UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 10-Q

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

	For the quarterly period ended September 30, 2013

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

	For the transition period from to

Commission file number: 000-50394

Central Energy Partners LP

(Exact Name of Registrant as Specified in Its Charter)

Delaware	20-0153267
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)

8150 N. Central Expressway, Suite 1525, Dallas, TX	75206
(Address of Principal Executive Offices)	(Zip Code)

Registrant's Telephone Number, Including Area Code: (214) 360-7480

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No ¨

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

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

Large Accelerated Filer

Accelerated Filer

Non-Accelerated Filer

Smaller Reporting
Company

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

The number of common units outstanding on November 8, 2013 was 16,066,482.

CENTRAL ENERGY PARTNERS LP AND SUBSIDIARIES

TABLE OF CONTENTS

ITEM		PAGE NO.

PART I FINANCIAL INFORMATION

1.	Financial Statements	4

	Report of Independent Registered Public Accounting Firm	4

	Consolidated Balance Sheets as of December 31, 2012 and September 30, 2013 (unaudited)	5

	Unaudited Consolidated Statements of Operations for the three months and nine months ended September 30, 2012 and 2013	6

	Unaudited Consolidated Statement of Partners’ Capital (Deficit) for the nine months ended September 30, 2013	7

	Unaudited Consolidated Statements of Cash Flows for the nine months ended September 30, 2012 and 2013	8

	Notes to Consolidated Financial Statements (unaudited)	9

2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	36

3.	Quantitative and Qualitative Disclosures About Market Risk	55

4.	Controls and Procedures	55

PART II OTHER INFORMATION

1.	Legal Proceedings	56

1A.	Risk Factors	56

2.	Unregistered Sales of Equity Securities and Use of Proceeds	56

3.	Defaults Upon Senior Securities	56

4.	Mine Safety Disclosures	56

5.	Other Information	56

6.	Exhibits	56

Signatures		69

	2

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

The statements contained in this Quarterly Report of Central Energy Partners LP (“Partnership”), that are not historical facts are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934 (“Exchange Act”). These forward-looking statements are identified as any statement that does not relate strictly to historical or current facts. Statements using words such as “may,” “could,” “should,” “expect,” “plan,” “project,” “strategy,” “forecast,” “intend,” “anticipate,” “believe,” “estimate,” “predict,” “potential,” “pursue,” “target,” “continue,” or similar expressions help identify forward-looking statements.

The forward-looking statements contained in this Quarterly Report are largely based on our expectations, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known operational and market conditions and other factors. Although we believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control. In addition, management’s assumptions about future events may prove to be inaccurate. Management cautions all readers that the forward-looking statements contained in this Quarterly Report are not guarantees of future performance, and management cannot assure any reader that such statements will be realized or the forward-looking events and circumstances will in fact occur. The Partnership’s actual results may differ materially from those anticipated, estimated, projected or expected by management. When considering forward-looking statements, please read “Item 1A. Risk Factors” and “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2012, which is incorporated by reference.

AVAILABLE INFORMATION

The Partnership is a reporting company pursuant to Section 12(g) of the Exchange Act. As a result, it files Quarterly Reports on Form 10-Q, Annual Reports on Form 10-K and Current Reports on Form 8-K, and amendments to these reports, with the SEC pursuant to Section 13(a) or 15(d) of the Exchange Act. These reports are available on the Partnership’s website at www.centralenergylp.com. These reports are also available on the SEC’s website at www.SEC.gov. In addition, the Partnership will provide copies of these reports free of charge upon request addressed to Ian T. Bothwell, Central Energy Partners LP, 8150 N. Central Expressway, Suite 1525, Dallas, Texas 75206.

The public may also read a copy of any materials filed by the Partnership with the SEC at the SEC’s Public Reference Room at 100 F Street, NE, Washington, D.C. 20549. You may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330.

All forward-looking statements speak only as of the date of this Quarterly Report. We do not intend to publicly update or revise any forward-looking statements as a result of new information, future events or otherwise.

	3

Part I – FINANCIAL INFORMATION

Item 1.

Report of Independent Registered Public Accounting Firm

To the Board of Directors of Central Energy GP LLC,

General Partner of Central Energy Partners LP and Unitholders Of Central Energy Partners LP

We have reviewed the unaudited consolidated balance sheet of Central Energy Partners LP and Subsidiaries (“Central”) as of September 30, 2013, the unaudited consolidated statements of operations for the three months and nine months ended September 30, 2012 and 2013, the unaudited consolidated statements of cash flows for the nine months ended September 30, 2012 and 2013 and the unaudited consolidated statement of partners’ capital (deficit) for the nine months ended September 30, 2013. These interim unaudited consolidated financial statements are the responsibility of Central’s management.

We conducted our review in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquires of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Oversight Board, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our review, we are not aware of any material modifications that should be made to the accompanying unaudited consolidated financial statements for them to be in conformity with United States generally accepted accounting principles.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of Central as of December 31, 2012 and the related consolidated statements of operations, cash flows and partners’ capital (deficit) for the year ended December 31, 2012 (not presented herein), and in our report dated April 1, 2013, we expressed an unqualified opinion on those consolidated financial statements.

Our audit report on Central’s consolidated financial statements as of December 31, 2012 included an explanatory paragraph referring to the matters discussed in Note L of those consolidated financial statements which raised substantial doubt about Central’s ability to continue as a going concern. As indicated in Note L to the accompanying unaudited interim consolidated financial statements, conditions continue to exist which raise substantial doubt about Central’s ability to continue as a going concern due to its insufficient cash flow to pay its current obligations and contingencies as they become due. The unaudited consolidated financial statements do not include any adjustments related to the recoverability and classification of recorded amounts that might be necessary should Central be unable to continue in existence.

/s/ MONGOMERY COSCIA GREILICH, LLP

Plano, Texas

November 14, 2013

	4

Central Energy Partners LP and Subsidiaries

CONSOLIDATED BALANCE SHEETS

ASSETS

			September 30,
	December 31,		2013
	2012		(Unaudited)
Current Assets
Cash	$	22,000	$	31,000
Trade accounts receivable (less allowance for doubtful accounts of $0 at 2012 and 2013)		647,000		362,000
Deferred tax assets		36,000		36,000
Prepaid expenses and other current assets		788,000		304,000
Total current assets		1,493,000		733,000
Property, plant and equipment – net		3,562,000		3,147,000
Other assets		125,000		128,000
Goodwill		3,941,000		3,941,000
Total assets	$	9,121,000	$	7,949,000

LIABILITIES AND PARTNERS’ CAPITAL (DEFICIT)

			September 30,
	December 31,		2013
	2012		(Unaudited)
Current Liabilities
Current maturities of long-term debt – related party	$	1,970,000	$	258,000
Accounts payable		2,295,000		1,371,000
Taxes payable		64,000		40,000
Unearned revenue		70,000		37,000
Accrued liabilities		2,227,000		1,244,000
Total current liabilities		6,626,000		2,950,000

Long-term debt - related party		-		2,242,000
Due to General Partner		1,510,000		1,955,000
Deferred income taxes		1,092,000		1,092,000

Commitments and contingencies		-		-

Partners’ capital (deficit)
Common units		(104,000)		(284,000)
General Partner’s equity		(3,000)		(6,000)
Total partners’ capital (deficit)		(107,000)		(290,000)
Total liabilities and partners’ capital (deficit)	$	9,121,000	$	7,949,000

The accompanying notes are an integral part of these consolidated financial statements.

	5

Central Energy Partners LP and Subsidiaries

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

	Three Months		Three Months		Nine Months		Nine Months
	Ended		Ended		Ended		Ended
	September 30,		September 30,		September 30,		September 30,
	2012		2013		2012		2013
Revenues	$	1,466,000	$	1,044,000	$	4,077,000	$	3,480,000
Cost of goods sold		1,294,000		838,000		3,866,000		2,946,000
Gross profit		172,000		206,000		211,000		534,000
Selling, general and administrative expenses and other
Legal and professional fees		141,000		182,000		339,000		430,000
Salaries and payroll related expenses		180,000		180,000		609,000		633,000
Other		139,000		(211,000)		442,000		(669,000)
		460,000		151,000		1,390,000		394,000
Operating income (loss)		(288,000)		55,000		(1,179,000)		140,000
Other income (expense)
Gain on sale of tractors		-		-		256,000		-
Interest expense, net		(49,000)		(106,000)		(136,000)		(272,000)
Loss before taxes		(337,000)		(51,000)		(1,059,000)		(132,000)
(Provision) for income taxes		(32,000)		(62,000)		(32,000)		(67,000)
Net loss	$	(369,000)	$	(113,000)	$	(1,091,000)	$	(199,000)

Net loss allocable to the partners	$	(369,000)	$	(113,000)	$	(1,091,000)	$	(199,000)
Less General Partner’s interest in net loss		(7,000)		(2,000)		(22,000)		(4,000)
Net loss allocable to the common units	$	(362,000)	$	(111,000)	$	(1,069,000)	$	(195,000)

Net loss per common unit	$	(0.02)	$	(0.01)	$	(0.07)	$	(0.01)

Weighted average common units outstanding		15,866,482		16,066,482		15,866,482		16,066,482

The accompanying notes are an integral part of these consolidated financial statements.

	6

Central Energy Partners LP and Subsidiaries

CONSOLIDATED STATEMENT OF PARTNERS’ CAPITAL (DEFICIT)

(Unaudited)

						Total
	Common Units			General		Partners’
	Units	Amount		Partner		Capital (Deficit)

Balance as of December 31, 2012	15,866,482	$	(104,000)	$	(3,000)	$	(107,000)

Issuance of Common Units	200,000		15,000		1,000		16,000

Net loss	-		(195,000)		(4,000)		(199,000)

Balance as of September 30, 2013	16,066,482	$	(284,000)	$	(6,000)	$	(290,000)

The accompanying notes are an integral part of these consolidated financial statements.

	7

Central Energy Partners LP and Subsidiaries

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Nine months ended		Nine months ended
	September 30,		September 30,
	2012		2013
Cash flows from operating activities:
Net loss	$	(1,091,000)	$	(199,000)
Adjustments to reconcile net loss to net cash (used in) provided by operating activities:
Depreciation and amortization		431,000		402,000
Gain of sale of tractors		(256,000)		-
Reduction in accrued tax penalties assessed		-		(1,119,000)
Unit based compensation		-		16,000
Changes in current assets and liabilities:
Trade accounts receivable		88,000		286,000
Prepaid and other current assets		537,000		479,000
Due to General Partner, net		31,000		445,000
Trade accounts payable		95,000		(924,000)
Unearned revenue		-		(33,000)
Accrued liabilities and other		569,000		126,000
U.S. taxes payable		(4,000)		(25,000)
Net cash provided by (used in) operating activities		400,000		(546,000)

Cash flows from investing activities:
Capital expenditures		(229,000)		(6,000)
Other non-current assets		(129,000)		-
Proceeds from sale of assets		507,000		31,000
Net cash provided by (used in) investing activities		149,000		25,000

Cash flows from financing activities:
Restricted cash		(2,000)		-
Issuance of related party debt		-		2,500,000
Payment of debt		(640,000)		(1,970,000)
Net cash (used in) provided by financing activities		(642,000)		530,000
Net (decrease) increase in cash		(93,000)		9,000
Cash at beginning of period		101,000		22,000
Cash at end of period	$	8,000	$	31,000

Supplemental disclosures of cash flow information:
Cash paid during the year for:
Interest	$	84,000	$	222,000
Taxes	$	36,000	$	84,000

Supplemental disclosures of noncash transactions:
Reduction in accrued tax penalties assessed	$	-	$	1,119,000

The accompanying notes are an integral part of these consolidated financial statements.

	8

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE A – ORGANIZATION

Central Energy Partners LP (“Partnership”), is a Delaware limited partnership, which was formed by Penn Octane Corporation (“Penn Octane”) on July 10, 2003. The limited partnership interests in the Partnership (“Common Units”) represent 98% of the interest in the Partnership. The General Partner is Central Energy 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 G – Partners’ Capital — Distributions of Available Cash) as provided in the Partnership’s partnership agreement (“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 (“Newly Issued 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. Central’s strategy is to acquire 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, but may include producing oil and gas properties.

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 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 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 – Rio Vista Operating Partnership L.P. (see Note G – 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”.

The unaudited consolidated balance sheet as of September 30, 2013, the unaudited consolidated statements of operations for the three months and nine months ended September 30, 2012 and 2013 and the unaudited consolidated statements of cash flows for the nine months ended September 30, 2012 and 2013 and the unaudited consolidated statement of partners’ capital (deficit) for the nine months ended September 30, 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 September 30, 2013, the unaudited consolidated results of operations for the three months and nine months ended September 30, 2012 and 2013, the unaudited consolidated statements of cash flows for the nine months ended September 30, 2012 and 2013 and the unaudited consolidated statement of partners’ capital (deficit) for the nine months ended September 30, 2013.

	9

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE A – ORGANIZATION – Continued

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 (“GP Interests”). 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. Messrs. Imad K. Anbouba and Carter R. Montgomery, each beneficially own 30.17% of the GP Interests. The Cushing LLP Opportunity Fund I, L.P. (“Cushing Fund”) holds 25% of the GP Interests and the remaining interests are held by others, none representing more than 5% individually.

