Energy LLC. The General Partner generally may not be removed except upon the vote of the holders of at least 80% of the outstanding Common Units; provided, however, if at any time any person or group, other than the General Partner and its affiliates, or a direct or subsequently approved transferee of the General Partner or its affiliates, acquires, in the aggregate, beneficial ownership of 20% or more of any class of units then outstanding, that person or group will lose voting rights on all of its units and the units may not be voted on any matter and will not be considered to be outstanding when sending notices of a meeting of Unitholders, calculating required votes, determining the presence of a quorum or for other similar purposes, unless such provision is waived by the General Partner. (The General partner has waived this provision with respect to the 46.7% interest in the Partnership held by the Cushing Fund as described below.). In addition, the partnership agreement contains provisions limiting the ability of holders of Common Units to call meetings or to acquire information about Central’s operations, as well as other provisions limiting the holders of Common Units ability to influence the manner or direction of management.

On November 17, 2010, the Partnership sold 12,724,019 newly-issued Common Units to Central Energy LP for $3,950,000 in cash pursuant to the terms of the Securities Purchase and Sale Agreement dated May 25, 2010, as amended, by and among the Partnership, Penn Octane and Central Energy LP.

On May 26, 2011, pursuant to the terms of its limited partnership agreement, Central Energy LP distributed the Newly Issued Common Units of the Partnership to its limited partners. As a result, the Cushing Fund holds 7,413,013 Common Units of the Partnership (46.7%) and 25% of the GP Interests. Sanctuary Capital LLC holds 1,017,922 Common Units of the Partnership (6.4%). Messrs. Anbouba and Montgomery were not distributed any Newly Issued Common Units from Central Energy, LP.

Distributions of Available Cash

Until December 2010, all Unitholders had the right to receive distributions from the Partnership of “available cash” as defined in the partnership agreement in an amount equal to at least the minimum distribution of $0.25 per quarter per unit, plus any arrearages in the payment of the minimum quarterly distribution on the Common Units from prior quarters subject to any reserves determined by the General Partner. The General Partner has a right to receive a distribution corresponding to its 2% General Partner interest and the incentive distribution rights described below. The distributions are to be paid within 45 days after the end of each calendar quarter.

In 2008, the Partnership made distributions of $1,308,000 to Unitholders and $27,000 to the General Partner for the quarters ended March 31 and June 30, 2008. The Partnership has not made any distributions since August 18, 2008 for the quarter ended June 30, 2008. The amount of the distributions paid through the June 2008 quarterly distribution represented the minimum quarterly distributions required to be made by the Partnership pursuant to the Partnership Agreement through that date.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE B – PARTNERS’ CAPITAL – Continued

Distributions of Available Cash – continued

In December 2010, the General Partner and more than a majority in interest of the limited partners holding Common Units of the Partnership approved an amendment to the Partnership Agreement to provide that the Partnership was no longer obligated to make distributions of “Common Unit Arrearage” or “Cumulative Common Unit Arrearages” pursuant to the terms of the Partnership Agreement in respect of any quarter prior to the quarter beginning October 1, 2011. The impact of this amendment is that the Partnership was not obligated to Unitholders for unpaid minimum quarterly distributions prior to the quarter beginning October 1, 2011 and Unitholders would only be entitled to minimum quarterly distributions arising from the quarter beginning October 1, 2011 and thereafter. This amendment was incorporated into the Partnership Agreement in April 2011. Based on Central’s cash flow constraints and the likelihood of a restriction on distributions by the Partnership as a result of anticipated acquisitions, on March 28, 2012, the General Partner and Unitholders holding more than a majority in interest of the Common Units of the Partnership voted to amend the Partnership Agreement to change the commencement of the payment of “Common Unit Arrearages” or “Cumulative Common Unit Arrearages” from the quarter beginning October 1, 2011 until an undetermined future quarter to be established by the Board of Directors of the General Partner. The impact of this amendment is that the Partnership is not obligated to Unitholders for unpaid minimum quarterly distributions until such time as the Board of Directors of the General Partner reinstates the obligation to make minimum quarterly distributions. Unitholders will only be entitled to minimum quarterly distributions arising from and after the date established by the Board of Directors for making such distributions.

At the present time, the limited partners of Central Energy, LP, the entity that acquired the Newly-Issued Common Units in the Sale, hold 80% of the total issued and outstanding Common Units of the Partnership and, therefore, control any Limited Partner vote on Partnership matters. The ability of the Partnership to make distributions can be further impacted by many factors including the ability to successfully complete an acquisition, the financing terms of debt and/or equity proceeds received to fund an acquisition and the overall success of the Partnership and its operating subsidiaries. In addition to eliminating the obligation to make payments of minimum quarterly distributions until an undetermined future quarter to be established by the Board of Directors of the General Partner, the General Partner expects that the minimum quarterly distribution amount and/or the target distribution levels will be adjusted to a level which reflects the existing economics of the Partnership and provides for the desired financial targets, including Common Unit trading price, targeted cash distribution yields and the participation by the General Partner in incentive distribution rights. The distribution of the 12,724,019 Newly-Issued Common Units in the Sale (which did not result in the acquisition of any proportional increase in distributable cash flow) and any additional issuance of Common Units or other Partnership securities in connection with the next acquisition will not support the current minimum quarterly distribution of $0.25 per Common Unit. Management anticipates making this adjustment in connection with an acquisition by the Partnership since the financing of an acquisition is likely to involve the issuance of additional Common Units or other securities by the Partnership. In connection with an acquisition, the General Partner will be able to better determine the future capital structure of the Partnership and the amounts of “distributable cash” that the Partnership may generate in the future. The establishment of a revised target distribution rate may be accomplished by a reverse split of the number of Partnership Common Units issued and outstanding and/or a reduction in the actual amount of the target distribution rate per Common Unit.

In addition to its 2% General Partner interest, the General Partner is currently the holder of incentive distribution rights which entitled the holder to an increasing portion of cash distributions as described in the Partnership Agreement. As a result, cash distributions from the Partnership are shared by the holders of the Common Units and the General Partner interest based on a formula whereby the General Partner receives disproportionately more distributions per percentage interest than the holders of the Common Units as annual cash distributions exceed certain milestones.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE C – INCOME ( Loss) Per Common UNIT

Net (loss) per Common Unit is computed on the weighted average number of Common Units outstanding in accordance with ASC 260. During periods in which Central incurs losses, giving effect to common unit equivalents is not included in the computation as it would be antidilutive. The following tables present reconciliations from net (loss) per Common Unit to net (loss) per Common Unit assuming dilution (see Note G – Unit Options and Equity Incentive Plan):

Depreciation expense of property, plant and equipment totaled $150,000 and $135,000 for the three months ended March 31, 2012 and 2013, respectively.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE D - PROPERTY, PLANT AND EQUIPMENT – continued

Sale of Regional’s Owned Tractor Fleet

On February 17, 2012, in connection with Regional’s Vehicle Lease Service Agreement (see Note H), Regional sold six of its owned tractors for proceeds of $97,000 of which $90,000 was used to fund the deposit required pursuant to the aforementioned agreement and the remainder was used for working capital.

During May 2012 and June 2012, in connection with Regional’s Vehicle Lease Service Agreement (see Note H), Regional sold 21 of its owned tractors for total proceeds of $410,000. The proceeds were used to meet ongoing debt service obligations.

In connection with the sale of the tractor fleet, a gain of $56,000 and $256,000 was recorded during the three months ended March 31, 2012 and year ended December 31, 2012, respectively.

As a result of the aforementioned sale of Regional’s owned tractors, Regional’s truck fleet currently consists of twenty leased tractors and five owned tractors.

RZB Note

In connection with the acquisition of Regional during July 2007, the Partnership funded a portion of the acquisition through a loan of $5,000,000 (“ RZB Note ”) from RB International Finance (USA) LLC, formerly known as RZB Finance LLC (“ RZB ”), dated July 26, 2007 (“ Loan Agreement ”). The RZB Note was due on demand and if no demand, with a one-year maturity. In connection with the RZB Note, Regional granted to RZB a security interest in all of Regional’s assets, including a deed of trust on real property owned by Regional, and the Partnership delivered to RZB a pledge of the outstanding capital stock of Regional.