On July 19, 2013, a non-affiliated third party (“Third Party”) tendered a non-binding indication of interest to the General Partner to purchase newly issued membership interests in the General Partner (“Letter”). As an indication of the Third Party’s interest in the transaction and as consideration for a “stand-still agreement” with the General Partner whereby the General Partner agreed for a period of 45 days not to solicit, encourage, entertain or accept any proposal by another third party to acquire an interest in the General Partner and/or the Partnership (“Stand-Still Period”), the Third Party delivered $100,000 to the General Partner on July 19, 2013. The cash consideration is to be repaid to the Third Party in the event a transaction is not consummated. The cash consideration is secured by a second lien on the assets of Regional. The General Partner is obligated to repay the cash consideration to the Third Party within 30 days after discussions regarding a transaction have terminated. If the consideration has not been paid by the due date, interest will immediately begin to accrue at the rate of 15% per annum. Should the General Partner fail to pay the $100,000 together with all accrued and unpaid interest by December 31, 2013, the Third Party has the right to foreclose on the assets of Regional without notice to the General Partner.

	10

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE B – PARTNERS’ CAPITAL - continued

General Partner Interest - continued

Any transaction ultimately agreed to between the parties is subject to the preparation, authorization, execution and delivery of a definitive purchase agreement, the approval of the definitive agreement by all of the members of the General Partner (as required by its company agreement), the receipt of all material consents and approvals necessary to complete such transaction, and certain other requirements set forth in the LOI. There is no assurance that the General Partner and the Third Party will reach agreement on the terms necessary to complete the definitive purchase agreement or that the members of the General Partner will approve such agreement.

Common Units

The Common Units represent limited partner interests in the Partnership and 98% of its outstanding capital. The holders of Common Units (“Unitholders”) are entitled to participate in the Partnership’s distributions and exercise the rights or privileges available to limited partners under the Partnership Agreement. The Unitholders have only limited voting rights on matters affecting the Partnership. Unitholders have no right to elect the General Partner or its directors on an annual or other continuing basis. Messrs. Anbouba and Montgomery and 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 the holders of the membership interests in the General Partner. 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 of the Partnership 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 46.1% 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 Unitholders ability to influence the manner or direction of management.

Private Placement of Common Units

On November 17, 2010, the Partnership sold the 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 (46.1%). Sanctuary Capital LLC holds 1,017,922 Common Units of the Partnership (6.3%). 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.

	11

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE B – PARTNERS’ CAPITAL - continued

Distributions of Available Cash – continued

The Partnership has not made any distributions since August 18, 2008 for the quarter ended September 30, 2008 due to the lack of available cash.

In December 2010, the General Partner and Unitholders holding more than a majority in interest of the 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, effective March 22, 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, 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 an 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 Unitholders and the General Partner 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.

	12

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE C – INCOME (Loss) Per Common UNIT

Net income (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 income (loss) per Common Unit to net income (loss) per Common Unit assuming dilution. During the three months and nine months ended September 30, 2013, Central did not have any dilutive securities outstanding (see Note F – Unit Options and Equity Incentive Plan):

	For the three months ended September 30, 2012
	(Loss)		Units	Per-Unit
	(Numerator)		(Denominator)	Amount

Net (loss) available to the Common Units	$	(362,000)
Basic EPS
Net (loss) available to the Common Units		(362,000)	15,866,482	$	(0.02)
Effect of Dilutive Securities
Options		—	—
Diluted EPS
Net (loss) available to the Common Units		N/A	N/A		N/A

	For the three months ended September 30, 2013
	Income		Units	Per-Unit
	(Numerator)		(Denominator)	Amount

Net (loss) available to the Common Units	$	(111,000)
Basic EPS
Net (loss) available to the Common Units		(111,000)	16,066,482	$	(0.01)
Effect of Dilutive Securities
Options		—	—
Diluted EPS
Net (loss) available to the Common Units		N/A	N/A		N/A

	For the nine months ended September 30, 2012
	(Loss)		Units	Per-Unit
	(Numerator)		(Denominator)	Amount

Net (loss) available to the Common Units	$	(1,069,000)
Basic EPS
Net (loss) available to the Common Units		(1,069,000)	15,866,482	$	(0.07)
Effect of Dilutive Securities
Options		—	—
Diluted EPS
Net (loss) available to the Common Units		N/A	N/A		N/A

	For the nine months ended September 30, 2013
	(Loss)		Units	Per-Unit
	(Numerator)		(Denominator)	Amount

Net (loss) available to the Common Units	$	(195,000)
Basic EPS
Net (loss) available to the Common Units		(195,000)	16,066,482	$	(0.01)
Effect of Dilutive Securities
Options		—	—
Diluted EPS
Net (loss) available to the Common Units		N/A	N/A		N/A

	13

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE D - PROPERTY, PLANT AND EQUIPMENT

	December 31,		September 30,
	2012		2013

Land	$	512,000	$	512,000
Terminal and improvements		4,818,000		4,809,000
Automotive equipment		1,341,000		1,297,000
		6,671,000		6,618,000
Less: accumulated depreciation and amortization		(3,109,000)		(3,471,000)
	$	3,562,000	$	3,147,000

Depreciation expense of property, plant and equipment totaled $134,000 and $134,000 for the three months ended September 30, 2012 and 2013 and $431,000 and $402,000 for the nine months ended September 30, 2012 and 2013, respectively.

On February 17, 2012, in connection with Regional’s Vehicle Lease Service Agreement (see Note G-Commitments and Contingencies – Penske Truck Lease), 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 G - Commitments and Contingencies – Penske Truck Lease), 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 $201,000 and $256,000 was recorded during the three months and nine months ended September 30, 2012, respectively.

Regional’s truck fleet currently consists of fifteen leased tractors and five owned tractors.

NOTE E — DEBT OBLIGATIONS

	December 31,		September 30,
	2012		2013
Long-term debt obligations were as follows:
Hopewell Note	$	-	$	2,500,000
RZB Note		1,970,000		-
		1,970,000		2,500,000
Less current portion		1,970,000		258,000
	$	-	$	2,242,000

RZB Loan

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 Loan”) from RB International Finance (USA) LLC, formerly known as RZB Finance LLC (“RZB”), dated July 26, 2007 (“Loan Agreement”). The RZB Loan was due on demand and if no demand, with a one-year maturity. In connection with the RZB Loan, 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.

	14

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE E — DEBT OBLIGATIONS - Continued

RZB Loan – continued

The RZB Loan 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 Loan 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 Loan and related collateral agreements upon execution of the Sixth Amendment. The Maturity Date of the RZB Loan 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 Loan from May 31, 2014 to March 31, 2013. Regional made the January 31, 2013 monthly amortization payment but failed to make the February 28, 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.

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, 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, RZB provided Regional with a payoff letter and released all of the collateral previously held as security. The interest rate related to the RZB Loan for the period January 1, 2013 through March 20, 2013 approximated 9.5%.

Hopewell Loan

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 up to $2,500,000 (“Hopewell Loan”), of which $1,998,000 was advanced on such date and an additional $252,000 and $250,000 was advanced on March 26, 2013 and July 19, 2013, respectively. 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.

	15

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE E — DEBT OBLIGATIONS - Continued

Hopewell Loan - continued

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, 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.

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.

Should a definitive purchase agreement not be executed and a transaction completed pursuant to the LOI with the Third Party described in Note B, the Third Party Advance with all accrued and unpaid interest is due and payable by December 31, 2013 to the Third Party. Should the General Partner fail to pay the required amounts, the Third Party has the right to foreclose on the assets of Regional without notice to the General Partner or Hopewell.

NOTE F – UNIT OPTIONS AND EQUITY INCENTIVE PLAN

The Partnership has no employees and is managed by its General Partner.

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 and nine months ended September 30, 2012 and 2013 under the fair-value provisions of ASC 505.

	16

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE F – UNIT OPTIONS AND EQUITY INCENTIVE PLAN – continued

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 recorded unit-based compensation of $16,000 during the nine months ended September 30, 2013 in connection with the issuance of the 200,000 Common Units. Central did not record any unit-based compensation for employees for the three months and nine months ended September 30, 2012 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 delegated to 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 Vice President, Chief Financial Officer and Secretary of the General Partner and President of Regional (“Executive”) (see Note J– Commitments and Contingencies – Employment Agreement). Under the terms of the Agreement, the Executive was granted 200,000 Common Units of the Partnership under the 2005 Plan which vested immediately upon such grant as set forth in a separate Unit Grant Agreement between the Executive and the General Partner.

	17

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE F — 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 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 results from a Change in Control of the General Partner, or (d) a termination results from the Death or Disability of the Executive as more fully described in the Agreement.

At September 30, 2013, there were no options outstanding under the 2005 Plan. At September 30, 2013, approximately 422,310 Common Units remain available for issuance under the 2005 Plan.

NOTE G - 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.

	18

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE G - COMMITMENTS AND CONTINGENCIES - Continued

Legal Proceedings – continued

VOSH Actions - continued

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 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.

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 Razorback L.L.C. (“Razorback”) and 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 Razorback and RVOP provided for working capital adjustments and indemnification under certain circumstances.

In connection with previous demands for indemnification by Razorback received by RVOP under the Purchase and Sale Agreement, RVOP and certain of its affiliated parties (“Seller Affiliates”) and Razorback and certain of its affiliated parties (“Buyer Affiliates”) executed a Compromise Settlement Agreement and General Release (“Settlement Agreement”) effective as of October 14, 2013. Under the terms of the Settlement Agreement, not later than 60 days after the execution of the Settlement Agreement (December 9, 2013), RVOP or Seller’s Affiliates will pay the amount of $125,000 to Razorback in full satisfaction of all claims asserted by Razorback or Buyer Affiliates against RVOP or Seller Affiliates as of the date of the Settlement Agreement or any future claims that may be asserted by Razorback or any of the Buyer Affiliates against RVOP or any of the Seller’s Affiliates other than the claim asserted against Razorback by Cardenas Development Co. (“Cardenas Claim”). RVOP remains responsible for any Losses (as defined in the Settlement Agreement) resulting from the Cardenas Claim in an amount not to exceed $50,000 (“Contingent Payment”). In connection with the Settlement Agreement, each of the parties released each other from any other future claims that may arise as a result of the Purchase and Sale Agreement (except for the Contingent Payment). At September 30, 2013, RVOP had accrued a reserve of approximately $283,000 for potential future obligations in connection with the Purchase and Sale Agreement. During the fourth quarter 2013, RVOP will record a gain of $108,000 representing the reduction of RVOP’s maximum exposure under the Settlement Agreement of $175,000 and the amounts recorded.

	19

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE G - COMMITMENTS AND CONTINGENCIES - Continued

Legal Proceedings – continued

SGR Energy LLC

On July 1, 2013, Regional filed suit in the United States District Court for the Eastern District of Virginia, “Regional Enterprises, Inc. v. SGR Energy, LLC, Civil Action No. 3:13v418” (“Litigation”) in connection with SGR Energy, LLC’s (“SGR”) failure to make the required payments due to Regional under the terms of a services agreement between the parties pursuant to which Regional stores and transports product (“Product”). In connection with the Litigation, Regional was seeking payment of all amounts owing under the services agreement including the costs associated with removal of the Product stored at Regional’s facilities and the cleanup of the facilities as provided for under the terms of the services agreement.

On August 16, 2013, SGR filed an answer and counterclaim to the Litigation (“Counterclaim”), which denied certain claims made by Regional in the Litigation and made counter claims against Regional including, breach of contract and tortious interference with contract. SGR was seeking actual and compensatory damages.

On August 20, 2013, Regional and SGR entered into a Settlement and Mutual Release agreement (“Settlement Agreement”). Under the terms of the Settlement Agreement, SGR agreed to make payments to Regional of all past due amounts in exchange for Regional agreeing to release the Product from storage. SGR also agreed to place proceeds to be received from the sale of the Product in the amount of $290,000 (“Escrow Amount”) into an escrow account (“Escrow”) to be distributed by an escrow agent (“Escrow Agent”) in accordance with the Settlement Agreement.

The Escrow Amount was to be used to secure SGR’s obligation to clean and vacate the tank by October 1, 2013 and the payment of the minimum rents as prescribed under the services agreement, which provide for rents to continue until the time that SGR has satisfactorily completed the cleanup of the facilities and vacated the tank. In connection with the Settlement Agreement, SGR and Regional agreed to dismiss the Litigation and Counterclaim without prejudice by agreed stipulation. SGR did not make all of the payments required and did not clean and vacate the tank as prescribed under the Settlement Agreement and the Escrow Agent did not distribute the Escrow Amount to Regional as prescribed under the Settlement Agreement.

On October 15, 2013, Regional, SGR and the Escrow Agent entered into a final settlement and mutual release agreement (“Final Release”) whereby the parties agreed that Regional would receive $250,000 of the Escrow Amount and SGR would receive $40,000 of the Escrow Amount. In addition, Regional agreed to be responsible for cleaning the tank, although SGR agreed that it would accept responsibility as the generator of any wastes which were collected and disposed of in connection with the cleaning of the facilities and the services agreement was terminated. Under the terms of the Final Release, all parties provided full releases to each other. The Escrow Amount received by Regional was sufficient to cover all the costs required to complete the cleaning of the tank, all amounts owing from SGR as of the date of the Final Release, and to pay the costs of litigation which Regional incurred in connection with the aforementioned litigation.

Other

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.

	20

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE G - COMMITMENTS AND CONTINGENCIES - Continued

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.

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.

	21

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE G - COMMITMENTS AND CONTINGENCIES - Continued

Agreements - continued

Penske Truck Lease - continued

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. On May 31, 2013, Regional notified Penske of its intent to terminate the lease arrangement effective June 15, 2013, for five tractors as provided for in the Lease Agreement as a result of the decline in Regional’s transportation business. As a result of this partial termination, Regional now leases fifteen tractors pursuant to the Lease Agreement. 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.

Tank Storage and Terminal Services Agreements

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 has been renewed automatically for successive one-year terms through November 30, 2013. During July 2013, Regional provided written notice in accordance with the Asphalt Agreement that it did not intend to renew the Asphalt Agreement under the existing terms.

	22

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE G - COMMITMENTS AND CONTINGENCIES - Continued

Agreements - continued

Tank Storage and Terminal Services Agreements - continued

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 and $225,000 for the three months and nine months ended September 30, 2013. The repairs of the Storage Tank were completed and the tank became operational during November 2013. Regional’s insurance providers have notified Regional that the incident did not fall within insurance coverage limits.

On October 31, 2013, Regional and a new customer entered into an agreement with an effective date of December 1, 2013 (“New Asphalt Agreement”) which 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. In connection with the New Asphalt Agreement, Regional will be required to fund during the first nine months of the New Asphalt Agreement up to $465,000 for refurbishments of certain assets currently idle and modifications to the existing facilities to provide for greater efficiencies and extended logistical capabilities. The term of the New Asphalt Agreement is four years and automatically extends for additional 2-year periods unless either party provides 180 days written notice to cancel. During the term of the New Asphalt Agreement, Regional agrees to provide up to five storage tanks and certain related equipment, including rail siding, to the customer on an exclusive basis as well as access to Regional’s barge docking facility.

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. Under the terms of the Terminal Agreement, the customer paid an annual tank rental 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 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. The parties are currently negotiating an extension to the Fuel Oil Agreement.

	23

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE G — COMMITMENTS AND CONTINGENCIES – Continued

Agreements - continued

Tank Storage and Terminal Services Agreements - continued

On September 27, 2007, Regional entered into a terminal agreement with a customer with an effective date of June 1, 2008 and an expiration date of May 30, 2013 (“Hydroxide Agreement”). The Hydroxide Agreement provided 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. On May 21, 2013, the Hydroxide Agreement was extended to August 31, 2013. On July 11, 2013, the parties entered into a new terminal agreement effective June 28, 2013 and an expiration date of June 27, 2016, subject to being automatically renewed in one-year increments unless terminated upon 120 days advance written notice by either party (“New Hydroxide Agreement”). Under the terms of the New Hydroxide Agreement, either party may cancel the agreement at any time by providing 120 days advance written notice after the one year anniversary of the effective date. Pursuant to the New Hydroxide Agreement, Regional agrees to provide two storage tanks, certain related pipelines and equipment, 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 fixed tank rental fee and variable fees based on excess of certain minimum levels of thru-put, plus a product transportation fee calculated on a per run basis, each subject to annual adjustment for inflation. Regional also contracts with this customer to provide other transportation and trans-loading services of specialty chemicals.

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 (“SGR Agreement”). The SGR Agreement provided for the pricing, terms, and conditions under which Regional would provide terminal facilities and services to the customer for the receipt, storage and distribution of No. 6 oil. Pursuant to the SGR Agreement, Regional provided one storage tank, 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 paid an annual tank rental amount, plus loading and unloading fees. As part of the lease, Regional insulated the tank and made other modifications to the tank and barge line. During October 2013, the SGR Agreement was terminated (see Note G – Legal Proceedings – SGR Energy LLC).

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 (“Asphalt Additive Agreement”). The customer has the sole discretion to extend the term of the Asphalt Additive 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 Asphalt Additive Agreement. The Asphalt Additive 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 an asphalt additive. Pursuant to the agreement, Regional agrees to provide one storage tank, 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, plus loading and unloading fees.

During November 2013, Regional entered into a services agreement with a customer with an effective date of November 1, 2013 and a termination date of April 30, 2014 (“Second Asphalt Additive Agreement”). The Second Asphalt Additive Agreement automatically renews for 90 days unless either party provides 60 days written notice to terminate prior to expiration. The Second Asphalt Additive 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 an asphalt additive. Pursuant to the agreement, Regional agrees to provide one storage tank, 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, plus loading and unloading fees. In connection with the Second Asphalt Additive Agreement, Regional has the right of first refusal to provide trucking services to the customer, provided Regional’s rates are competitive.

	24

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE G — COMMITMENTS AND CONTINGENCIES – Continued

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:

	⋅	the term of employment is for a period of two years unless terminated as more fully described in the Agreement; provided, that on the second anniversary and each annual anniversary thereafter, the Agreement shall be deemed to be automatically extended, upon the same terms and conditions, for successive periods of one year, unless either party provides written notice of its intention not to extend the term of the Agreement at least 90 days’ prior to the applicable renewal date;

	⋅	the Executive will serve as Executive Vice President, Chief Financial Officer and Secretary of the General Partner and President of Regional;

	⋅	the Executive will receive an annual salary of $275,000 (“Base Salary”) which may be adjusted from time to time as determined by the Board of Directors of the General Partner (as more fully described in the Agreement, Regional will pay a minimum of 75% of the Base Salary);

	⋅	for each calendar year of the employment term, the Executive shall be eligible to receive a bonus to be determined by the General Partner’s Board of Directors in its sole and absolute discretion;

	⋅	the Executive shall be entitled to five weeks of paid vacation during each 12-month period of employment beginning upon the effective date of the Agreement;

	⋅	the Executive will be entitled to other customary benefits including participation in pension plans, health benefit plans and other compensation plans as provided by the General Partner;

	⋅	the Agreement terminates (a) upon death, (b) at any time upon notice from the General Partner for cause as more fully defined in the Agreement, (c) by the General Partner, without cause, upon 15 days advance notice to the Executive, or (d) by the Executive at any time for Good Reason (as more fully defined in the Agreement) or (e) by Executive without Good Reason (as more fully defined in the Agreement) upon 15 days advance notice to the General Partner;

	⋅	the Executive will be granted 200,000 Common Units of the Partnership under the General Partner’s 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. All of the terms and conditions of such grant shall be governed by the terms and conditions of the 2005 Plan and the Unit Grant Agreement; and

	⋅	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 Partnership’s benefit plans, the General Partner shall provide to the Executive one or more future grants of Common Units of the Partnership 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 this 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.

	25

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE G — COMMITMENTS AND CONTINGENCIES – Continued

Agreements - 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.

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 Mr. 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.

	26

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE G — COMMITMENTS AND CONTINGENCIES – Continued

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 the Partnership is required to take into account that Unitholder’s share of items of income, gain, loss and deduction of the 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. 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, No. 6 Oil and/or asphalt additives 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 and ships) 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.

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.

	27

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE G — COMMITMENTS AND CONTINGENCIES – Continued

Partnership Tax Treatment - continued

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 H – MAJOR CUSTOMERS AND CONCENTRATIONS OF CREDIT RISK

Major Customers

For the three months ended September 30, 2013, Suffolk Sales, MeadWestvaco, and SGR Energy LLC accounted for approximately 32%, 18%, and 11% of Regional’s revenues, respectively. For the nine months ended September 30, 2013, Suffolk Sales, SGR Energy LLC, and MeadWestvaco accounted for approximately 22%, 16%, and 15% of Regional’s revenues, respectively. At September 30, 2013, Suffolk Sales, MeadWestvaco, and SGR Energy LLC accounted for approximately 51%, 14%, and 12% of Regional’s accounts receivable, respectively.

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 September 30, 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.

NOTE I — INCOME TAXES

Federal Tax Liabilities – Regional

As of September 30, 2013, Regional has accrued $0 and $8,000 for federal income taxes and associated penalties and interest, respectively.

On February 18, 2013, in response to the IRS’s demand for $160,000 of past due income taxes for the tax year December 2011 and $55,000 of penalties and interest owed by Regional for the tax years ended December 2008 and December 2011, Regional requested from the IRS an installment agreement arrangement (the “IRS 2013 Installment Agreement”). During June 2013, Regional filed its 2012 federal income tax return and filed forms to request a refund of $160,000 of income taxes as a result of the carryback of losses incurred during the 2012 tax year which effectively eliminated the $160,000 of taxes associated with the December 31, 2011 tax return. Regional has received verbal confirmation from the IRS that the recently filed tax returns and application for refund have been processed and such amounts have been offset against the amounts reflected as owing to the IRS described above.

	28

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE I — INCOME TAXES - Continued

State Tax Liabilities - Regional

As of September 30, 2013, Regional has accrued $40,000 and $23,000 for Virginia state income taxes and sales and use taxes and associated penalties and interest, respectively. The Commonwealth of Virginia, Department of Taxation (“VDOT”) had previously notified Regional that approximately $62,000 and $63,000 of income tax, penalties and interest related to the tax periods ended October 2006 and July 2007, respectively, were outstanding (“2006 and 2007 Taxes”) and $42,000 of income tax, penalties and interest related to the tax year ended December 31, 2011 (“2011 Taxes”) were also outstanding. During June 2013, Regional made arrangements with the VDOT to pay the 2011 Taxes due in installments of $6,500 per month until such amounts have been fully paid. The VDOT had also included approximately $31,000 of sales taxes as part of this payment arrangement. During June 2013, Regional filed its 2012 Virginia state income tax return and filed forms to request a refund of $29,000 of state income taxes as a result of the carryback of losses incurred during the 2012 tax year which effectively eliminated the $29,000 of taxes associated with the 2011 Taxes. The VDOT has informed Regional that the payment amounts owed in connection with the 2011 Taxes will be offset by the refund request referred to above and associated penalties and interest will be removed. During September 2013, Regional received confirmation that the 2006 and 2007 Taxes were reduced to $40,000. Regional intends to have the amounts owed in connection with the 2006 and 2007 Taxes included in the payment arrangement for the 2011 Taxes. During the nine months ended September 30, 2013, Regional has recorded state income tax expense of $67,000.

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 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 also filed all of the previously delinquent required state partnership tax returns for the years ended December 31, 2008 and 2009 during 2011. The Internal Revenue Code of 1986, as amended (“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. 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. On January 11, 2013, the Partnership submitted its appeal of the Notice. On February 8, 2013 and June 10, 2013, the Partnership received notice from the IRS that its request to remove the 2008 and 2009 penalties, respectively, was granted.

	29

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE I — INCOME TAXES - Continued

Tax Liabilities – continued

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

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.

During May 2013, the Partnership received a notice from the State of California Franchise Tax Board (“CAFTB”) that indicated the Partnership was liable for late filing penalties of approximately $316,000 (“CA Penalties”) in connection with the short tax year return (“Short Tax Year Return”) filed for the period January 1, 2011 through May 26, 2011 as a result of a technical termination that occurred under Section 708(b) of the Code. The Partnership had previously been granted an extension by the IRS to file the federal Short Year Tax Return to the time that the Partnership’s 2011 federal tax return would have been due had a technical termination not occurred. The Partnership filed a request with the CAFTB to have the penalties removed based on the similar hardship which the IRS had considered in granting the Partnership its extension for filing the federal Short Year Tax Return. During September 2013, the Partnership received confirmation from the CAFTB that the CA Penalties were removed.

Included in selling, general, administrative expenses and other during the nine months ended September 30, 2013, the Partnership has recorded a reduction of tax penalties of $1,119,000 in connection with the removal of the prior accrual of penalties associated with 2009 partnership federal tax return.

The Partnership had timely applied for an automatic extension to file its 2012 federal and state income tax returns and Schedule K-1’s and delivered the 2012 tax returns and Schedules K-1 to its Unitholders by the required extensions due date of September 15, 2013.

NOTE J — 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 nine months ended September 30, 2012 and 2013, Regional had no environmental contingencies requiring specific disclosure or the recording of a liability.

NOTE K — 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.

	30

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE K — RELATED PARTY TRANSACTIONS - Continued

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 June 30, 2013, $434,000 and $73,000, 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 Central, including the payment of certain outstanding obligations.

In connection with the Third Party Advance (see note B – General Partner Interest), $358,000 was used by the General Partner during the three months ended September 30, 2013 to fund working capital requirements of Central, 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 September 1, 2013 is 1.64% per annum and such rate is adjusted monthly by the IRS under IRB 625. At September 30, 2013, the total amount owed to the General Partner by the Partnership, including accrued interest, was $1,955,000.

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 September 30, 2013 is $4,046,000. The payment of this amount is subordinated to the 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 and nine months ended September 30, 2012 and 2013, Regional recorded allocable expenses of $36,000, $64,000, $224,000 and $177,000, respectively.