The RZB Note was converted to a term loan in June 2009 in connection with the Sixth Amendment, Assumption of Obligations and Release Agreement between Regional, the Partnership and RZB (the “ Sixth Amendment ”). The Sixth Amendment provided for an increase in the principal amount of the RZB Note to $4,250,000 as the result of an “incremental loan” of $250,000, established a monthly amortization for the principal amount of the Loan, increased the annual interest rate to 8%, and extended the Maturity Date to April 30, 2012, among other terms and conditions. Regional assumed all obligations of the Partnership under the RZB Note and related collateral agreements upon execution of the Sixth Amendment. The Maturity Date of the RZB Note was extended to May 31, 2014 in connection with the Seventh Amendment to the Loan Agreement among the parties dated May 21, 2010. On November 29, 2012, Regional and RZB entered into a “Limited Waiver and Ninth Amendment” (“ Ninth Amendment ”) to the Loan Agreement. The Ninth Amendment waived the defaults existing at the time of the Ninth Amendment and reduced required monthly amortization payments to $50,000 per month beginning January 31, 2013. The Ninth Amendment also shortened the maturity date of the RZB Note from May 31, 2014 to March 31, 2013. Regional made the January 31, 2013 monthly amortization payment. On March 1, 2013, Regional received a “Notice of Default, Demand for Payment and Reservation of Rights” (“ March 1, 2013 Demand Notice ”) from RZB in connection with the Loan Agreement.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE E — DEBT OBLIGATIONS - Continued

RZB Note – continued

The March 1, 2013 Demand Notice was delivered as the result of Regional’s failure to pay the monthly principal payment in the amount of $50,000 due and payable on February 28, 2013 as prescribed under the Ninth Amendment and the continued default with respect to the non-payment of interest and principal due under the Loan Agreement which had been previously waived pursuant to the Ninth Amendment. The March 1, 2013 Demand Notice declared all Obligations (as defined in the Loan Agreement) immediately due and payable and demanded immediate payment in full of all Obligations, including fees, expenses and other costs of RZB. The March 1, 2013 Demand Notice also (1) contemplated the initiation of foreclosure proceedings in respect of the property owned by Regional and covered by that certain Mortgage, Deed of Trust and Security Agreement dated as of July 26, 2007 and (2) demanded immediate payment of all rents due upon the property pursuant to the terms of the Assignment of Leases and Rents dated July 26, 2006.  In connection with the Hopewell Loan (see “Hopewell Note” below), on March 20, 2013, all obligations unpaid and outstanding under the RZB Loan Agreement totaling $1,975,000 were paid in full. In connection with the closing of the Hopewell Loan Agreement, RZB provided Regional with a payoff letter and released all of the collateral previously held as security. The interest rate for the period January 1, 2013 through March 20, 2013 approximated 9.5 %.

Hopewell Note

On March 20, 2013, Regional entered into a Term Loan and Security Agreement (“ Hopewell Loan Agreement ”) with Hopewell Investment Partners, LLC (“ Hopewell ”) pursuant to which Hopewell would loan Regional of up to $2,500,000 (“ Hopewell Loan ”), of which $1,998,000 was advanced on such date and an additional $252,000 was advanced on March 26, 2013. William M. Comegys III, a member of the Board of Directors of the General Partner, is a member of Hopewell. As a result of this affiliation, the terms of the Hopewell Loan were reviewed by the Conflicts Committee of the Board of Directors of the General Partner. The committee determined that the Hopewell Loan was on terms better than could be obtained from a third-party lender.

In connection with the Hopewell Loan, Regional issued Hopewell a promissory note (“ Hopewell Note ”) and granted Hopewell a security interest in all of Regional’s assets, including a first lien mortgage on the real property owned by Regional and an assignment of rents and leases and fixtures on the remaining assets of Regional. In connection with the Hopewell Loan, the Partnership delivered to Hopewell a pledge of the outstanding capital stock of Regional and the Partnership entered into an unlimited guaranty for the benefit of Hopewell. In addition, Regional and the Partnership entered into an Environmental Certificate with Hopewell representing as to the environmental condition of the property owned by Regional, agreeing to clean up or remediate any hazardous substances from the property, and agreeing, jointly and severally, to indemnify Hopewell from and against any claims whatsoever related to any hazardous substance on, in or impacting the property of Regional.

The principal purpose of the Hopewell Loan was to repay the entire amounts due by Regional to RZB in connection with the Loan Agreement totaling $1,975,000 at the time of payoff, including principal, interest and legal fees and other expenses owed in connection with the Loan Agreement. The remaining amounts provided under the Hopewell Loan to Regional were used for working capital.

The Hopewell Loan matures in three years and carries a fixed annual rate of interest of 12%. Under the terms of the Hopewell Loan, Regional is required to make interest payments only for the first six months beginning April 20, 2013 and then 29 equal monthly payments of $50,000 (principal and interest) from the seventh month through the 35 ^th month with a balloon payment of $1,342,000 due on March 19, 2016.

Per the Hopewell Loan Agreement, Regional is required to provide annual audited and certified quarterly financial statements to Hopewell. The failure to provide those financial statements as prescribed is an event of default, and Hopewell may, by written notice to Regional, declare the Hopewell Note immediately due and payable.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE F – UNIT-BASED PAYMENT

The Partnership may issue options, warrants, rights or appreciation rights with respect to Common Units for any Partnership purpose, including to non-employees for goods and services and to acquire or extend debt, without approval of the Limited Partners. The Partnership applies the provisions of ASC 505 to account for such transactions. ASC 505 requires that such transactions be accounted for at fair value. If the fair value of the goods and services or debt related transactions are not readily measurable, the fair value of the options, warrants, rights or appreciation rights is used to account for such transactions. Central did not record any unit-based payment costs for non-employees for the three months ended March 31, 2012 and 2013 under the fair-value provisions of ASC 505.

NOTE G – UNIT OPTIONS AND EQUITY INCENTIVE PLAN

The Partnership has no employees and is managed by its General Partner. The Partnership applies ASC 718 for options and/or Common Units granted to employees and directors of the General Partner. During the quarter ended March 31, 2006, Central adopted the provisions of ASC 718 for unit-based payments to employees using the modified prospective application transition method. Under this method, previously reported amounts should not be restated to reflect the provisions of ASC 718. ASC 718 requires measurement of all employee unit-based payment awards using a fair-value method and recording of such expense in the consolidated financial statements over the requisite service period. The fair value concepts have not changed significantly in ASC 718; however, in adopting this standard, companies must choose among alternative valuation models and amortization assumptions. After assessing alternative valuation models and amortization assumptions, Central will continue using both the Black-Scholes valuation model and straight-line amortization of compensation expense over the requisite service period for each separately vesting portion of the grant. Central will reconsider use of this model if additional information becomes available in the future that indicates another model would be more appropriate, or if grants issued in future periods have characteristics that cannot be reasonably estimated using this model. As described below on March 20, 2013, the Partnership agreed to issue a grant of 200,000 common units to an executive officer of the General Partner which will fully vest upon issuance. The Partnership will record unit-based compensation upon issuance of the 200,000 common units. Central did not record any unit-based compensation for employees for the three months ended March 31, 2012 and 2013 under the fair-value provisions of ASC 718.

Equity Incentive Plan

On March 9, 2005, the Board of Directors of the General Partner (“ Board ”) approved the 2005 Equity Incentive Plan (“ 2005 Plan ”). The 2005 Plan permits the grant of common unit options, common unit appreciation rights, restricted Common Units and phantom Common Units to any person who is an employee (including to any executive officer) or consultant of Central or the General Partner or any affiliate of Central or the General Partner. The 2005 Plan provides that each outside director of the General Partner shall be granted a common unit option once each fiscal year for not more than 5,000 Common Units, in an equal amount as determined by the Board of Directors. The aggregate number of Common Units authorized for issuance as awards under the 2005 Plan is 750,000. The 2005 Plan remains available for the grant of awards until March 9, 2015, or such earlier date as the Board of Directors may determine. The 2005 Plan is administered by the compensation committee of the Board of Directors. In addition, the Board of Directors may exercise any authority of the compensation committee under the 2005 Plan. Under the terms of the Partnership Agreement and the then applicable rules of the NASDAQ National Market, no approval of the 2005 Plan by the Unitholders of the Partnership was required.

On March 20, 2013, the Board of Directors of the General Partner (“ Board ”), approved the entering into an employment agreement (“ Agreement ”) with Mr. Ian T. Bothwell (“ Executive ”), Executive Vice President, Chief Financial Officer and Secretary of the General Partner and President of Regional (see Note J). Under the terms of the Agreement, the Executive is to be granted 200,000 Common Units of the Partnership under the 2005 Plan which shall vest immediately upon such grant as set forth in a separate Unit Grant Agreement between the Executive and the General Partner.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE G — UNIT OPTIONS AND EQUITY INCENTIVE PLAN - Continued

Equity Incentive Plan - continued

In addition to any grants of Common Units or other securities of the Partnership as the Compensation Committee of the Board may determine from time to time pursuant to one or more of the General Partner’s benefit plans, the General Partner shall provide to the Executive one or more future grants of Common Units equal to the number of common units determined by dividing (1) one and one-half percent (1.5%) of the gross amount paid for each of the next one or more acquisitions completed by the Partnership and/or an affiliate of the Partnership during the term of the Agreement, which gross amount shall not exceed $100 million (each an “ Acquisition ”), by (2) the average value per common unit assigned to the equity portion of any consideration issued by the Partnership and/or an affiliate of the Partnership to investors in connection with each Acquisition including any provisions for adjustment to equity as offered to investors, if applicable. In the event the General Partner does not extend the Agreement after the second anniversary date thereof for any reason other than as provided in the Agreement, the Partnership shall issue to the Executive the number of Common Units determined by dividing (1) the amount calculated by multiplying three-quarters of one percent (0.75%) times the sum determined by subtracting the gross amount paid for each of the Acquisitions completed by the Partnership and/or an affiliate of the Partnership during the term of the Executive’s employment by the General Partner from $100 million by (2) the average value per common unit assigned to the equity portion of any consideration issued by the Partnership and/or an Affiliate of the Partnership to investors in connection with each Acquisition including any provisions for adjustment to equity as offered to investors, if applicable. The Common Units subject to issuance above will be issued pursuant to a Unit Grant Agreement, which grant will be governed by the terms and conditions of the 2005 Plan (or its successor). The right to receive the Common Units pursuant to the above will not terminate until fully issued in the event the Executive is (a) terminated by the General Partner without Cause, (b) the Executive resigns for Good Reason, (c) a termination resulting from a Change in Control of the General Partner, or (d) a termination resulting from the Death or Disability of the Executive as more fully described in the Agreement.