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CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE K — 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 September 30, 2013, the intercompany balance owed by Regional to the Partnership and/or RVOP is approximately $1,914,000, 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.

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 Rover Technologies LLC since September 2011 for its share of the overhead costs. Management intends to satisfy the outstanding expense reimbursements upon completion of a recapitalization. For the three months and nine months ended September 30, 2012 and 2013, expenses billed in connection with both of these agreements were $25,000, $12,000, $76,000 and $42,000, respectively.

NOTE L — 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 nine months ended September 30, 2013. During March 2013, the RZB Loan ($1,970,000 at December 31, 2012) was repaid with proceeds from the $2,500,000 of total advances received by Regional under the Hopewell Loan.

Central’s deficit in working capital, excluding the current amounts due under the Hopewell Loan, totaled $1,958,000 at September 30, 2013. If a definitive transaction with the Third Party is not completed, the General Partner is obligated to repay the Third Party Advance of $400,000, plus interest, by December 31, 2013 or the Third Party will have the right to foreclose on the assets of Regional without notice to the General Partner. In connection with the New Asphalt Agreement, Regional is required to fund up to $465,000 during the next three to nine months for refurbishments and modifications to the facility. The Partnership and the General Partner have limited cash resources and are dependent on Regional to fund ongoing corporate expenses.

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CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE L — REALIZATION OF ASSETS – Continued

Substantially all of Central’s assets are pledged or committed to be pledged as collateral for the Hopewell Loan, and therefore, Central is unable to obtain additional financing collateralized by those assets. Central believes that Regional will have sufficient working capital for its ongoing operations assuming (a) the expected increase in revenues from recent contracts entered into by Regional are realized, (b) the remaining expiring contract during 2013 at Regional is renewed without disruption in service and at terms no less favorable than the existing contract terms, (c) that Regional’s obligations to creditors are not accelerated, and (d) that Regional’s costs to operate do not increase. If the aforementioned conditions are not achieved, Regional’s working capital may not be adequate to meet current cash requirements and Regional will be unable to fund any amount of working capital to Central.

Central’s ability to raise capital is hindered by the existing pledge and therefore the ability to obtain additional capital over the cash generated from operations to make the Hopewell Note payments, for payment of income taxes, for expansion, capital improvements to existing assets, for working capital or otherwise is limited. 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 its ongoing cash requirements or 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, (3) the General Partner completing the transaction contemplated under the LOI with the Third Party or if not completed, the ability to repay the Third Party Advance as required, (4) RVOP satisfactorily making the required payment in connection with the Settlement Agreement with TransMontaigne, (5) the Partnership continuing to receive waiver of salaries and expenses by the Partnership’s executive officers until sufficient working capital is received, (6) Regional’s ability to fund the capital improvements required under the New Asphalt Agreement, (7) Regional’s ability to obtain additional advances under the Hopewell Loan, and (8) 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.

Regional is currently seeking to obtain additional funding through an increase in the amounts advanced under the Hopewell Loan or from a funding transaction completed by the Partnership and/or the General Partner. 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.

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CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE M - 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 N - 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 and nine months ended September 30, 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 and nine months ended September 30, 2012 and 2013 and at December 31, 2012 and September 30, 2013:

	Three months		Three months		Nine months		Nine months
	ended		ended		ended		ended
	September 30,		September 30,		September 30,		September 30,
	2012		2013		2012		2013

Revenue from external customers	$	1,466,000	$	1,044,000	$	4,077,000	$	3,480,000
Interest expense	$	49,000	$	99,000	$	136,000	$	257,000
Depreciation and amortization	$	134,000	$	134,000	$	431,000	$	402,000
Income tax expense	$	32,000	$	62,000	$	32,000	$	67,000
Net (loss)	$	(177,000)	$	(256,000)	$	(516,000)	$	(879,000)

	December 31,		September 30,
	2012		2013
Total assets	$	8,927,000	$	7,911,000

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CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE O – REGISTRATION RIGHTS AGREEMENTS

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 the Partnership. 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.

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.

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

Central Energy Partners LP (Partnership) and its consolidated subsidiaries, including Regional Enterprises, Inc. (Regional) are collectively hereinafter referred to as “Central”.

The following discussion of Central's liquidity and capital resources should be read in conjunction with the unaudited consolidated financial statements of Central and related notes thereto appearing elsewhere herein.

Current Assets and Operations

Regional

On July 27 2007, the Partnership acquired the business of Regional Enterprises, Inc., a Virginia corporation. Regional has provided liquid bulk storage, transportation and railcar trans-loading of bulk liquids, including hazardous chemicals and petroleum products, to its customers for over 40 years.

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 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 operated a trans-loading facility in Johnson City, Tennessee, with 6 rail car slots which it was forced to shut-down effective March 31, 2013 as a result of the decision by Regional’s sole customer for this facility not to renew its agreement (which expired on March 31, 2013) as a result of the shut-down of a nearby processing plant for which that customer was supplying product out of the Johnson City site. Regional also provides transportation services to customers for products which don’t originate at any of Regional’s terminal facilities. Certain customers for whom Regional provides storage services also use its transportation services. The hazardous materials and petroleum products stored, trans-loaded and transported by Regional are owned by its customers at all times.

Regional’s revenues for the three months and nine months ended September 30, 2012 and 2013 were divided as set forth below. All dollar amounts are in thousands.

	Three Months Ended								Nine months ended
	September 30, 2012				September 30, 2013				September 30, 2012				September 30, 2013
	Revenue		%		Revenue		%		Revenue		%		Revenue		%

Hauling	$	981	67	%	$	499	48	%	$	2,618	64	%	$	1,841	53	%
Storage		336	23	%		446	43	%		1,017	25	%		1,329	38	%
Terminal		149	10	%		95	9	%		442	11	%		294	9	%
Other		-	0	%		2	0	%		-	0	%		2	0	%
Total	$	1,466	100	%	$	1,042	100	%	$	4,077	100	%	$	3,466	100	%

Recent Developments

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 dated May 25, 2010, as amended. At closing, the Partnership sold 12,724,019 newly issued Common Units (“Newly Issued Common Units”) to Central Energy, LP for $3,950,000 and Penn Octane and an affiliate sold 100% of the limited liability company interests in the General Partner to Central Energy, LP for $150,000 (“Sale”). As a result of the completion of the Sale, all control in the General Partner was transferred to Central Energy, LP, the Newly Issued Common Units were sold to Central Energy, LP, and Messrs. Imad K. Anbouba and Carter R. Montgomery, each of which owns 50% of the issued and outstanding limited liability company interests of Central Energy, LLC, the general partner of Central Energy, LP, became the sole managers of the General Partner.

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Central Energy, LP was obligated under the terms of its limited partnership agreement to distribute the Newly Issued Common Units of the Partnership and the GP Interests which it acquired in the Sale to its partners. During May 2011 and September 2011, Central Energy, LP completed the distribution of the Newly Issued Common Units and the GP Interests, respectively, to its partners. As a result, Central Energy, LP no longer holds any Common Units of the Partnership or GP Interests. Of the Newly Issued Common Units, The Cushing MLP Opportunity Fund I, L.P., a Delaware limited partnership (the “Cushing Fund”), holds 7,413,013 Common Units of the Partnership (46.1%), and Sanctuary Capital LLC, a limited liability company, holds 1,017,922 Common Units of the Partnership (6.3%). Neither of Messrs. Anbouba or Montgomery received any Common Units in the distribution of the Newly Issued Common Units. Messrs. Imad K. Anbouba and Carter R. Montgomery, each beneficially own 30.17% of the GP Interests. The Cushing LLP Opportunity Fund I, L.P. (“Cushing Fund”) holds 25% of the GP Interests and the remaining GP Interests are held by others, none representing more than 5% individually.

The ownership of the Partnership and General Partner changed on November 17, 2010, and since that date the General Partner’s new management has regained and has maintained compliance with the Partnership’s securities and tax reporting obligations. As a result, the Partnership is considered “current” with respect to its reporting obligations under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), and is able to utilize Regulation S and Forms S-3 and S-8 for the future sale and registration of its securities, and Unitholders will be able to sell Common Units in compliance with Rule 144.

Beginning in the second half of 2011, after regaining compliance with its tax and financial reporting obligations, management’s focus turned to expanding the asset base of the Partnership. The General Partner identified a number of potential acquisition opportunities, made indicative offers to purchase six different midstream assets and entered into significant discussions for the purchase of three of such assets. Several of these opportunities were the subject of an auction process in which the General Partner was not the successful bidder as the result of more aggressive bids being placed by other entities. In each case, management of the General Partner believed that the successful bids exceeded the value of the assets.

Management continues to focus on the future growth of Central’s assets, and related cash generation, through acquisitions. Our primary business objectives are to maintain stable cash flows and to again make quarterly cash distributions on our Common Units. Our plan is to pursue accretive acquisitions of oil and gas assets that can expand our operations. Our acquisition activity is focused on gas transportation and services assets, such as gas gathering, dehydration and compression systems, pipelines, fractionation and condensate stabilization facilities, and related assets, but may include producing oil and gas properties. Our acquisitions will be made through subsidiaries of the Partnership created to acquire identified entities or assets. We will use available resources of Central, proceeds from the issuance by Central of Common Units or new securities, or any combination thereof, and/or third-party debt to fund such acquisitions.

Results of Operations

The unaudited consolidated results of operations from continuing operations during the three months and nine months ended September 30, 2012 and 2013, reflect the results associated with Regional’s storage, trans-loading and transportation business of refined petroleum and petrochemical products and all indirect income and expenses of the Partnership.

Three months ended September 30, 2013 and 2012 (all amounts in thousands)

													Change Three Months Ended
	Three Months Ended						Three Months Ended						September 30, 2013 versus
	September 30, 2013						September 30, 2012						September 30, 2012
	Regional		Corporate		Total		Regional		Corporate		Total		Regional		Corporate		Total

Revenues	$	1,044	$	-	$	1,044	$	1,466	$	-	$	1,466	$	(422)	$	-	$	(422)
Costs Of Goods Sold		838		-		838		1,294		-		1,294		(456)		-		(456)
Gross Profit		206		-		206		172		-		172		34		-		34
Selling, General and Administrative Expenses		300		(149)		151		268		192		460		32		(340)		(308)
Operating Income (Loss)		(94)		149		55		(96)		(192)		(287)		2		340		342
Interest Expense, net		(99)		(7)		(106)		(49)		-		(49)		(50)		(7)		(57)
Gain On Sale Of Tractors		-		-		-		-		-		-		-		-		-
Income (Loss) Before Taxes		(193)		142		(51)		(145)		(191)		(336)		(48)		334		285
Provision (Benefit) For Income Taxes		62		-		62		32		-		32		30		-		30
Net Income (Loss)	$	(256)	$	142	$	(113)	$	(177)	$	(191)	$	(369)	$	(78)	$	334	$	255

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Revenues. Regional’s revenues for the three months ended September 30, 2013 were $1.0 million compared with $1.5 million for the three months ended September 30, 2012, a decrease of $0.4 million (28.8%). The decrease in revenues during the three months ended September 30, 2013 was principally due to decreased terminal services revenues resulting from the two tank customers which did not have thru-put of product during the period and the reduction of terminal and hauling revenues due to the closure of the Johnson City, TN facility. In addition, hauling revenues also declined during the three months ended September 30, 2013 due to increased competition. The aforementioned reduction in revenues was partially offset from the rental of a storage tank during the three months ended September 30, 2013 which was idle during the same period one year earlier.

Cost of Goods Sold. Regional’s cost of goods sold for the three months ended September 30, 2013 were $0.8 million compared with $1.3 million for the three months ended September 30, 2012, a decrease of $0.5 million (35.2%). The cost of goods sold during the three months ended September 30, 2012 included higher costs associated with the Asphalt Loss and maintenance of tractors and terminal assets over the three months ended September 30, 2013. Costs of goods sold related to storage and terminal services did not increase despite the increase in related revenues as the storage and terminal business has mostly fixed costs to operate. The reduction in cost of goods sold was also attributable to the reduced hauling revenues during the three months ended September 30, 2013 compared with September 30, 2012.

Selling, General and Administrative Expenses. Selling, general and administrative expenses (SG&A) for Regional during the three months ended September 30, 2013 were 12% higher ($0.03 million) compared to the three months ended September 30, 2012. The increase was the result of higher professional fees incurred in connection with additional financing under the Hopewell Loan, litigation costs and compliance costs, partially offset by reduction of penalties and interest as a result of the abatement of penalties during the three months ended September 30, 2013 compared with the three months ended September 30, 2012.

The decrease in SG&A expenses for Central of $0.3 million during the three months ended September 30, 2013 compared with the same period one year earlier was principally due to the reduction of CAFTB tax penalties assessed as a result of the abatement of penalties totaling $0.3 million during the three months ended September 30, 2013, decreased professional fees incurred at the Central and increased allocations of insurance related costs to Regional during the three months ended September 30, 2013.

Nine months ended September 30, 2013 and 2012 (all amounts in thousands)

													Change Nine Months Ended
	Nine Months Ended						Nine Months Ended						September 30, 2013 versus
	September 30, 2013						September 30, 2012						September 30, 2012
	Regional		Corporate		Total		Regional		Corporate		Total		Regional		Corporate		Total
Revenues	$	3,480	$	-	$	3,480	$	4,077	$	-	$	4,077	$	(597)	$	-	$	(597)
Costs Of Goods Sold		2,946		-		2,946		3,866		-		3,866		(920)		-		(920)
Gross Profit		534		-		534		210		-		210		323		-		323
Selling, General and Administrative Expenses		1,088		(694)		394		813		575		1,389		275		(1,269)		(994)
Operating Income (Loss)		(555)		694		139		(603)		(575)		(1,178)		48		1,269		1,318
Interest Expense, net		(257)		(15)		(272)		(136)		-		(136)		(121)		(15)		(136)
Gain On Sale Of Tractors		-		-		-		256		-		256		(256)		-		(256)
Income (Loss) Before Taxes		(812)		679		(133)		(484)		(575)		(1,059)		(328)		1,254		926
Provision (Benefit) For Income Taxes		67		-		67		32		-		32		35		-		35
Net Income (Loss)	$	(879)	$	679	$	(200)	$	(516)	$	(575)	$	(1,091)	$	(363)	$	1,254	$	892

Revenues. Regional’s revenues for the nine months ended September 30, 2013 were $3.5 million compared with $4.1 million for the nine months ended September 30, 2012, a decrease of $0.6 million (14.6%). The decrease in revenues during the nine months ended September 30, 2013 was principally due to decreased terminal services revenues resulting from the two tank customers which did not have thru-put of product during the period April 2013 thru September 2013 and the reduction of terminal and hauling revenues due to the closure of the Johnson City, TN facility and the Storage Tank which was taken out of service in April 2012 and was not put back into service until November 2013. In addition, hauling revenues also declined during the nine months ended September 30, 2013 due to increased competition, the reduction in available drivers and the closure of certain customer facilities for maintenance. The aforementioned reduction in revenues was partially offset from the net increase in storage tank revenues during the nine months ended September 30, 2013 resulting from a storage tank fully utilized during the nine months ended September 30, 2013 although the same tank was idle throughout the nine months ended September 30, 2012.

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Cost of Goods Sold. Regional’s cost of goods sold for the nine months ended September 30, 2013 were $2.9 million compared with $3.9 million for the nine months ended September 30, 2012, a decrease of $0.9 million (23.8%). The cost of goods sold during the nine months ended September 30, 2012 included higher costs associated with the Asphalt Loss and maintenance of tractors and terminal assets over the nine months ended September 30, 2013. Costs of goods sold related to storage and terminal services did not increase despite the increase in related revenues as the storage and terminal business has mostly fixed costs to operate. The reduction in cost of goods sold was also attributable to the reduced hauling revenues during the nine months ended September 30, 2013 compared with September 30, 2012 partially offset from increased prices paid for fuel and the fixed cost portion of the newly entered Penske Truck Lease which was entered into in June 2012.

Selling, General and Administrative Expenses. Selling, general and administrative expenses (SG&A) for Regional during the nine months ended September 30, 2013 were $1.1 million compared with $0.8 million for the nine months ended September 30, 2012. The increase was the result of higher professional fees incurred in connection with the closing and subsequent financings under the Hopewell Loan, litigation costs and compliance costs, partially offset by reduction of penalties and interest as a result of the abatement of penalties during the nine months ended September 30, 2013 compared with the nine months ended September 30, 2012.

The decrease in SG&A expenses for Central of $1.3 million during the nine months ended September 30, 2013 compared with the same period one year earlier was principally due to the reduction of tax penalties assessed as a result of the abatement of penalties totaling $1.1 million during the nine months ended September 30, 2013, decreased professional fees incurred at the Central and increased allocations of insurance related costs to Regional during the nine months ended September 30, 2013.

Liquidity and Capital Resources

Management’s primary focus during the first half of 2011 was complying with obligations under federal and state law regarding a number of obligations that the Partnership and Regional had failed to meet due to its previous lack of working capital. During the second half of 2011 and all of 2012, after regaining compliance with its tax and financial reporting obligations, management’s focus turned to expanding the asset base of the Partnership. The General Partner identified a number of potential acquisition opportunities, made indicative offers to purchase six different midstream assets and entered into significant negotiations for the purchase of three of such assets. Several of these opportunities were the subject of an auction process in which the General Partner was not the successful bidder as the result of more aggressive bids being placed by other entities. In each case, management of the General Partner believed that the successful bids exceeded the value of the assets.

At the present time, the Partnership’s sole operating subsidiary is Regional. Cash flow from the Partnership’s current and future operating subsidiaries are intended to fund the various costs incurred by the General Partner in operating the Partnership (including the compliance costs associated with being a publicly-registered entity), acquisition costs (including costs associated with identifying and valuing acquisition targets, performing due diligence reviews and documenting a potential transaction) and other governance activities associated with a publicly-traded entity. At the time of the Sale, the General Partner anticipated the need for cash reserves sufficient to allow the Partnership to regain compliance with its delinquent tax and financial reporting requirements and to fund general overhead for a reasonable period of time while it identified and completed the acquisition of additional assets that would provide sufficient liquidity to fund its future operations and the ongoing overhead costs described above. Those funds were exhausted by September 2012. In connection with the GP Sale during October 2012, the General Partner raised additional funds which it believed were sufficient to cover general overhead for an additional six months with the intent of completing an acquisition within that time frame. Those funds were exhausted by June 2013. As described in the previous paragraph, the General Partner has not completed an acquisition of additional assets.

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On August 19, 2013, the General Partner entered into a non-binding Letter of Intent (“LOI”) with the Third Party outlining the terms and conditions by which the General Partner would issue new membership interests. The LOI is non-binding, except for certain provisions including confidentiality and provisions related to the payment of an additional $300,000 as consideration for extending the Stand-Still Period to the earlier to occur of the execution of a definitive purchase agreement or termination of the LOI. The LOI terminated on October 23, 2013. The parties are still negotiating for the completion of a transaction. The additional consideration is also secured by the second lien on the assets of Regional. Should a definitive purchase agreement not be executed and a transaction completed, the entire $400,000 (“Third Party Advance”) is due and payable to the Third Party on the same terms as set forth in the Letter. As of September 30, 2013, the Third Party Advance has been exhausted. Any transaction ultimately agreed to between the parties is subject to the preparation, authorization, execution and delivery of a definitive purchase agreement, the approval of the definitive purchase agreement by all of the members of the General Partner (as required by its company agreement), the receipt of all material consents and approvals necessary to complete such transaction, and certain other requirements set forth in the LOI. There is no assurance that the General Partner and the Third Party will reach agreement on the terms necessary to complete the definitive purchase agreement or that the members of the General Partner will approve such agreement.

Due to the Partnership’s and the General Partner’s concerns over future liquidity, 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 Mr. Montgomery since September 2011 and the Chief Financial Officer since September 2011. In addition, the General Partner has not reimbursed Rover Technologies LLC since September 2011 for its share of the overhead costs. Management intends to resume compensation to the executive officers and satisfy outstanding expense reimbursements to the executive officers and/or their affiliates at such time as sufficient working capital is available to pay such expenses.

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 nine months beginning April 20, 2013 and then 26 equal monthly payments of $56,000 (principal and interest) from the tenth month through the 35^th month with a balloon payment of $1,612,000 due on March 19, 2016. Regional is also required to perform maintenance of its facilities and complete upgrades in accordance with terms of the New Asphalt Agreement. RVOP is required to pay $125,000 by December 10, 2013 in connection with the settlement of the TransMontaigne dispute. The Third Party Advance may be required to be repaid by December 31, 2013.

Regional’s projected revenues are not expected to be sufficient to meet the expected cash requirements for operations, including required maintenance and upgrades of the facilities, and the other payment obligations described above. Furthermore, Regional’s operational cash flows have been negatively impacted from declining hauling revenues. On March 31, 2013, Regional ceased operations at the Johnson City facility and management has not been successful in recapturing the lost hauling revenues from the Johnson City facility to date and recently made arrangements to return five of the New Tractors under the Lease Agreement. During the remainder of fiscal 2013, one contract which provides for the leasing of one of the Large Tanks is subject to expiration. Regional expects to be able to negotiate an extension to the existing contract under terms no less favorable than the existing terms. In order to further reduce operating costs, Regional has reduced the size of its administrative staff by laying off three workers. Management of Regional continues to examine ways to further reduce costs associated with its hauling business given the reduced demand for its services. This could include the sale of a portion of its tanker trailers and/or the termination of the Penske Lease Agreement.

Currently the Partnership and the General Partner have each exhausted their available cash reserves. Based on the factors described above, Regional’s future stability depends on managements ability to continue to negotiate successfully with creditors until such time that operations have been stabilized and/or Regional is able to obtain additional working capital through increases of advances under the Hopewell Loan or from funding provided by the Partnership and/or the General Partner and assumes that none of the obligations described above or any other obligations are accelerated and/or projected results of operations are less than anticipated.

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Although the use of Regional’s remaining cash from operations, if any, to fund the Partnership’s and the General Partner’s overhead expenses is not expected to be available in the near term, any funding by Regional is restricted as a result of the debt covenants associated with the Hopewell Loan Agreement, the Third Party Advance and the agreement to subordinate the payment of all intercompany receivables and loans to the Hopewell Note. Currently, there is no cash available for distribution to the Partners. At September 30, 2013, the Partnership had unpaid third-party obligations totaling $5,200,000 and contingent liabilities. The Partnership also had intercompany obligations to the General Partner for cash advances of $1,955,000 at September 30, 2013.

Management also continues to seek acquisition opportunities for the Partnership to expand its assets and generate additional cash from operations. There is no assurance that Regional will have sufficient working capital to cover the ongoing overhead expenses of the Partnership and the General Partner (including unpaid salaries, expense reimbursements and professional fees) for the period of time that management believes is necessary to complete an acquisition that will provide additional working capital for the Partnership. 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 the Partnership does not have sufficient cash reserves, its ability to pursue additional acquisition transactions will be adversely impacted. Should the Partnership fail to obtain the needed working capital as required in the near future, it will be forced to take alternative action, such as the sale of assets or liquidation.

Management believes that the future completion of any acquisition will require the use of then available Partnership resources, third-party debt and/or proceeds from the issuance of additional Common Units or new securities by the Partnership, or a combination thereof. Management does not expect that it will complete an acquisition before the second quarter of 2014. There is no assurance that management will be successful in completing an acquisition. If an acquisition is completed, management expects that the terms of any related financing will contain some form of restriction on the Partnership’s ability to make distributions on its Common Units until such time as the acquired operations have been stabilized and the Partnership has built adequate cash reserves for its operations.

Based on the Partnership’s expected cash flow constraints and the likelihood of a restriction on distributions as a result of anticipated acquisitions, effective March 22, 2012, the General Partner and Limited Partners holding a majority of the issued and outstanding Common Units of the Partnership voted to amend the Partnership Agreement to change the commencement of the payment of Common Unit Arrearages from the first 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 the acquisition and the overall success of the Partnership and its operating subsidiaries.

In addition to eliminating the obligation to make payments of any unpaid minimum quarterly distributions until an undetermined date to be established by its Board of Directors, 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 the 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 its next acquisition since the financing of an acquisition may 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.

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In addition to its 2% General Partner interest, the General Partner is currently the holder of incentive distribution rights which entitle 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 Common Units and the General Partner 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.

The General Partner has the right, at any time when Unitholders have received distributions for each of the four most recently completed quarters and the amount of each such distribution did not exceed the adjusted operating surplus of the Partnership for such quarter, to reset the minimum quarterly distribution and the target distribution levels based on the average of the distributions actually made for the two most recent quarters immediately preceding the reset election. Following a reset election, the minimum quarterly distribution will be adjusted to equal the reset minimum quarterly distribution, and the target distribution levels will be reset to correspondingly higher levels based on percentage increases above the reset minimum quarterly distribution.

If the General Partner elects to reset the target distribution levels, the holder of the incentive distribution rights will be entitled to receive their proportionate share of a number of Common Units derived by dividing (i) the average amount of cash distributions made by the Partnership for the two full quarters immediately preceding the reset election by (ii) the average of the cash distributions made by the Partnership in respect of each Common Unit for the same period. Our General Partner will also be issued the number of general partner units necessary to maintain its 2% general partner’s interest in the Partnership that existed immediately prior to the reset election at no cost to the General Partner. We anticipate that our General Partner would exercise this reset right in order to facilitate acquisitions or internal growth projects that would not be sufficiently accretive to cash distributions per Common Unit without such conversion. It is possible, however, that our General Partner could exercise this reset election at a time when it is experiencing, or expects to experience, declines in the cash distributions it receives related to its incentive distribution rights and may, therefore, desire to be issued Common Units rather than retain the right to receive distributions based on the initial target distribution levels. This risk could be elevated if our incentive distribution rights have been transferred to a third party. As a result, a reset election may cause our Unitholders to experience a reduction in the amount of cash distributions that they would have otherwise received had we not issued new Common Units and general partner interests in connection with resetting the target distribution levels. Additionally, our General Partner has the right to transfer our incentive distribution rights at any time, and such transferee shall have the same rights as the General Partner relative to resetting target distributions if our General Partner concurs that the tests for resetting target distributions have been fulfilled.