At March 31, 2013, there were no options outstanding under the 2005 Plan. At March 31, 2013, approximately 422,310 Common Units remain available for issuance under the 2005 Plan.

NOTE H - COMMITMENTS AND CONTINGENCIES

Legal Proceedings

VOSH Actions

On July 25, 2005, an equipment failure during the loading of nitric acid from a railcar to a tanker truck resulted in a release of nitric acid and injury to an employee of Regional. Cleanup costs totaled approximately $380,000 in 2005 and were covered entirely by reimbursement from Regional’s insurance carrier. Several lawsuits against Regional were filed by property owners in the area. All of these suits were settled for an aggregate amount of $115,000, which was within insurance coverage limits. The Virginia Department of Labor and Industry, Occupational Safety and Health Compliance (“ VOSH ”) issued a citation against Regional on October 7, 2005 seeking a fine of $4,500. Regional requested withdrawal of the citation and disputed the basis for the citation and the fine. On June 18, 2007, the Commissioner of Labor and Industry filed suit against Regional in the Circuit Court for the City of Hopewell for collection of the unpaid fine. The citation arose from allegations that Regional had failed to evaluate properly the provision and use of employer-supplied equipment.  During September 2012, the Court dismissed the citations after a bench trial. In January 2013, the final order in the matter was issued by the Court. VOSH did not request an appeal of the decision by the required due date.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE H - COMMITMENTS AND CONTINGENCIES - Continued

Legal Proceedings - continued

VOSH Actions – continued

On November 27, 2005, an employee of Regional died following inhalation of turpentine vapors. Under Virginia law, recovery by the deceased employee’s estate was limited to a workers compensation claim, which was closed on April 20, 2007 for the amount of $11,000. The Virginia Department of Labor and Industry, Occupational Safety and Health Compliance issued a citation against Regional on May 24, 2006 seeking a fine of $28,000. Regional requested withdrawal of the citation and disputed the basis for the citation and the fine. The amount of the fine is not covered by insurance. On June 18, 2007, the Commissioner of Labor and Industry for the Commonwealth of Virginia filed suit against Regional in the Circuit Court for the City of Hopewell for collection of the unpaid fine. There were four citations involved in the case referenced above.  One of the citations arose from the Commissioner's allegations that Regional had exposed this employee to levels of hydrogen sulfide gas in excess of the levels permitted by applicable regulations. Another citation arose from the Commissioner's allegations that Regional had not provided respiratory protection equipment needed to protect this employee from hazards in the workplace. The other two citations arose from the Commissioner's allegations that Regional had not evaluated the need for respiratory equipment in this work environment and had not evaluated the need to create a confined-space permit entry system for the employee's work in taking a sample of turpentine from the top of the railcar. During September 2012, the Court dismissed the first two citations after a bench trial. The Court subsequently dismissed the remaining other two citations.  In April 2013, the final order in the matter was issued by the Court. VOSH did not request an appeal of the decision by the required due date.

Other Contingencies

Central is involved with other proceedings, lawsuits and claims in the ordinary course of its business. Central believes that the liabilities, if any, ultimately resulting from such proceedings, lawsuits and claims should not materially affect its consolidated financial results.

TransMontaigne Dispute

Rio Vista Operating Partnership L.P. (“ RVOP ”) is a subsidiary of the Partnership which held liquid petroleum gas assets located in southern Texas and northern Mexico contributed (“ LPG Assets ”) to it by Penn Octane Corporation upon formation of the Partnership. It sold all of the LPG Assets to TransMontaigne in two separate transactions. The first transaction included the sale of substantially all of its U.S. assets, including a terminal facility and refined products tank farm located in Brownsville, Texas and associated improvements, leases, easements, licenses and permits, an LPG sales agreement and its LPG inventory in August 2006. In a separate transaction, RVOP sold its remaining LPG Assets to affiliates of TransMontaigne, including TMOC Corp., in December 2007. These assets included the U.S. portion of two pipelines from the Brownsville terminal to the U.S. border with Mexico, along with all associated rights-of-way and easements and all of the rights for indirect control of an entity owning a terminal site in Matamoros, Mexico. The Purchase and Sale Agreement dated December 26, 2007 (“ Purchase and Sale Agreement ”) between TransMontaigne and RVOP provided for working capital adjustments and indemnification under certain circumstances. RVOP has received demands for indemnification dated December 17, 2008, December 31, 2008, March 17, 2009, May 12, 2009, May 18, 2009, March 18, 2010, September 22, 2010 and January 24, 2011 (“ Indemnification Notices ”) seeking reimbursement from RVOP for $775,000 in claims relating to working capital adjustments and indemnification obligations as prescribed under the Purchase and Sale Agreement.

In addition to the aforementioned claims, the January 24, 2011 Indemnification Notice included a demand for indemnification based on a lawsuit filed by MCAR Development against Razorback, LLC, a subsidiary of TransMontaigne, on January 4, 2011, which lawsuit demands payment of damages resulting from a pipeline meandering outside the recorded pipeline easement. Razorback had requested that RVOP assume the defense of the litigation and provide indemnification to Razorback. RVOP did not agree to assume the defense of the litigation but is cooperating with TransMontaigne in its defense of the litigation.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE H - COMMITMENTS AND CONTINGENCIES - Continued

Legal Proceedings - continued

TransMontaigne Dispute - continued

RVOP intends to work with TransMontaigne to define the scope of the adjustments contained in the Indemnification Notices to an amount which RVOP considers to be more realistic and which also considers RVOP offsets to the amounts already presented by TransMontaigne. Any amount which may subsequently be agreed to by TransMontaigne and RVOP shall first be charged to the $500,000 Holdback provided for in the Purchase and Sale Agreement, and also is subject to the $1,000,000 limitation indemnification. RVOP has accrued a reserve of approximately $283,000 for potential future obligations in addition to the Holdback. RVOP’s management believes that the amount of the TransMontaigne claim will be resolved within the amounts provided.

Terminal Operator Status of Regional Facility

In May 2011, Regional was contacted by the IRS regarding whether its Hopewell, Virginia facility would qualify as a “terminal operator” which handles “taxable fuels” and accordingly is required to register through a submission of Form 637 to the IRS. Code Section 4101 provides that a “fuel terminal operator” is a person that (a) operates a terminal or refinery within a foreign trade zone or within a customs bonded storage facility or, (b) holds an inventory position with respect to a taxable fuel in such a terminal. In June 2011, an agent of the IRS toured the Hopewell, Virginia facility and notified the plant manager verbally that he thought the facility did qualify as a “terminal operator.” As a result, even though Regional disagrees with the IRS agent’s analysis, it elected to submit, under protest, to the IRS a Form 637 registration application in July 2011 to provide information about the Hopewell facility. Regional believes that its Form 637 should be rejected by the IRS because (1) the regulations do not apply to Regional’s facility, (2) the items stored do not meet the definition of a “taxable fuel” and (3) there were no taxable fuels being stored or expected to be stored in the foreseeable future that would trigger the registration requirement. Regional had not received a response with respect to its Form 637 submission or arguments that it is not subject to the Requirements. During December 2012, Regional received notification from IRS’ appeals unit (“ Appeals Unit ”) that the above matter was under review. A telephonic meeting took place in January 2013 whereby the Appeal Unit determined that Regional did not meet the conditions of a terminal operator which handled taxable fuels and that the matter was dismissed. During March 2013, Regional received formal notification from the IRS that the matter was dismissed with no further action required by Regional. As indicated above, should Regional’s operations in the future include activities which qualify Regional as a terminal operator which handles taxable fuels as defined in the Code, Regional would be subject to additional administrative and filing requirements, although the costs associated with compliance are not expected to be material and Regional would be subject to penalties for the failure to file timely with the IRS any future required reports or forms.

Penske Truck Lease

Effective January 18, 2012, Regional entered into a Vehicle Maintenance Agreement (“ Maintenance Agreement ”) with Penske Truck Leasing Co., L. P. (“ Penske ”) for the maintenance of its owned tractor and trailer fleet. The Maintenance Agreement provides for (i) fixed servicing as described in the agreement, which is basically scheduled maintenance, at the fixed monthly rate for tractors and for trailers and (ii) additional requested services, such as tire replacement, mechanical repairs, physical damage repairs, tire replacement, towing and roadside service and the provision of substitute vehicles, at hourly rates and discounts set forth in the agreement. Pricing for the fixed services is subject to upward adjustment for each rise of at least one percent (1%) for the Consumer Price Index for All Urban Consumers for the United States published by the United States Department of Labor. The term of the agreement is 36 months. Regional is obligated to maintain liability insurance coverage on all vehicles naming Penske as a co-insured and indemnify Penske for any loss it or its representatives may incur in excess of the insurance coverage. Penske has the right to terminate the Maintenance Agreement for any breach by Regional upon 60 days written notice, including failure to pay timely all fees owing Penske, maintenance of Regional’s insurance obligation or any other breach of the terms of the agreement.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

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NOTE H - COMMITMENTS AND CONTINGENCIES - Continued

Agreements - continued

Penske Truck Lease - continued

On February 17, 2012, Regional entered into a Vehicle Lease Service Agreement with Penske for the outsourcing of 20 new Volvo tractors (“ New Tractors ”) to be acquired by Penske and leased to Regional, and the outsourcing of the maintenance of the New Tractors to Penske (“ Lease Agreement ”). Under the terms of the Lease Agreement, Regional made a $90,000 deposit, the proceeds for which were obtained from the sale of six of Regional’s owned tractors, and will pay a monthly lease fee per tractor and monthly maintenance charge (“ Maintenance Charge ”) which is based on the actual miles driven by each New Tractor during each month. The Maintenance Charge covers all scheduled maintenance, including tires, to keep the New Tractors in good repair and operating condition. Any replacement parts and labor for repairs which are not ordinary wear and tear shall be in accordance with Penske fleet pricing, and such costs are subject to upward adjustment on the same terms as set forth in the Maintenance Agreement. Penske is also obligated to provide roadside service resulting from mechanical or tire failure. Penske will obtain all operating permits and licenses with respect to the use of the New Tractors by Regional.

The term of the Lease Agreement is for seven years. The New Tractors were delivered by Penske during May 2012 and June 2012. Under the terms of the Lease Agreement, Regional (i) may acquire any or all of the New Tractors after the first anniversary date of the Lease Agreement based on the non-depreciated value of the tractor and (ii) has the option after the first anniversary date of the Lease Agreement to terminate the lease arrangement with respect to as many as five of the New Tractors leased based on a documented downturn in business. Regional is obligated to maintain liability insurance coverage on all vehicles covered by the Lease Agreement on the same basis as in the Lease Agreement.

The Lease Agreement can be terminated by Penske upon an “event of default” by Regional. An event of default includes (i) failure by Regional to pay timely any lease charges when due or maintain insurance coverage as required by the Lease Agreement, (ii) any representation or warranty of Regional is incorrect in any material respect, (iii) Regional fails to remedy any non-performance under the agreement within five (5) days of written notice from Penske, (iv) Regional or any guarantor of its obligations becomes insolvent, makes a bulk transfer or other transfer of all or substantially all of its assets or makes an assignment for the benefit of creditors or (v) Regional files for bankruptcy protection or any other proceeding providing for the relief of debtors. Penske may institute legal action to enforce the Lease Agreement or, with or without terminating the Lease Agreement, take immediate possession of the New Trucks wherever located or, upon five (5) days written notice to Regional, either require Regional to purchase any or all of the New Tractors or make the “alternative payment” described below. In addition, Regional is obligated to pay all lease charges for all such New Tractors accrued and owing through the date of the notice from Penske as described above. Penske’s ability to require Regional to purchase the New Truck fleet or make the “alternative payment” would place a substantial financial burden on Regional.

The Lease Agreement can also be terminated by either party upon 120 days written notice to the other party as to any New Truck subject to the agreement on any annual anniversary of such tractor’s in-service date. Upon termination of the Lease Agreement by either party, Regional shall, at Penske’s option, either acquire the New Tractor that is the subject of the notice at the non-depreciated value of such tractor, or pay Penske the “alternative payment.” The “alternative payment” is defined in the Lease Agreement as the difference, if any, between the fair market value of the New Tractor and such tractor’s “depreciated Schedule A value” ($738 per month commencing on the in-service date of such tractor). If the Lease Agreement is terminated by Penske and Regional is not then in default under any term of the Lease Agreement, Regional is not obligated to either acquire the New Tractor that is the subject of the termination or pay Penske the “alternative payment” as described above.

In connection with the delivery of the New Tractors, Regional sold its remaining owned tractor fleet, except for several owned tractor units which were retained to be used for terminal site logistics.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

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NOTE H - COMMITMENTS AND CONTINGENCIES - Continued

Agreements - continued

Asphalt Agreement

On November 30, 2000, Regional renewed a Storage and Product Handling Agreement with a customer with an effective date of December 1, 2000 (“ Asphalt Agreement ”). The Asphalt Agreement provides for the pricing, terms and conditions under which the customer will purchase terminal services and facility usage from Regional for the storage and handling of the customer’s asphalt products. The Asphalt Agreement was amended on October 15, 2002 with an effective date of December 1, 2002 (“ Amended Asphalt Agreement ”). The term of the Amended Asphalt Agreement was five years with an option by the customer for an additional five-year renewal term, which the customer exercised in July 2007. After the additional five-year term, the Amended Asphalt Agreement renews automatically for successive one-year terms unless terminated upon 120 days advance written notice by either party. The Asphalt Agreement automatically renewed through December 1, 2013. The annual fee payable to Regional for the initial five-year term of the Amended Asphalt Agreement is approximately $500,000, payable in equal monthly installments, subject to adjustments for inflation and certain facility improvements. In exchange for the annual fee, Regional agrees to provide minimum annual throughput of 610,000 net barrels per contract year, with additional volume to be paid on a per barrel basis. During the term of the Amended Asphalt Agreement, Regional agrees to provide three storage tanks and certain related equipment to the customer on an exclusive basis as well as access to Regional’s barge docking facility.

On March 19, 2012, one of the storage tanks (“ Storage Tank ”) leased under the Amended Asphalt Agreement was discovered to have a leak. During April 2012, after removal of the existing product from the Storage Tank, the customer of the Storage Tank was notified by Regional that the Storage Tank was no longer available for use until necessary repairs were completed. During the year ended December 31, 2012, Regional recorded a loss of $238,000 (“Asphalt Loss”) in connection with the leak, including the estimated amounts to repair the Storage Tank. Lost revenue with respect to the Storage Tank totaled approximately $200,000 in 2012 and $75,000 for the three months ended March 31, 2013. Regional expects that the Storage Tank will be operational during May 2013. Regional’s insurance providers have notified Regional that the incident did not fall within insurance coverage limits.

Fuel Oil Agreement

On November 16, 1998, Regional renewed a Terminal Agreement with a customer with an effective date of November 1, 1998, as amended on April 5, 2001, October 11, 2001 and August 1, 2003 (“ Fuel Oil Agreement ”). The Fuel Oil Agreement provides for the pricing, terms and conditions under which Regional will provide terminal facilities and services to the customers for the delivery of fuel oil. Pursuant to the agreement, as amended, Regional agreed to provide three storage tanks, certain related pipelines and equipment, and at least two tractor tankers to the customer on an exclusive basis, as well as access to Regional’s barge docking facility. In exchange for use of Regional’s facilities and services, the customer paid an annual tank rental amount of approximately $300,000 plus a product transportation fee calculated on a per 100 gallon basis, each subject to annual adjustment for inflation. Regional agreed to deliver a minimum daily quantity of fuel oil on behalf of the customer. During December 2008, the customer and Regional negotiated a new Fuel Oil Agreement whereby Regional was only required to provide two storage tanks through May 2009 and one storage tank through November 30, 2011, which was subsequently extended by the customer through November 30, 2013 in accordance with the terms of the Fuel Oil Agreement. In addition, under the newly negotiated Fuel Oil Agreement, the customer pays an annual tank rental amount of approximately $308,000 plus a product transportation fee calculated on a per gallon basis, each subject to annual adjustment for inflation. The Fuel Oil Agreement expires on November 30, 2013.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

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NOTE H — COMMITMENTS AND CONTINGENCIES – Continued

Agreements - continued

No. 4 Oil Agreement

On January 7, 2009, Regional entered into a Terminal Agreement with Noble Oil Services, Inc. with an effective date of January 7, 2009 and an expiration date of January 6, 2012. The Terminal Agreement provided for the pricing, terms, and conditions under which Regional would provide terminal facilities and services to the customer for the receipt, storage (“ Tank 120 ”) and distribution of No. 4 Oil or vacuum gas oil. Pursuant to the agreement, the customer paid an annual tank rental amount of approximately $330,000, plus a product transportation fee calculated on a per run basis, each subject to annual adjustment for inflation. The customer did not renew this contract and Tank 120 remained idle until January 1, 2013 when it was leased to a new customer (see below).

VGO Agreement

On May 1, 2009, Regional entered into a Terminal Agreement with Noble Oil Services, Inc. with an effective date of May 1, 2009, as amended June 2, 2009, and June 10, 2009. The VGO Terminal Agreement expired January 6, 2012. The VGO Terminal Agreement provided for the customer to pay an annual tank rental amount of approximately $288,000, plus a product transportation fee calculated on a per run basis, each subject to annual adjustment for inflation. The customer did not renew this contract. This tank was leased to a new customer beginning March 1, 2012 (see below).

Sodium Hydroxide Agreement

On September 27, 2007, Regional entered into a Terminal Agreement with Suffolk Solutions, an affiliate of Suffolk Sales with an effective date of June 1, 2008 and an expiration date of May 30, 2013 subject to being automatically renewed in one-year increments unless terminated upon 90 days advance written notice by either party. This Terminal Agreement provides for the pricing, terms, and conditions under which Regional will provide terminal facilities and services to the customer for the receipt, storage and distribution of sodium hydroxide. Pursuant to the agreement, Regional agrees to provide two storage tanks, certain related pipelines and equipment, necessary tractor tankers, as well as access to Regional’s barge docking and rail facilities. In exchange for use of Regional’s facilities and services, the customer pays an annual tank rental amount of approximately $314,172, plus a product transportation fee calculated on a per run basis, each subject to annual adjustment for inflation. Regional also contracts with Suffolk to provide other transportation and trans-loading services of specialty chemicals. The parties are currently negotiating a renewal of the Terminal Agreement.