Tax Liabilities

Federal Tax Liabilities – Regional

As of September 30, 2013, Regional has accrued $0 and $8,000 for federal income taxes and associated penalties and interest, respectively.

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State Tax Liabilities - Regional

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 corporation.

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

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Disputes

VOSH Actions

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 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.

TransMontaigne Dispute

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SGR Energy LLC

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Other

Terminal Operator Status of Regional Facility

Debt Obligations

RZB Loan

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Hopewell Loan

Should a definitive purchase agreement not be executed and a transaction completed pursuant to the LOI with the Third Party as described above, the Third Party Advance with all accrued and unpaid interest is due and payable by December 31, 2013 to the Third Party. Should the General Partner fail to pay the required amounts, the Third Party has the right to foreclose on the assets of Regional without notice to the General Partner or Hopewell.

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Advances from General Partner

In connection with the Third Party Advance (see above), $358,000 was used by the General Partner during the three months ended September 30, 2013 to fund working capital requirements of Central, including the payment of certain outstanding obligations.

Intercompany Notes

Regional. 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 September 30, 2013 is $4,046,000. The payment of this amount is subordinated to the payment of the Hopewell Note by Regional.

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 September 30, 2013, the intercompany balance owed by Regional to the Partnership and/or RVOP is approximately $1,914,000, 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.

Material Agreements

Employment Agreement

During March 2013, the General Partner entered into an employment agreement with Ian T. Bothwell, Executive Vice President, Chief Financial Officer and Secretary of the General Partner and President of Regional. The provisions of the employment agreement are set forth in “Note G – Commitments and Contingencies – Employment Agreement” to the unaudited consolidated financial statements.

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Unpaid Compensation and Reimbursements

Due to the Partnership’s and the General Partner’s concerns over future liquidity, 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 Mr. 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.

Tank Storage and Terminal Services Agreements

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Equipment Leases

Penske Truck Lease

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Private Placements

On November 17, 2010, the Partnership issued 12,724,019 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 Corporation and Central Energy, LP. Central Energy, LP was obligated, under the terms of its limited partnership agreement, to distribute all of the Common Units of the Partnership which it acquired in the Sale to its limited partners, which it did on May 26, 2011. As a result, The Cushing MLP Opportunity Fund I L.P. holds 7,413,013 Common Units of the Partnership (46.1%) and Sanctuary Capital LLC holds 1,017,922 Common Units of the Partnership (6.3%).

Reimbursement Agreements

Allocated Expenses Charged to Subsidiary

Registration Rights Agreements

Penn Octane Corporation

Limited Partners of Central Energy, LP

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Realization of Assets

Central’s deficit in working capital, excluding the current amounts due under the Hopewell Loan, totaled $1,958,000 at September 30, 2013. If a definitive transaction with the Third Party is not completed, the General Partner is obligated to repay the Third Party Advance of $400,000, plus interest, by December 31, 2013 or the Third Party will have the right to foreclose on the assets of Regional without notice to the General Partner. In connection with the New Asphalt Agreement, Regional is required to fund up to $465,000 during the three to nine months for refurbishments and modifications to the facility. The Partnership and the General Partner have limited cash resources and are dependent on Regional to fund ongoing corporate expenses.

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Off-Balance Sheet Arrangements

The Partnership and Regional do not have any off-balance sheet arrangements.

Recently Issued Financial Accounting Standards

The Accounting Standards Codification is the single source of authoritative generally accepted accounting principles (“GAAP”) recognized by the Financial Accounting Standards Board to be applied by nongovernmental entities in the preparation of financial statements in conformity with GAAP. Rules and interpretive releases of the SEC, under authority of federal securities laws, are also sources of authoritative GAAP for SEC registrants. The Codification became effective for interim and annual periods ending after September 15, 2009 and superseded all previously existing non-SEC accounting and reporting standards. All other non-grandfathered non-SEC accounting literature not included in the Codification is non-authoritative. All of Central’s references to GAAP now use the specific Codification Topic or Section rather than prior accounting and reporting standards. The Codification did not change existing GAAP and therefore, did not affect Central’s consolidated financial position or results of operations.

Critical Accounting Policies

The unaudited consolidated financial statements of Central reflect the selection and application of accounting policies which require management to make significant estimates and judgments. See note B to Central’s audited consolidated financial statements included in its Annual Report on Form 10-K for the fiscal year ended December 31, 2012, “Summary of Significant Accounting Policies”.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

Not applicable.

Item 4. Controls and Procedures.

Disclosure Controls

Disclosure controls are procedures that are designed with the objective of ensuring that information required to be disclosed in our reports under the Securities Exchange Act of 1934, as amended (“Exchange Act”), such as this Quarterly Report, is reported in accordance with the rules of the SEC. Disclosure controls are also designed with the objective of ensuring that such information is accumulated appropriately and communicated to management, including the chief executive officer and chief financial officer, as appropriate, to allow for timely decisions regarding required disclosures.

As of the end of the period covered by this Quarterly Report, we carried out an evaluation, under the supervision and with the participation of our General Partner’s management, including our General Partner’s executive officer and its chief financial officer, of the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Exchange Act Rules 13a-15(e) and 15d-15(e). Based on its assessment and those criteria, management concluded that Central’s disclosure controls and procedures over financial reporting were not effective as of September 30, 2013.

Internal Control Over Financial Reporting

Since mid-2009, our General Partners’ accounting department has consisted of only the chief financial officer, an assistant to the chief financial officer and Regional’s accountant. Our General Partner’s internal control environment is limited in such a manner that there is less than the desired internal control over financial reporting and accounting, except as it relates to Regional and therefore, a system of checks and balances is lacking. As a result of this material weakness, our management concluded that our disclosure controls and procedures were not effective as of September 30, 2013. The lack of sufficient personnel, the inability to complete an acquisition since 2008 and the continued financial difficulties encountered by Central was and continues to be the major reason that Central has been unable to comply with the reporting requirements of the Exchange Act and related regulations promulgated by the SEC as they relate to the disclosures of financial information and now continues to be an ongoing risk of maintaining compliance in the near future.

During the years ended 2011 and 2012 and the period ended September 30, 2013, the General Partner’s new accounting department was comprised only of the chief financial officer while it sought to identify an acquisition opportunity that might include an accounting function to bolster the General Partner’s and Regional’s accounting capabilities. This has not occurred. As a result, the lack of sufficient personnel continues to be an issue with respect to establishing the desired internal control over financial reporting and accounting. The General Partner does not expect to be able to take the steps necessary to improve its internal control over financial reporting during the remainder of 2013 given its current financial condition absent the acquisition of a company with the necessary accounting functions and personnel to resolve its dilemma. During June 2012 through December 2012, Regional’s controller was required to take several medical leave of absences and ultimately resigned during April 2013. Regional’s assistant controller who was recently hired in January 2013, has assumed the accounting role. During the three months ended September 30, 2013, there were no other changes in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Despite the lack of accounting personnel, the management of the General Partner believes the Partnership’s unaudited consolidated financial statements included in this Quarterly Report fairly present in all material respects its financial position, results of operations and cash flows for the periods presented in accordance with GAAP.

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Part II – OTHER INFORMATION

Item 1. Legal Proceedings

See “Note G – Commitments and Contingencies” to the unaudited consolidated financial statements included in this report for a more detailed discussion of current contingencies.

Item 1A. Risk Factors

See “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations Liquidity and Capital Resources” regarding the risks associated with Central’s inability to obtain additional working capital.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

See “Note F – Unit Options and Equity Incentive Plan” and “Note G – Commitments and Contingencies” to the unaudited consolidated financial statements included in this report for a more detailed discussion of unregistered sales of equity securities.

Item 3. Defaults upon Senior Securities

See Note E – Debt Obligations to the unaudited consolidated financial statements included in this report for material defaults with respect to the RZB Note.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

Item 6. Exhibits

The following Exhibits are incorporated by reference to previously filed reports, as noted:

Exhibit No.
2.1		Distribution Agreement, dated September 16, 2004, by and among Penn Octane Corporation, Rio Vista Energy Partners L.P. and its Subsidiaries. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10 filed August 26, 2004, SEC File No. 000-50394).

2.2		Amended and Restated Purchase and Sale Agreement, dated August 15, 2006, by and between Rio Vista Operating Partnership L.P. and TransMontaigne Product Services Inc. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2006, filed on November 20, 2006, SEC File No. 000-50394).

2.3		Agreement and Plan of Merger, dated July 27, 2007, by and among Rio Vista Energy Partners L.P., Regional Enterprises, Inc., Regional Enterprises, Inc. (also known as Regional Enterprises, Inc.); the shareholders; and W. Gary Farrar, Jr. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

2.4		Articles of Merger of Regional Enterprises, Inc. and Regional Enterprises, Inc., dated July 27 2007. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

2.5		Asset Purchase Agreement, dated October 1, 2007, by and between Rio Vista Penny LLC and G M Oil Properties, Inc. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K, filed on November 26, 2007, SEC File No. 000-50394).

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Exhibit No.
2.6		Amendment to Asset Purchase Agreement, dated November 16, 2007, by and between Rio Vista Penny LLC and G M Oil Properties, Inc. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K, filed on November 26, 2007, SEC File No. 000-50394).

2.7		Asset Purchase Agreement, dated as of October 1, 2007, by and between Rio Vista Penny LLC, Penny Petroleum Corporation and Gary Moores. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K, filed on November 26, 2007, SEC File No. 000-50394).

2.8		Amendment to Asset Purchase Agreement, dated October 25, 2007, by and among Rio Vista Energy Partners L.P., Rio Vista Penny LLC, Penny Petroleum Corporation and Gary Moores. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K, filed on November 26, 2007, SEC File No. 000-50394).

2.9		Second Amendment to Asset Purchase Agreement, dated November 16, 2007, by and among Rio Vista Energy Partners L.P., Rio Vista Penny LLC, Penny Petroleum Corporation and Gary Moores. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K, filed on November 26, 2007, SEC File No. 000-50394).

2.10		Stock Purchase Agreement, dated October 2, 2007, by and between Rio Vista GO, GO LLC, Outback Production Inc., Gary Moores and Bill Wood. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K, filed on November 26, 2007, SEC File No. 000-50394).

2.11		Amendment to Membership Interest Purchase and Sale Agreement, dated November 16, 2007, by and between Rio Vista Energy Partners L.P., Rio Vista GO LLC, Outback Production Inc., GO LLC, and Gary Moores and Bill Wood. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K, filed on November 26, 2007, SEC File No. 000-50394).

2.12		Purchase and Sale Agreement, dated December 26, 2007, by and among Rio Vista Operating Partnership L.P., Penn Octane International, LLC, TMOC Corp., TLP MEX L.L.C. and RAZORBACK L.L.C. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K, filed on January 3, 2008, SEC File No. 000-50394).

2.13		Securities Purchase and Sale Agreement between Central Energy, LLC, Rio Vista Energy Partners L.P. and Penn Octane Corporation dated May 25, 2010. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on May 28, 2010, SEC File No. 000-50394.)

2.14		Third Amendment to Securities Purchase and Sale Agreement between Central Energy, LLC, Rio Vista Energy Partners L.P. and Penn Octane Corporation, effective July 21, 2010 and dated August 9, 2010. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on August 13, 2010, SEC File No. 000-50394.)

2.15		Fourth Amendment to Securities Purchase and Sale Agreement between Central Energy, LLC, Rio Vista Energy Partners L.P. and Penn Octane Corporation, dated November 17, 2010. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on November 23, 2010, SEC File No. 000-50394.)

3.1		Certificate of Limited Partnership of Rio Vista Energy Partners L.P., filed July 10, 2003. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10 filed August 26, 2004, SEC File No. 000-50394).

3.2		Amendment of Certificate of Limited Partnership of Rio Vista Energy Partners L.P., filed September 17, 2003. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2004, filed on November 22, 2004, SEC File No. 000-50394).

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Exhibit No.
3.3		First Amended and Restated Limited Partnership Agreement of Rio Vista Energy Partners L.P., dated September 16, 2004. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10, filed August 26, 2004, SEC File No. 000-50394).

3.4		First Amendment to the First Amended and Restated Agreement of Limited Partnership of Rio Vista Energy Partners L.P., dated October 26, 2005. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2005, filed on November 21, 2005, SEC File No. 000-50394).

3.5		Certificate of Formation of Rio Vista GP LLC. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10 filed August 26, 2004, SEC File No. 000-50394).

3.6		Rio Vista GP LLC Amended and Restated Limited Liability Company Agreement, dated September 16, 2004. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10 filed August 26, 2004, SEC File No. 000-50394).

3.7		First Amendment to Amended and Restated Limited Liability Company Agreement of Rio Vista GP LLC, dated October 2, 2006. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2005, filed on April 6, 2006, SEC File No. 000-50394).

3.8		First Amendment to the Amended and Restated Limited Liability Company Agreement of Rio Vista GP, LLC dated December 28, 2010. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on January 4, 2011, SEC File No. 000-50394.)