No. 6 Oil Agreements

On March 1, 2012, Regional entered into a Services Agreement with a customer with an effective date of March 1, 2012 and a termination date of February 28, 2015, subject to being automatically renewed in one-year increments unless terminated upon 180 days advance written notice by either party. This Services Agreement provides for the pricing, terms, and conditions under which Regional will provide terminal facilities and services to the customer for the receipt, storage and distribution of No. 6 oil. Pursuant to the agreement, Regional agrees to provide one storage tank (capacity of approximately 1.2 million gallons), certain related pipelines and equipment, necessary tractor tankers, as well as access to Regional’s barge docking and rail facilities. In exchange for use of Regional’s facilities and services, the customer pays an annual tank rental amount of approximately $360,000, plus loading and unloading fees. As part of the lease, Regional insulated the tank and made other modifications to the tank and barge line.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

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NOTE H — COMMITMENTS AND CONTINGENCIES – Continued

Agreements - continued

MORLIFE 5000 Agreement

During January 1, 2013, Regional entered into a Services Agreement with a customer with an effective date of January 1, 2013 and a termination date of December 31, 2015. The customer has the sole discretion to extend the term of the Services Agreement prior to expiration for up to two successive one-year terms upon providing Regional 90 days advance written notice prior to expiration of the Services Agreement. This Services Agreement provides for the pricing, terms, and conditions under which Regional will provide terminal facilities and services to the customer for the receipt, storage and distribution of MORLIFE 5000, an asphalt additive. Pursuant to the agreement, Regional agrees to provide Tank 120, certain related pipelines and equipment, necessary tractor tankers, as well as access to Regional’s barge docking and rail facilities. In exchange for use of Regional’s facilities and services, the customer pays an annual tank rental amount of approximately $420,000, plus loading and unloading fees.

Employment Agreement

On March 20, 2013, the Board approved an employment agreement with Mr. Ian T. Bothwell, Executive Vice President, Chief Financial Officer and Secretary of the General Partner and President of Regional (“ Executive ”). The general provisions of the employment agreement (“ Agreement ”) include:

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE H — COMMITMENTS AND CONTINGENCIES – Continued

Employment Agreement – continued

In the event the General Partner does not extend this Agreement after the second anniversary date of this Agreement for any reason other than as provided in the Agreement, the Partnership shall issue to Executive the number of Common Units of the Partnership determined by dividing (1) the amount calculated by multiplying three-quarters of one percent (0.75%) times the sum determined by subtracting the gross amount paid for each of the Acquisitions completed by the Partnership and/or an affiliate of the Partnership during the term of Executive’s employment by the General Partner from $100 million by (2) the average value per Common Unit assigned to the equity portion of any consideration issued by the Partnership and/or an Affiliate of the Partnership to investors in connection with each Acquisition including any provisions for adjustment to equity as offered to investors, if applicable. The Common Units subject to issuance under this bullet point will be issued pursuant to a Unit Grant Agreement, which grant will be governed by the terms and conditions of the 2005 Plan (or its successor) and the Unit Grant Agreement. The right to receive the Common Units pursuant to this bullet point will not terminate until fully issued in the event the Executive is (a) terminated by the General Partner without Cause, (b) the Executive resigns for Good Reason, (c) due to a termination resulting from Change in Control of the General Partner, or (d) a termination resulting from Death or Disability of the Executive as more fully described in the Agreement. All Common Units issued pursuant to this bullet point will be registered pursuant to a Form S-8 registration statement to be filed by the Partnership or an amendment to the current Form S-8 registration statement on file with the SEC if still deemed effective by the SEC.

In the event that the parties decide not to renew the Agreement, the General Partner terminates the Agreement for cause or the Executive terminates the Agreement without good reason, the Executive shall be entitled to receive all accrued and unpaid salary, expenses, vacation, bonuses and incentives awarded prior to the termination date (Accrued Amounts). In the event the Executive is terminated pursuant to clauses (a), (b) and (c) in the last bullet point above, then the Executive shall be entitled to receive the Accrued amounts together with (i) severance pay equal to two (2) times the sum of (1) the Executive’s Base Salary in the year in which the termination date occurs and (2) the amount of the Annual and Anniversary Bonus for the year prior to the year in which the termination date occurs and (ii) for a period of up to 18 months following termination, continuation of all employee benefit plans and health insurance as provided prior to termination. The Agreement also contains restrictions on the use of “confidential information” during and after the term of the Agreement and restrictive covenants that survive the termination of the Agreement including (i) a covenant not to compete, (ii) a non-solicitation covenant with respect to employees and customers and (iii) a non-disparagement covenant, all as more fully described in the Agreement.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE H - COMMITMENTS AND CONTINGENCIES - Continued

Employment Agreement – continued

Payment of Compensation

Effective November 1, 2011, Messrs. Anbouba and Montgomery, executive officers of the General Partner, agreed to forego any further compensation until such time as the General Partner completed its plan for recapitalizing the Partnership and obtaining sufficient funds needed to conduct its operations. On January 1, 2012, the Chief Financial Officer of the General Partner also ceased receiving compensation. During June 2012, the Chief Financial Officer of the General Partner began receiving a portion of his ongoing monthly salary. The Partnership has also failed to reimburse expenses to Messrs. Anbouba and Montgomery since September 2011 and the Chief Financial Officer since September 2011. Central has looked at several different financing scenarios to date, each involving the acquisition of additional assets, to meet its future capital needs. None of these acquisitions has been successfully completed. Management continues to seek acquisition opportunities for Central to expand its assets and generate additional cash from operations. It is anticipated that the payment of compensation and reimbursement of expenses to the General Partner’s executive officers will be reinstated once an acquisition transaction is completed.

Partnership Tax Treatment

The Partnership is not a taxable entity for U.S. tax purposes (see below) and incurs no U.S. Federal income tax liability. Regional is a corporation and as such is subject to U.S. Federal and State corporate income tax. Each Unitholder of Partnership is required to take into account that Unitholder’s share of items of income, gain, loss and deduction of Partnership in computing that Unitholder’s federal income tax liability, even if no cash distributions are made to the Unitholder by Partnership. Distributions by Partnership to a Unitholder are generally not taxable unless the amount of cash distributed is in excess of the Unitholder’s adjusted basis in Partnership.

Regional is a corporation and as such is subject to U.S. federal and state corporate income tax. Most of its income is not “qualifying income” as discussed below. Central believes that a portion of Regional’s income could be considered as “qualifying income”. Central believes that income derived from the storage of Asphalt, No. 2 Oil and/or No. 6 Oil could constitute “qualifying income.” Central may explore options regarding the reorganization of some or all of its Regional assets into a more efficient tax structure to take advantage of the tax savings that could result from the “qualified income” being generated at the Partnership level rather than at the Regional level. Central expects that there would be a tax expense associated with the transfer of income from Regional to the Partnership.

Section 7704 of the Internal Revenue Code (Code) provides that publicly traded partnerships shall, as a general rule, be taxed as corporations despite the fact that they are not classified as corporations under Section 7701 of the Code. Section 7704 of the Code provides an exception to this general rule for a publicly traded partnership if 90% or more of its gross income for every taxable year consists of “qualifying income” (Qualifying Income Exception). For purposes of this exception, “qualifying income” includes income and gains derived from the exploration, development, mining or production, processing, refining, transportation (including pipelines) or marketing of any mineral or natural resource. Other types of “qualifying income” include interest (other than from a financial business or interest based on profits of the borrower), dividends, real property rents, gains from the sale of real property, including real property held by one considered to be a “dealer” in such property, and gains from the sale or other disposition of capital assets held for the production of income that otherwise constitutes “qualifying income”. Non qualifying income which is held and taxed through a taxable entity (such as Regional), is excluded from the calculation in determining whether the publicly traded partnership meets the qualifying income test. The Partnership estimates that more than 90% of its gross income (excluding Regional) was “qualifying income.” No ruling has been or will be sought from the IRS and the IRS has made no determination as to the Partnership’s classification as a partnership for federal income tax purposes or whether the Partnership’s operations generate a minimum of 90% of “qualifying income” under Section 7704 of the Code.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE H — COMMITMENTS AND CONTINGENCIES – Continued

Partnership Tax Treatment - continued

If the Partnership was classified as a corporation in any taxable year, either as a result of a failure to meet the Qualifying Income Exception or otherwise, the Partnership’s items of income, gain, loss and deduction would be reflected only on the Partnership’s tax return rather than being passed through to the Partnership’s Unitholders, and the Partnership’s net income would be taxed at corporate rates.

If the Partnership was treated as a corporation for federal income tax purposes, the Partnership would pay tax on income at corporate rates, which is currently a maximum of 35%. Distributions to Unitholders would generally be taxed again as corporate distributions, and no income, gains, losses, or deductions would flow through to the Unitholders. Because a tax would be imposed upon the Partnership as a corporation, the cash available for distribution to Unitholders would be substantially reduced and the Partnership’s ability to make minimum quarterly distributions would be impaired. Consequently, treatment of the Partnership as a corporation would result in a material reduction in the anticipated cash flow and after-tax return to Unitholders and therefore would likely result in a substantial reduction in the value of the Partnership’s Common Units.

Current law may change so as to cause the Partnership to be taxable as a corporation for federal income tax purposes or otherwise subject the Partnership to entity-level taxation. The partnership agreement provides that, if a law is enacted or existing law is modified or interpreted in a manner that subject the Partnership to taxation as a corporation or otherwise subjects the Partnership to entity-level taxation for federal, state or local income tax purposes, then the minimum quarterly distribution amount and the target distribution amount will be adjusted to reflect the impact of that law on the Partnership.

NOTE I – MAJOR CUSTOMERS AND CONCENTRATIONS OF CREDIT RISK

Major Customers

For the three months ended March 31, 2013, SGR Energy LLC, Suffolk Sales, MeadWestVaco, and General Chemical Corporation accounted for approximately 21%, 18%, 13% and 12% of Regional’s revenues, respectively, and approximately 15%, 18%, 20% and 15% of Regional’s accounts receivable, respectively. PVS Chemicals, Inc. accounted for 7% of Regional's revenues and 11% of Regional's accounts receivables. Olin Corporation accounted for 6% of Regional’s revenues and 11% of Regional’s accounts receivables.

Concentrations of Credit Risk

The balance sheet items that potentially subject Central to concentrations of credit risk are primarily cash and cash equivalents and accounts receivable. Central maintains cash balances in different financial institutions. Balances in accounts are insured up to Federal Deposit Insurance Corporation ( FDIC ) limits of $250,000 per institution. At March 31, 2013, Central did not have any cash balances in financial institutions in excess of FDIC insurance coverage. Concentrations of credit risk with Regional’s accounts receivable are mitigated by Regional’s ongoing credit evaluations of its customers.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE J — INCOME TAXES

Tax Liabilities

IRS Installment Agreement

On November 17, 2010, Regional entered into an installment agreement (“ IRS Installment Agreement ”) with the Internal Revenue Service (“ IRS ”) for the payment of $384,000 owing in income taxes, penalties and interest in connection with the income tax return filed for the period November 2006 to July 27, 2007.

In addition to the $384,000, the IRS Installment Agreement provided for the $198,000 of income taxes, penalties and interest due in connection with the December 31, 2008 income tax return that was filed in 2010 to be included as part of the overall balance of the IRS Installment Agreement at such time that those balances outstanding were formally assigned for collection within the IRS. Regional paid all taxes due and owing to the IRS for the tax period July 28, 2007 to December 31, 2007 prior to entering into the IRS Installment Agreement. During 2009, the Partnership and RVOP allocated expenses to Regional for the period years 2008 and 2009. The amount of the allocated expenses for those periods totaled approximately $1,100,000. During the three months ended March 31, 2011, the Partnership and RVOP allocated additional expenses to Regional of $419,000 for the period from July 28, 2007 to December 31, 2007. Regional has amended its previously filed income tax returns for the period from July 28, 2007 to December 31, 2007 and for the year ended December 31, 2008 to reflect the allocated expenses and other income tax adjustments which eliminated the $198,000 amount referred to above. The effect on income tax payable and income tax expense for those changes was reflected in the 2009 consolidated financial statements of Central. During March 2012, the IRS Installment Agreement was fully paid. Subsequently, Regional received written notification from the IRS that the lien filed in connection with the IRS Installment Agreement was released.

IRS 2013 Installment Agreement

During the three months ended March 31, 2013, Regional has recorded income tax expense of $14,000. As of March 31, 2013, Regional has accrued $60,000 and $54,000 for federal and state income taxes and associated penalties and interest, respectively, which includes $44,000 and $125,000 of income tax benefits recorded during the three months ended March 31, 2013 and the year ended December 2012, respectively, resulting from losses incurred during those periods. Regional intends to carryback and amend the previously filed income tax returns for the year ended December 31, 2011 for the losses incurred during the year ended December 31, 2012. Due to Regional’s deficit in working capital, Regional has thus far been unable to make any significant estimated tax payments for the taxable year ended December 31, 2011. Under the provisions of the Code, taxpayers are subject to penalties for late payment of taxes based on the original amount of tax reported without consideration for reductions in actual taxes owed resulting from a carryback of losses from a future tax period. Regional was notified by the IRS during 2012 that penalties were due in connection with the failure to pay the taxes originally reported due for the tax year December 31, 2008 as described above, which were subsequently reduced to zero as a result of a carryback of net operating losses that were incurred for the year ended December 31, 2009. Regional’s appeal of the decision by the IRS which originally denied the request by Regional to have the penalties which were assessed in connection with the 2008 tax return abated due to reasonable cause was denied. Regional has also been notified by the Commonwealth of Virginia, Department of Taxation (“VDOT”) that penalties and interest were also due in connection with past due income taxes.

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NOTE J — INCOME TAXES - Continued

Tax Liabilities – continued

IRS 2013 Installment Agreement – continued

On February 18, 2013, Regional submitted an installment agreement (the “ IRS 2013 Installment Agreement ”) with the IRS for the payment of $205,000 owing in income taxes, penalties and interest in connection with the income tax return filed for the years December 31, 2008 and December 31, 2011. Regional has yet to receive confirmation from the IRS that the IRS 2013 Installment Agreement has been approved. Under the terms of the IRS 2013 Installment Agreement, Regional was required to pay $5,000 on February 25 and is required to make payments of $10,000 per month beginning March 25, 2013 until all amounts owing under the IRS Installment Agreement, including continuing interest and penalties on outstanding balances, have been paid in full. As of April 25, 2013, Regional has made all of the required payments under the IRS 2013 Installment Agreement. Regional intends to file an amendment to the previously filed 2011 tax return which would reduce the amount of income taxes due for that period. The IRS 2013 Installment Agreement does not provide the ability to offset or reduce the amount of the obligation based on future adjustments to amounts due which originally comprised the amounts due under the IRS 2013 Installment Agreement. The IRS can cancel the IRS 2013 Installment Agreement for a number of reasons, including the late payment of any installment due under the agreement, the failure to pay timely all tax amounts due, or to provide financial information when requested. Regional is currently in discussions with the VDOT regarding the ability to enter into an installment agreement in connection with unpaid income taxes, penalties and interest. Regional intends to file an amendment to the previously filed 2011 state income tax return which would reduce the amount of income taxes due for that period.

Regional has timely applied for an automatic extension to file its 2012 federal and state income tax returns and expects to deliver the 2012 tax returns by the required extensions due date, which is September 15, 2013.

Late Filings and Delivery of Schedules K-1 to Unitholders

The Partnership does not file a consolidated tax return with Regional since this wholly-owned subsidiary is a C corporation. On June 14, 2011, the Partnership filed the previously delinquent federal partnership tax returns for the periods from January 1, 2008 through December 31, 2008 and January 1, 2009 through December 31, 2009. On June 23, 2011, the Partnership also distributed the previously delinquent Schedules K-1 for such taxable periods to its Partners. The Partnership timely filed its federal partnership tax returns for the years ended December 31, 2010 and December 31, 2011, and delivered the Schedules K-1 to its Unitholders for those tax periods. The Partnership also filed all of the previously delinquent required state partnership tax returns for the years ended December 31, 2008 and 2009 during 2011. The Partnership timely filed all the required state partnership tax returns for the years ended December 31, 2010 and December 31, 2011. The Internal Revenue Code of 1986, as amended (the “ Code ”), provides for penalties to be assessed against taxpayers in connection with the late filing of the federal partnership returns and the failure to furnish timely the required Schedules K-1 to investors. Similar penalties are also assessed by certain states for late filing of state partnership returns. The Code and state statutes also provide taxpayer relief in the form of reduction and/or abatement of penalties assessed for late filing of the returns under certain circumstances. The Internal Revenue Service (“ IRS ”) previously notified the Partnership that its calculation of penalties for the delinquent 2008 and 2009 tax returns was approximately $2.5 million.

The Partnership previously estimated that the maximum penalty exposure for all state penalties for delinquent 2008 and 2009 tax returns was $940,000.

During September 2011, the Partnership submitted to the IRS its request for a waiver of the penalties for failure to timely file the Partnership’s federal tax returns and associated K-1’s for the tax years 2008 and 2009. The waiver request was made pursuant to Code Section 6698(a)(2) which provides that the penalty will not apply if the taxpayer establishes that its failure to file was due to reasonable cause. The Partnership also requested a waiver based on the IRS’s past administrative policies towards first offenders.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE J — INCOME TAXES – Continued

Tax Liabilities – continued

Late Filings and Delivery of Schedules K-1 to Unitholders – continued

During September 2011, the Partnership received notice from the IRS that is was opening an administrative procedure to audit the 2008 and 2009 tax returns of the Partnership and Central Energy GP LLC. On November 19, 2012, the Partnership received a notice from the IRS that its request for a waiver of the penalties for failure to timely file the Partnership’s federal tax returns and associated K-1’s for tax years 2008 and 2009, was denied (“ Notice ”). The Notice indicated that the information submitted in connection with the request did not establish reasonable cause or show due diligence. In connection with the Notice, the Partnership had the right to appeal the decision and/or supply additional information for the IRS to reconsider the denial. On January 11, 2013, the Partnership submitted its appeal of the Notice. On February 8, 2013, the Partnership received notice from the IRS that its request to remove the 2008 penalties was granted and that the request to remove the 2009 penalties was currently under review. The Partnership would be entitled to pursue other avenues of relief if all of its appeal efforts for the removal of the 2009 penalties are unsuccessful. The amount of the IRS penalties for the 2009 tax year total approximately $1.2 million and continue to accrue interest until the penalties are ultimately satisfied.