3.9		Amendment to Certificate of Formation of Rio Vista GP, LLC dated December 28, 2010. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on January 4, 2011, SEC File No. 000-50394.)

3.10		Second Amendment to the First Amended and Restated Agreement of Limited Partnership of Rio Vista Energy Partners L.P. dated December 28, 2010. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on January 4, 2011, SEC File No. 000-50394.)

3.11		Amendment to Certificate of Limited Partnership of Rio Vista Energy Partners, L.P. dated December 28, 2010. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on January 4, 2011, SEC File No. 000-50394.)

3.12		Second Amended and Restated Limited Liability Company Agreement of Central Energy GP LLC, dated April 12, 2011. (Incorporated by reference to the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2010 and filed on April 15, 2011, SEC File No. 000-50394.)

3.13		Second Amended and Restated Agreement of Limited partnership of Central Energy Partners LP, dated April 12, 2011. (Incorporated by reference to the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2010 and filed on April 15, 2011, SEC File No. 000-50394.)

3.14		Amendment to Second Amended and Restated Agreement of Limited Partnership of the Partnership dated March 28, 2012. (Incorporated by reference to the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2011 and filed on March 30, 2012, SEC File No. 000-50394.)

4.1		Specimen Unit Certificate for Common Units. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10 filed August 26, 2004, SEC File No. 000-50394).

4.2		Forms of Warrants to Purchase Common Units to be issued to Penn Octane warrant holders. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10 filed August 26, 2004, SEC File No. 000-50394).

	58

Exhibit No.
4.3		Registration Rights Agreement, dated December 3, 2007, by and among Rio Vista Energy Partners L.P., Rio Vista GP LLC, Standard General Fund L.P., Credit Suisse Management LLC and Structured Finance Americas LLC. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K, filed on December 4, 2007, SEC File No. 000-50394).

4.4		Registration Rights Agreement dated as of May 27, 2009 by and between Rio Vista Energy Partners L.P. and TCW Energy X Blocker, L.L.C. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on June 2, 2009, SEC File No. 000-50394.)

4.5		Registration Rights Agreement dated as of August 1, 2011 by and among Central Energy Partners LP and the limited partners of Central Energy, LP. (Incorporated by reference to the Partnership’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2011 and filed on August 15, 2011, SEC File No. 000-50394.)

4.6		Specimen Common Unit Certificate of Central Energy Partners LP (Incorporated by reference to the Partnership’s Quarterly Report on Form 10-Q filed on May 15, 2012, SEC File No. 000-50394.)

10.1		Contribution, Conveyance and Assumption Agreement, dated September 16, 2004, by and among Penn Octane Corporation, Rio Vista GP LLC, Rio Vista Energy Partners L.P., Rio Vista Operating GP LLC and Rio Vista Operating Partnership L.P. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10, filed August 26, 2004, SEC File No. 000-50394).

10.2		Omnibus Agreement, dated September 16, 2004, by and among Penn Octane Corporation, Rio Vista GP LLC, Rio Vista Energy Partners, L.P. and Rio Vista Operating Partnership L.P. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10, filed August 26, 2004, SEC File No. 000-50394).

10.3		Amendment No. 1 to Omnibus Agreement, dated September 16, 2004, by and among Penn Octane Corporation, Rio Vista GP LLC, Rio Vista Energy Partners L.P. and Rio Vista Operating Partnership L.P. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2004, filed on November 22, 2004, SEC File No. 000-50394).

10.4		Purchase Contract, dated October 1, 2004, by and between Penn Octane Corporation and Rio Vista Operating Partnership L.P. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10, filed August 26, 2004, SEC File No. 000-50394).

10.5		Form of Unit Purchase Option between Penn Octane Corporation and Shore Capital LLC. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10, filed August 26, 2004, SEC File No. 000-50394).

10.6		Form of Unit Purchase Option between Penn Octane Corporation and Jerome B. Richter. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10, filed August 26, 2004, SEC File No. 000-50394).

10.7		Rio Vista Energy Partners L.P. Unit Option Agreement, dated July 10, 2003, granted to Shore Capital LLC. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10, filed August 26, 2004, SEC File No. 000-50394).

10.8		Form of RVGP Voting Agreement by and among Rio Vista GP LLC, Penn Octane Corporation and the members of Rio Vista GP LLC. (Incorporated by reference to Rio Vista’s Registration Statement on Form 10 filed August 26, 2004, SEC File No. 000-50394).

	59

Exhibit No.
10.9		Conveyance Agreement, dated September 30, 2004 from Penn Octane Corporation in favor of Rio Vista Operating Partnership L.P. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2004, filed on November 22, 2004, SEC File No. 000-50394).

10.10		Guaranty & Agreement between Rio Vista Energy Partners L.P. and RZB Finance LLC, dated September 15, 2004. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2004, filed on November 22, 2004, SEC File No. 000-50394).

10.11		Guaranty & Agreement, dated September 15, 2004, between Rio Vista Operating Partnership L.P. and RZB Finance LLC. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2004, filed on November 22, 2004, SEC File No. 000-50394).

10.12		General Security Agreement, dated September 15, 2004, between Rio Vista Energy Partners L.P. and RZB Finance LLC. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2004, filed on November 22, 2004, SEC File No. 000-50394).

10.13		General Security Agreement, dated September 15, 2004, between Rio Vista Operating Partnership L.P. and RZB Finance LLC. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2004, filed on November 22, 2004, SEC File No. 000-50394).

10.14*		Rio Vista Energy Partners L.P. 2005 Equity Incentive Plan (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2004, filed on April 12, 2005, SEC File No. 000-50394).

10.15		Promissory Note, dated August 15, 2005, between Rio Vista Operating Partnership L.P. and TransMontaigne Product Services Inc. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2005, filed on August 19, 2005, SEC File No. 000-50394).

10.16		Security Agreement, dated August 15, 2005, between Rio Vista Operating Partnership L.P. and TransMontaigne Product Services Inc. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2005, filed on August 19, 2005, SEC File No. 000-50394).

10.17		Amended and Restated Consulting Agreement, dated November 15, 2005, by and among Penn Octane Corporation, Rio Vista Energy Partners and Jerome B. Richter. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2005, filed on November 21, 2005, SEC File No. 000-50394).

10.18		Unit Purchase Option, dated February 6, 2007, between Shore Trading LLC and Penn Octane Corporation. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2006, filed on April 17, 2007, SEC File No. 000-50394).

10.19		Consent to Transfer of Units, Acknowledgement of Representation, and Waiver of Conflicts, dated February 6, 2007, by and among Penn Octane Corporation, Rio Vista GP LLC and Shore Trading LLC. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2006, filed on April 17, 2007, SEC File No. 000-50394).

	60

Exhibit No.
10.20		Consulting Agreement entered into on March 5, 2007, with an effective date of November 15, 2006 by and between Penn Octane Corporation and Rio Vista Energy Partners L.P. and JBR Capital Resources, Inc. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2006, filed on April 17, 2007, SEC File No. 000-50394).

10.21		Letter Agreement, dated March 5, 2007, by and between Penn Octane Corporation, Rio Vista Energy Partners L.P. and JBR Capital Resources, Inc. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2006, filed on April 17, 2007, SEC File No. 000-50394).

10.22*		Form of Rio Vista GP LLC Chairman Services Agreement. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2006, filed on April 17, 2007, SEC File No. 000-50394).

10.23*		Form of Rio Vista GP LLC Managers Services Agreement. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2006, filed on April 17, 2007, SEC File No. 000-50394).

10.24*		Form of Rio Vista GP LLC Manager and Officer Indemnification Agreement. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2006, filed on April 17, 2007, SEC File No. 000-50394).

10.25*		Form of Nonqualified Unit Option Agreement under the 2005 Rio Vista Energy Partners L.P. Equity Incentive Plan. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2006, filed on April 17, 2007, SEC File No. 000-50394).

10.26		Consulting Agreement, dated November 1, 2006, by and among Penn Octane Corporation And Rio Vista Energy Partners L.P. and Ricardo Canney. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.27		Consulting Agreement, dated July 2, 2007, by and between Rio Vista Energy Partners, L.P. and CEOcast, Inc. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.28		Employment and Non-Competition Agreement, dated July 27, 2007, by and between Regional Enterprises, Inc. and W. Gary Farrar, III. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.29		Escrow Agreement, dated July 27, 2007, by and among Rio Vista Energy Partners L.P., Regional Enterprises, Inc., W. Gary Farrar, Jr., and First Capital Bank. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.30		Loan Agreement, dated July 26, 2007, by and between Rio Vista Energy Partners L.P., and RZB Finance LLC (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.31		Guaranty and Agreement, dated July 26, 2007, by and between Regional Enterprises, Inc., and RZB Finance LLC. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

	61

Exhibit No.
10.32		Guaranty and Agreement, dated July 26, 2007, by and between Penn Octane Corporation, and RZB Finance LLC. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.33		Guaranty and Agreement, dated July 26, 2007, by and between Rio Vista Operating Partnership L.P. and RZB Finance LLC Dated As Of July 26, 2007. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.34		$5,000,000 Promissory Note, dated July 26, 2007, issued by Rio Vista Energy Partners L.P. to RZB Finance LLC. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.35		General Security Agreement, dated July 26, 2007, by and between RZB Finance LLC and Regional Enterprises, Inc. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.36		Pledge Agreement, dated July 26, 2007, by and between: Rio Vista Energy Partners L.P., and RZB Finance LLC. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.37		First Amendment to Line Letter, dated July 26, 2007, by and between RZB Finance LLC and Penn Octane Corporation. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.38		Debt Assumption Agreement, dated July 26, 2007, by and between Rio Vista Energy Partners L.P. and Regional Enterprises, Inc. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.39		$5,000,000 Debt Assumption Note, dated July 26, 2007, issued by Regional Enterprises, Inc. to Rio Vista Energy Partners L.P. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.40		$2,500,000 Promissory Note, dated July 26, 2007, issued by Regional Enterprises, Inc. to Rio Vista Energy Partners L.P. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.41		Environmental Indemnity Agreement, dated July 26, 2007, by and between Regional Enterprises, Inc. and RZB Finance LLC. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

10.42		Reaffirmation of Security Agreements, dated July 26, 2007, by and among Rio Vista Energy Partners L.P., Penn Octane Corporation Rio Vista Operating Partnership L.P., and RZB Finance LLC. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on August 20, 2007, SEC File No. 000-50394).

	62

Exhibit No.
10.43		Binding Letter of Intent, dated September 12, 2007, by and between TransMontaigne Partners L.P. and Rio Vista Operating Partnership L.P. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on November 19, 2007, SEC File No. 000-50394).

10.44		Restated and Amended Promissory Note, dated September 12, 2007, by and between Rio Vista Operating Partnership L.P. and TransMontaigne Product Services, Inc. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on November 19, 2007, SEC File No. 000-50394).

10.45		Restated and Amended Security Agreement, dated September 12, 2007, by and among Rio Vista Operating Partnership, L.P., TransMontaigne Product Services, Inc. and TransMontaigne Partners L.P. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on November 19, 2007, SEC File No. 000-50394).

10.46		First Priority Equity Interest Pledge Agreement, dated September 12, 2007, by and among Rio Vista Operating Partnership, L.P., Penn Octane International, LLC, TransMontaigne Product Services, Inc. and TransMontaigne Partners L.P., with the acknowledgment of Penn Octane de Mexico, S. de R.L. de C.V. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on November 19, 2007, SEC File No. 000-50394).

10.47		First Priority Equity Interest Pledge Agreement, dated September 12, 2007, by and among Rio Vista Operating Partnership, L.P., Penn Octane International, LLC, TransMontaigne Product Services, Inc. and TransMontaigne Partners L.P., with the acknowledgment of Termatsal, S. de R.L. de C.V. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on November 19, 2007, SEC File No. 000-50394).

10.48		Assignment Agreement, dated September 12, 2007, by and among Rio Vista Operating Partnership, L.P., TransMontaigne Partners L.P. and TransMontaigne Product Services, Inc. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2007, filed on November 19, 2007, SEC File No. 000-50394).

10.49		Unit Purchase Agreement, dated November 29, 2007, by and among Rio Vista Energy Partners L.P., Rio Vista GP LLC, Standard General Fund L.P., Credit Suisse Management LLC and Structured Finance Americas LLC. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K, filed on December 4, 2007, SEC File No. 000-50394).

10.50		Guaranty made as of November 19, 2007 by Rio Vista Eco LLC, Rio Vista GO LLC, GO LLC and MV Pipeline Company in favor of TCW Asset Management Company as administrative agent for Holders. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2007, filed on April 15, 2008, SEC File No. 000-50394).

10.51		Security Agreement dated as of November 19, 2007 by Rio Vista Penny LLC in favor of TCW Asset Management Company, as administrative agent. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2007, filed on April 15, 2008, SEC File No. 000-50394).

10.52		Assumption Agreement dated November 19, 2007 by and among GM Oil Properties, Inc., Rio Vista Penny LLC, TCW Asset Management Company, as administrative agent and the holders party to the Note Purchase Agreement. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2007, filed on April 15, 2008, SEC File No. 000-50394).