Since filing the delinquent 2008 and 2009 state partnership tax returns, the Partnership had also (i) submitted a request for abatement of penalties based on reasonable cause and/or (ii) applied for participation into voluntary disclosure and compliance programs for first offenders which provide relief of the penalties to those states which impose significant penalties for late filing of state returns (“ Requests ”). During 2012, the Partnership received notices from all of the applicable states that the Requests to have the penalties abated and/or waived through participation in voluntary disclosure and compliance programs were granted.

The Partnership has accrued a total of approximately $1.1 million through March 31, 2013 as its estimate of the penalty exposure related to its failure to file timely its federal tax return for the 2009 tax year. The Partnership no longer is liable for penalties for late filings of state tax returns for 2008 and 2009. There can be no assurance that the Partnership’s request for relief from the federal tax penalties will be approved by the IRS or that the Partnership’s estimate of its penalty exposure is accurate. The Partnership does not currently have the financial resources to pay the penalties that may be assessed by the IRS.

The Partnership has timely applied for an automatic extension to file its 2012 federal and state income tax returns and Schedule K-1’s and expects to deliver the 2012 tax returns and Schedules K-1 to its Unitholders by the required extensions due date, which is September 15, 2013. However, there is no certainty that the Schedules K-1 for the 2012 Tax Year will be completed and delivered timely to Unitholders by the Partnership due its lack of operating capital.

NOTE K — ENVIRONMENTAL MATTERS

Regional is subject to various federal, state and local laws and regulations relating to the protection of the environment. Regional has established procedures for the ongoing evaluation of its operations, to identify potential environmental exposures and to comply with regulatory policies and procedures. Regional accounts for environmental contingencies in accordance with ASC 450. Environmental expenditures that relate to current operations are expensed or capitalized as appropriate. Expenditures that relate to an existing condition caused by past operations, and do not contribute to current or future revenue generation, are expensed. Liabilities for environmental contingencies are recorded when environmental assessments and/or clean-ups are probable and the costs can be reasonably estimated. Central maintains insurance which may cover in whole or in part certain types of environmental contingencies. For the quarters ended March 31, 2012 and 2013, Regional had no environmental contingencies requiring specific disclosure or the recording of a liability.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE L — RELATED PARTY TRANSACTIONS

The General Partner has a legal duty to manage the Partnership in a manner beneficial to the Partnership’s Unitholders. However, the General Partner also has a legal duty to manage its affairs in a manner that benefit its members. This can create a conflict of interest between the Unitholders of the Partnership and the members of the General Partner. The Partnership Agreement provides certain requirements for the resolution of conflicts, but also limits the liability and reduces the fiduciary duties of the General Partner to the Unitholders. The Partnership Agreement also restricts the remedies available to Unitholders for actions that might otherwise constitute breaches of the General Partner’s fiduciary duty.

Advances from General Partner

During the year ended December 31, 2011 and the nine months ended September 30, 2012, the General Partner made cash advances to the Partnership of $955,000 and $30,000, respectively, for the purpose of funding working capital. On September 14, 2012, a Super-Majority of the Members, as defined in the Second Amended and Restated Limited Liability Company Agreement of the General Partner, dated April 12, 2011, as amended (“ Agreement ”), approved the issuance and sale by the General Partner of 12,000 additional Membership Interests of the General Partner (“ Additional Interests ”) at a purchase price of $50.00 per unit, pursuant to Sections 3.2(a) and 6.13(a) of the Agreement (“ GP Sale ”). The Additional Interests were purchased by all the existing members of the General Partner, except 144 units offered to one existing member (“ Unsubscribed Units ”), in accordance with their pro rata ownership of the General Partner. In accordance with the Agreement, the General Partner offered the Unsubscribed Units to those members whom participated in the GP Sale for which those members also purchased their pro rata portion of the Unsubscribed Units.

As of December 31, 2012 and March 31, 2013, $434,000 and $63,000, respectively, of the net proceeds from the GP Sale, which totaled $507,000 (after the offset of $93,000 of prior advances from Messrs. Anbouba and Montgomery that were applied towards their purchase price amounts due in connection with the GP Sale) were used by the General Partner to fund working capital requirements of the Partnership, including the payment of certain outstanding obligations. All funds advanced to the Partnership by the General Partner since November 17, 2010 have been treated as a loan pursuant to the terms of an intercompany demand promissory note effective March 1, 2012. The intercompany demand note provides for advances from time to time by the General Partner to the Partnership of up to $2,000,000. Repayment of such advances, together with accrued and unpaid interest, is to be made in 12 substantially equal quarterly installments starting with the quarter ended March 31, 2016. The note bears interest at the imputed rate of the IRS for medium term notes. The rate at March 1, 2013 is 1.1% per annum and such rate is adjusted monthly by the IRS under IRB 625. At March 31, 2013, the total amount owed to the General Partner by the Partnership, including accrued interest, was $1,576,000.

Intercompany Loans and Receivables

Regional Acquisition Funding

In connection with the Regional acquisition, on July 26, 2007 Regional issued to the Partnership a promissory note in the amount of $2,500,000 (“ Central Promissory Note ”) in connection with the remaining funding needed to complete the acquisition of Regional. Interest on the Central Promissory Note is 10% annually and such interest is payable quarterly. The Central Promissory Note is due on demand. Regional has not made an interest payment on the Central Promissory Note since its inception. Interest is accruing but unpaid. The balance on the note at March 31, 2013 is $3,921,000. The payment of this amount is subordinated to the payment of the Hopewell Note by Regional.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE L — RELATED PARTY TRANSACTIONS – Continued

Intercompany Loans and Receivables – continued

Other Advances

In addition to the Central Promissory Note, there have been other intercompany net advances made from time to time from the Partnership and/or RVOP to Regional, including the $1.0 million advanced by the Partnership to Regional in connection with the third amendment to the RZB Loan Agreement and allocations of corporate expenses, offset by actual cash payments made by Regional to the Partnership and/or RVOP. These intercompany amounts were historically evidenced by book entries. Effective March 1, 2012, Regional and the Partnership entered into an intercompany demand promissory note incorporating all advances made as of December 31, 2010 and since that date. The note bears interest at the rate of 10% annually from January 1, 2011. At March 31, 2013, the intercompany balance owed by Regional to the Partnership and/or RVOP is approximately $1,542,000, which includes interest. This amount is due to the Partnership and RVOP on demand; however, as is the case with the Central Promissory Note, payment of these amounts is also subordinated to payment of the Hopewell Note by Regional.

Allocated Expenses Charged to Subsidiary

Regional is charged for direct expenses paid by the Partnership on its behalf, as well as its share of allocable overhead for expenses incurred by the Partnership which are indirectly attributable for Regional related activities. For the three months ended March 31, 2012 and 2013, Regional recorded allocable expenses of $119,000 and $58,000, respectively.

Reimbursement Agreements

Effective November 17, 2010, the Partnership moved its principal executive offices to Dallas, Texas. As a result, it has entered into a Reimbursement Agreement with AirNow Compression Systems, LTD, an affiliate of Imad K. Anbouba, the General Partner’s Chief Executive Officer and President. The agreement provides for the monthly payment of allocable “overhead costs,” which include rent, utilities, telephones, office equipment and furnishings attributable to the space utilized by employees of the General Partner. The term of the agreement is month-to-month and can be terminated by either party on 30 day’s advance written notice. Effective January 1, 2011, the Partnership entered into an identical agreement with Rover Technologies LLC, a limited liability company affiliated with Ian Bothwell, the General Partner’s Executive Vice President, Chief Financial Officer and Secretary, located in Manhattan Beach, California. Mr. Bothwell is a resident of California and lives in Manhattan Beach. Since June 2012, Regional has been directly charged for its allocated portion of Rover Technologies LLC’s expenses.

The Partnership has not reimbursed AirNow Compression Systems, LTD. since January 2013 or Rover Technologies LLC since September 2011 for the overhead costs associated with offices maintained on the premises of each affiliated organization. Management intends to satisfy outstanding expense reimbursements upon completion of a recapitalization. For the three months ended March 31, 2012 and 2013, expenses billed in connection with both of these agreements were $27,000 and $17,000, respectively.

NOTE M — REALIZATION OF ASSETS

The unaudited consolidated balance sheets of Central have been prepared in conformity with accounting principles generally accepted in the United States of America, which contemplate continuation of Central as a going concern. Central had a loss from operations for the year ended December 31, 2012 and the three months ended March 31, 2013. During March 2013, the RZB Note ($1,970,000 at December 31, 2012) was repaid with proceeds from the $2,250,000 advance received by Regional under the Hopewell Loan.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE M — REALIZATION OF ASSETS – Continued

Regional’s unpaid income taxes totaled approximately $282,000 at March 31, 2013, including penalties and interest and excluding approximately $169,000 of adjustments for future net operating loss carrybacks, and are required to be paid in accordance with the terms of the IRS 2013 Installment Agreement and the future terms to be arranged with the VDOT. In addition, the Partnership is liable for the federal late filing penalties related to the Partnership’s failure to deliver timely Schedules K-1 for the 2009 Tax Year to its Unitholders of up to $1,200,000. Central’s deficit in working capital, excluding the current amounts due under the Hopewell Loan and income taxes, penalties and interest, totaled $2,000,000 at March 31, 2013. RVOP is also responsible for contingencies associated with the TransMontaigne dispute (see Note H – Commitments and Contingencies – TransMontaigne Dispute). The Partnership and the General Partner have limited cash resources and are dependent on Regional to fund ongoing corporate expenses.

Substantially all of Central’s assets are pledged or committed to be pledged as collateral for the Hopewell Note, and therefore, Central is unable to obtain additional financing collateralized by those assets. While Central believes that Regional will have sufficient working capital for future operations assuming (a) the Storage Tank is placed back into service as currently projected, (b) the expected increase in revenues from recent contracts entered into by Regional are realized, (c) the expiring contracts during 2013 are renewed without disruption in service and at terms no less favorable than the existing contract terms, (d) that Regional’s obligations to creditors are not accelerated, and (e) that Regional’s costs to operate do not increase, the amount of working capital which Regional can provide to Central, if any, to fund general overhead is limited.

Should Central need additional capital in excess of the cash generated from operations to make the Hopewell Note payments, for payment of taxes, penalties and interest, for payment of the contingent liabilities, for expansion, repair of the Storage Tank, capital improvements to existing assets, for working capital or otherwise, its ability to raise capital would be hindered by the existing pledge. In addition, the Partnership has obligations under existing registrations rights agreements. These rights may be a deterrent to any future equity financings. Management continues to seek acquisition opportunities for the Partnership to expand its assets and generate additional cash from operations. As described above, there is no assurance that Regional will have sufficient working capital to cover any of the ongoing overhead expenses of the Partnership for the period of time that management believes is necessary to complete an acquisition that will provide additional working capital for the Partnership. If the Partnership does not have sufficient cash reserves, its ability to pursue additional acquisition transactions will be adversely impacted. Furthermore, despite significant effort, the Partnership has thus far been unsuccessful in completing an acquisition transaction. There can be no assurance that the Partnership will be able to complete an accretive acquisition or otherwise find additional sources of working capital. If an acquisition transaction cannot be completed or if additional funds cannot be raised and cash flow is inadequate, the Partnership and/or Regional would be required to seek other alternatives which could include the sale of assets, closure of operations and/or protection under the U.S. bankruptcy laws.

In view of the matters described in the preceding paragraphs, recoverability of the recorded asset amounts shown in the accompanying consolidated balance sheet is dependent upon the ability of (1) Regional to achieve operating results as currently projected, (2) Regional to pay its creditors as required, including the Hopewell Loan, the IRS 2013 Installment Agreement and the VDOT amounts to be arranged, (3) the Partnership resolving favorably the exposure for late tax filing penalties for the tax year ended December 31, 2009 and non-delivery of Schedules K-1, (4) RVOP satisfactorily resolving the TransMontaigne dispute, (5) Regional satisfactorily completing the repairs associated with the Storage Tank, (6) the Partnership continuing to receive waiver of salaries and expenses by the Partnership’s executive officers until sufficient working capital is received, and (7) the Partnership’s ability to receive additional distributions from Regional or future advances from the General Partner in amounts necessary to fund overhead until an acquisition transaction is completed by the Partnership. The unaudited consolidated financial statements do not include any adjustments related to the recoverability and classification of recorded asset amounts or amounts and classification of liabilities that might be necessary should Central be unable to obtain adequate funding to maintain operations and to continue in existence.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE M — REALIZATION OF ASSETS – Continued

To provide the Partnership with the ability it believes necessary to continue in existence, management previously entered into the Sale of Partnership Common Units, received funding from the General Partner, including funds from the recently completed GP Sale, completed the Hopewell Loan and repaid the RZB Note and has resolved favorably a portion of the contingencies associated with the Partnership’s late tax filing matters. The Partnership continues taking steps to favorably resolve the remaining late tax filing matters and TransMontaigne contingencies and continues to pursue acquisition transactions. It is Management’s intention to acquire additional assets in 2013 on terms that will enable the Partnership to solidify its ability to continue as a going concern.

NOTE N - 401K

Regional sponsors a defined contribution retirement plan ( 401(k) Plan ) covering all eligible employees effective November 1, 1988. The 401(k) Plan allows eligible employees to contribute, subject to Internal Revenue Service limitations on total annual contributions, up to 60% of their compensation as defined in the 401(k) Plan, to various investment funds. Regional matches, on a discretionary basis, 50% of the first 6% of employee contributions. Furthermore, Regional may make additional contributions on a discretionary basis at the end of the Plan year for all eligible employees.

NOTE O - SEGMENT INFORMATION

Central reports segment information in accordance with ASC 280. Under ASC 280, all publicly traded companies are required to report certain information about the operating segments, products, services and geographical areas in which they operate and their major customers. Operating segments are components of a company for which separate financial information is available that is evaluated regularly by management in deciding how to allocate resources and assess performance. This information is reported on the basis that it is used internally for evaluating segment performance. Central had only one operating segment (transportation and terminaling business of Regional) during the three months ended March 31, 2012 and 2013. The following are amounts related to the transportation and terminaling business included in the accompanying consolidated financial statements for the three months ended March 31, 2012 and 2013 and at December 31, 2012 and March 31, 2013:

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE P – REGISTRATION RIGHTS AGREEMENTS

TCW Affiliate

In November 2007, an affiliate of the Partnership entered into a $30 million senior secured credit facility with TCW Asset Management Company (“ TCW ”), as agent, and TCW Energy Fund X Investors, as holders (“ TCW Credit Facility ”), in connection with the purchase of certain oil and gas properties located in Haskell, McIntosh and Pittsburg Counties, Oklahoma. The TCW Credit Facility was amended on several occasions and finally settled in May 2009 after TCW issued a “notice of event of default – demand for cure.” As a part of the settlement, the Partnership entered into a registration rights agreement with an affiliate of TCW to provide piggyback registration rights with respect to 400,000 Common Units held by the affiliate of TCW. As of November 2012, the affiliate of TCW had sold all of the 400,000 Common Units provided as part of the settlement and as a result, the piggyback registration rights with respect to the 400,000 Common Units terminated.

Penn Octane Corporation

In November 2011, the Partnership granted piggy-back registration rights to Penn Octane Corporation with respect to 197,628 Common Units held by Penn Octane in connection with the transaction whereby Penn Octane and an affiliate sold 100% of the limited liability company interests in the General Partner to Central Energy, LP and the Partnership sold 12,724,019 Common Units to Central Energy, LP (see Note A – Organization).

Limited Partners of Central Energy, LP

Effective as of August 1, 2011, the Partnership and the limited partners of Central Energy, LP executed a Registration Rights Agreement. The Registration Rights Agreement was prepared and signed by the parties as a part of the transaction consummated on November 17, 2010 pursuant to which Central Energy, LP, an affiliate of the General Partner, acquired 12,724,019 newly-issued Common Units of Central. The Registration Rights Agreement provides the limited partners of Central Energy, LP who acquired newly-issued Common Units in the November 17, 2010 transaction (“ Purchasers ”) with shelf registration rights and piggyback registration rights, with certain restrictions, for the Common Units held by them (“ Registrable Securities ”). The Partnership is required to file a “shelf registration statement” covering the Registrable Securities as soon as practicable after April 15, 2012, and maintain the shelf registration statement as “effective” with respect to the Registrable Securities until the earlier to occur of (1) all securities registered under the shelf registration statement have been distributed as contemplated in the shelf registration statement, (2) there are no Registrable Securities outstanding or (3) two years from the dated on which the shelf registration statement was first filed. The piggyback registration rights permit a Purchaser to elect to participate in an underwritten offering of the Partnership’s securities other than a registration statement filed in connection with the registration of the Partnership’s securities relating solely to (1) employee benefit plans or (2) a Rule 145 transaction. The amount of Registrable Securities that the Purchasers can offer for sale in a piggyback registration is subject to certain restrictions as set forth in the Registration Rights Agreement.

The Partnership is required to pay all costs associated with the shelf registration, any piggyback registration or an underwritten offer except for the underwriting fees, discounts and selling commission, transfer taxes (if any) applicable to the sale of the Registrable Securities, and fees and disbursements of legal counsel for any Purchaser. the Partnership is also indemnifying the Purchasers and their respective directors, officers, employees, agents, managers and underwriters, pursuant to an applicable underwriting agreement with such underwriter, from any losses, claims, damages, expenses or liabilities (1) arising from any untrue statement or alleged untrue statement of a material fact contained in the shelf registration statement or any other registration statement relating to the Registrable Securities or (2) the omission or alleged omission to state in such registration statement a material fact required to be stated therein or necessary to make the statements therein not misleading. The Registration Rights Agreement also prohibits the Partnership from entering into a similar agreement which would be inconsistent with the rights granted in the Registration Statement or provide any other holder of the Partnership’s securities rights that are more favorable than those granted to Purchasers without the prior written approval of Purchasers holding a majority of the Registrable Securities.

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE P – REGISTRATION RIGHTS AGREEMENTS - Continued

Limited Partners of Central Energy, LP – Continued

Given the current financial condition of Central, as well as the current bid/ask price of the Common Units, the Partnership does not anticipate filing the shelf registration statement for the foreseeable future. The Partnership will seek to amend the Registration Rights Agreement to extend such filing requirement to a later date.