	63

Exhibit No.
10.53		Rio Vista Energy Partners L.P. Common Unit Purchase Warrant issued to TCW Energy Funds X Holdings, L.P. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2007, filed on April 15, 2008, SEC File No. 000-50394).

10.54		Promissory note dated November 19, 2007 issued by Rio Vista to Gary Moores. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2007, filed on April 15, 2008, SEC File No. 000-50394).

10.55		Note Purchase Agreement between Rio Vista Penny LLC, TCW Asset Management Company and TCW Energy Fund X Investors dated November 19, 2007. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2007, filed on April 15, 2008, SEC File No. 000-50394).

10.56		First Amendment to Note Purchase Agreement dated as of September 29, 2008 by and among Rio Vista Penny LLC, TCW Asset Management Company, and the Holders party to the Original Note Purchase Agreement. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2008, filed on November 17, 2008, SEC File No. 000-50394).

10.57		Amended and Restated Management Services Agreement, dated and effective as of September 29, 2008, is made by and among Rio Vista Operating LLC, Rio Vista Energy Partners L.P., and Rio Vista Penny LLC. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2008, filed on November 17, 2008, SEC File No. 000-50394).

10.58		Promissory Note dated April 15, 2008 between Rio Vista Energy Partners L.P. and Jerome B. Richter. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2008, filed on November 17, 2008, SEC File No. 000-50394).

10.59		Amendment to Promissory Note dated June 27, 2008 issued by Rio Vista to Gary Moores. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2008, filed April 14, 2009, SEC File No. 000-50394.)

10.60		Second Amendment to Promissory Note dated January 20, 2009 issued by Rio Vista to Gary Moores. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2008, filed April 14, 2009, SEC File No. 000-50394.)

10.61		Second Amendment to Loan Agreement dated as of July 2008 between RZB Finance LLC and Rio Vista. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2008, filed April 14, 2009, SEC File No. 000-50394.)

10.62		Third Amendment to Loan Agreement dated as of December 2008 between RZB Finance LLC and Rio Vista. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2008, filed April 14, 2009, SEC File No. 000-50394.)

10.63		Fourth Amendment to Loan Agreement dated as of February 28, 2009 between RZB Finance LLC and Rio Vista. . (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2008, filed April 14, 2009, SEC File No. 000-50394.)

10.64		Fifth Amendment to Loan Agreement dated as of March 31, 2009 between RZB Finance LLC and Rio Vista. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2008, filed April 14, 2009, SEC File No. 000-50394.)

	64

Exhibit No.
10.65		Letter agreement to extend payments and other requirements pursuant to Note Purchase Agreement dated December 30, 2008 between Rio Vista Penny LLC and TCW Asset Management Company. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2008, filed April 14, 2009, SEC File No. 000-50394.)

10.66		Letter agreement to extend payments and other requirements pursuant to Note Purchase Agreement dated February 28, 2009 between Rio Vista Penny LLC and TCW Asset Management Company. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2008, filed April 14, 2009, SEC File No. 000-50394.)

10.67		Letter agreement to extend payments and other requirements pursuant to Note Purchase Agreement dated March 23, 2009 between Rio Vista Penny LLC and TCW Asset Management Company. (Incorporated by reference to Rio Vista’s Annual Report on Form 10-K for the year ended December 31, 2008, filed April 14, 2009, SEC File No. 000-50394.)

10.68		Letter Agreement to extend payments and other requirements pursuant to Note Purchase Agreement dated April 13, 2009 between Rio Vista Penny LLC and TCW Asset Management Company. (Incorporated by reference to Rio Vista’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2009, filed on May 20, 2009, SEC File No. 000-50394.)

10.69		Settlement Agreement dated as of May 27, 2009 by and between Rio Vista Energy Partners L.P., Rio Vista ECO, LLC, TCW Asset Management Company, as administrative agent, and TCW Energy X Blocker, L.L.C. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on June 2, 2009, SEC File No. 000-50394.)

10.70		Sixth Amendment, Assumption of Obligations and Release Agreement dated as of June 12, 2009 among RZB Finance LLC, Rio Vista Energy Partners L.P. and Regional Enterprises Inc. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on June 19, 2009, SEC File No. 000-50394.)

10.71		The press release of Rio Vista Energy Partners L.P. dated November 14, 2009, announcing the delay in filing the September 30, 2009 quarterly financial statements on Form 10-Q. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on August 17, 2009, SEC File No. 000-50394.)

10.72		The press release of Rio Vista Energy Partners L.P. dated November 14, 2009, announcing its receipt of the NASDAQ Determination Letter which denied Rio Vista’s plan for regaining compliance with NASDAQ Marketplace Rule 5250(c)(1). (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on October 2, 2009, SEC File No. 000-50394.)

10.73		The press release of Rio Vista Energy Partners L.P. dated November 23, 2009 announcing that its receipt of the NASDAQ letter indicating that Rio Vista’s failure to file the September 30, 2009 quarterly report on Form 10-Q would serve as additional basis for delisting Rio Vista securities from NASDAQ and the delinquent filing would be shared with the Listing Qualifications Panel in connection with Rio Vista’s appeal of NASDAQ decision to delist Rio Vista securities from the NASDAQ Capital market. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on November 23, 2009, SEC File No. 000-50394.)
10.74		Seventh Amendment dated as of May 21, 2010 between RZB Finance LLC and Regional Enterprises Inc. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on May 28, 2010, SEC File No. 000-50394.)

	65

Exhibit No.
10.75		Conditional Acceptance of Settlement Offer and Release dated as of November 17, 2010, by and among each of Ian T. Bothwell, Bruce I. Raben, Ricardo Rodriquez, Murray J. Feiwell, Nicholas J. Singer and Douglas L. manner, on the one hand, and Rio Vista Energy partners L.P. on the other. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on November 23, 2010, SEC File No. 000-50394.)

10.76		Mutual Release dated as of November 17, 2010 by and among Penn Octane Corporation, Rio Vista Energy Partners, L.P. and Rio Vista GP, LLC. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on November 23, 2010, SEC File No. 000-50394.)

10.77		Release dated as of November 17, 2010 by Rio Vista Energy Partners, L.P., Rio Vista GP, LLC and Central Energy, LP, and the persons identified on Schedule I attached thereto. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on November 23, 2010, SEC File No. 000-50394.)

10.78		Termination Agreement dated as of November 17, 2010 among Penn Octane Corporation, Rio Vista GP, LLC, Rio Vista Energy Partners, L.P. and Rio Vista Operating Partnership L.P. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on November 23, 2010, SEC File No. 000-50394.)

10.79*		Employment Agreement between Rio Vista GP, LLC and Imad K. Anbouba dated December 28, 2010. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on January 4, 2011, SEC File No. 000-50394.)

10.80*		Employment Agreement between Rio Vista GP, LLC and Carter R. Montgomery dated December 28, 2010. (Incorporated by reference to Rio Vista’s Current Report on Form 8-K filed on January 4, 2011, SEC File No. 000-50394.)

10.81		Installment Agreement dated November 17, 2010 by and between Regional Enterprises, Inc. and the Internal Revenue Service. (Incorporated by reference to the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2010 and filed on April 15, 2011, SEC File No. 000-50394.)

10.82		Buy-Sell Agreement dated April 13, 2011 by and among Imad K. Anbouba, Carter R. Montgomery and the Cushing MLP Opportunity Fund I, L.P. (Incorporated by reference to the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2010 and filed on April 15, 2011, SEC File No. 000-50394.)

10.83		Reimbursement Agreement effective November 17, 2010, by and between Central Energy GP LLC and AirNow Industrial Compressions Systems, LTD. (Incorporated by reference to the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2010 and filed on April 15, 2011, SEC File No. 000-50394.)

10.84		Reimbursement Agreement effective January 1, 2011 by and between Central Energy GP LLC and Rover Technologies LLC. (Incorporated by reference to the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2010 and filed on April 15, 2011, SEC File No. 000-50394.)

10.85*		Employment Agreement of Donald P. Matthews dated November 22, 2011. (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on November 28, 2011, SEC File No. 000-50394.)

10.86		Form of Vehicle Lease Service Agreement by and between Regional Enterprises, Inc. and Penske Truck Leasing Co., L.P. dated January 18, 2012. (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on February 24, 2012, SEC File No. 000-50394.)

	66

Exhibit No.
10.87		Vehicle Maintenance Agreement by and between Regional Enterprises, Inc. and Penske Truck Leasing Co., L.P. dated January 18, 2012. (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on February 24, 2012, SEC File No. 000-50394.)

10.88		Executed Vehicle Lease Service Agreement by and between Regional Enterprises, Inc. and Penske Truck Leasing Co., L.P. dated February 17, 2012. (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on October 11, 2012, SEC File No. 000-50394.)

10.89		Intercompany Demand Promissory Note between Central Energy GP LLC and Central Energy Partners LP dated March 1, 2012. (Incorporated by reference to the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2011 filed on March 30, 2012, SEC File No. 000-50394.)

10.90		Intercompany Demand Promissory Note between Central Energy Partners LP and Regional Enterprises, Inc. dated March 1, 2012. (Incorporated by reference to the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2011 filed on March 30, 2012, SEC File No. 000-50394.)

10.91		Response and Notice of Default and Reservation of Rights dated September 14, 2012 from RB International Finance (USA) LLC (“RBI”) in connection with the Loan Agreement dated as of July 26, 2007 (as amended, supplemented or otherwise modified from time to time) between Regional Enterprises, Inc. (as successor by assumption of obligations to the Partnership) and RBI. (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on September 21, 2012, SEC File No. 000-50394.)

10.92		Notice of Default, Demand for Payment and Reservation of Rights dated October 4, 2012 (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on October 11, 2012, SEC File No. 000-50394.)

10.93		Limited Waiver and Ninth Amendment dated as of November 1, 2012 between RB International Finance (USA) LLC and Regional Enterprises (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on November 30, 2012, SEC File No. 000-50394.)

10.94		Notice of Default, Demand for Payment and Reservation of Rights dated March 1, 2013 (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on March 7, 2013, SEC File No. 000-50394.)

10.95		Term Loan and Security Agreement between Regional Enterprises, Inc., as Borrower, and Hopewell Investment Partners LLC, as Lender, dated March 20, 2013 (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on March 26, 2013, SEC File No. 000-50394.)

10.96		Promissory Note dated March 20, 2013 in an amount of up to $2,500,000 issued by Regional Enterprises, Inc., as Borrower, to Hopewell Investment Partners LLC, as Lender (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on March 26, 2013, SEC File No. 000-50394.)

10.97		First Lien Mortgage, Security Agreement, Assignment of Rents, Leases and Fixture Filing by and from Regional Enterprises, Inc., as Mortgagor, to Hopewell Investment Partners LLC, as Mortgagee, dated as of March 20, 2013 (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on March 26, 2013, SEC File No. 000-50394.)

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Exhibit No.
10.98		Pledge Agreement dated March 20, 2013 by Central Energy Partners LP to Hopewell Investment Partners (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on March 26, 2013, SEC File No. 000-50394.)

10.99		Assignment of Leases and Rents from Regional Enterprises, Inc. to Hopewell Investment Partners LLC (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on March 26, 2013, SEC File No. 000-50394.)

10.100		Environmental Certificate (With Covenants, Representations and Warranties) from Regional Enterprises, Inc. and Central Energy Partners LP to Hopewell Investment Partners LLC (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on March 26, 2013, SEC File No. 000-50394.)

10.101		Unlimited Guaranty dated March 20, 2013 from Central Energy Partners LP to Hopewell Investment Partners LLC (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on March 26, 2013, SEC File No. 000-50394.)

10.102*		Employment Contract of Ian T. Bothwell (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on March 26, 2013, SEC File No. 000-50394.)

16.1		Letter regarding Change of Certifying Accountant (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on October 18, 2011 and the Current Report on Form 8-K/A filed on October 26, 2011, SEC File No. 000-50394).

*		indicates management contract or compensatory plan or arrangement.

The following Exhibits are filed as part of this report:

Exhibit No.		Description
15		Accountant’s Acknowledgement.

31.1		Certification Pursuant to Rule 13a-14(a)/15d-14(a) of the Exchange Act

31.2		Certification Pursuant to Rule 13a-14(a)/15d-14(a) of the Exchange Act

32		Certification Pursuant to 18 U.S.C. Section 1350 as adopted Pursuant to Section 906 of the Sarbanes – Oxley Act of 2002

All of the Exhibits are available from the SEC’s website at www.sec.gov. In addition, the Partnership will furnish a copy of any Exhibit upon payment of a fee (based on the estimated actual cost which shall be determined at the time of the request) together with a request addressed to Ian T. Bothwell, Central Energy Partners LP, 8150 N. Central Expressway, Suite 1525, Dallas, Texas 75206.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

	CENTRAL ENERGY PARTNERS LP

	By:	CENTRAL ENERGY GP LLC,
		its General Partner

November 14, 2013		By:	/s/ Imad K. Anbouba
		Imad K. Anbouba
		Chief Executive Officer and President

November 14, 2013		By:	/s/ Ian T. Bothwell
		Ian T. Bothwell
		Executive Vice-President, Chief Financial Officer, and Secretary (Principal Financial and Accounting Officer)

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