10-Q

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, 2014

OR

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

For the transition period from                                   to                                

Commission file number: 000-50394

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.)
4809 Cole Ave., Suite 108, Dallas, TX	75205
(Address of Principal Executive Offices)	(Zip Code)

Registrant's Telephone Number, Including Area Code: (214) 526-9700

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 x

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 7, 2014 was 19,591,482.

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, 2013 and September 30, 2014 (unaudited)	5
	Unaudited Consolidated Statements of Operations for the three months and nine months ended September 30, 2013 and 2014	6
	Unaudited Consolidated Statement of Partners’ Deficit for the nine months ended September 30, 2014	7
	Unaudited Consolidated Statements of Cash Flows for the nine months ended September 30, 2013 and 2014	8
	Notes to Consolidated Financial Statements (unaudited)	9
2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	22
3.	Quantitative and Qualitative Disclosures About Market Risk	30
4.	Controls and Procedures	30
PART II	OTHER INFORMATION
1.	Legal Proceedings	31
1A.	Risk Factors	31
2.	Unregistered Sales of Equity Securities and Use of Proceeds	31
3.	Defaults Upon Senior Securities	31
4.	Mine Safety Disclosures	31
5.	Other Information	31
6.	Exhibits	32
Signatures		35

1

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

The statements contained in this Quarterly Report of Central Energy Partners LP (the “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 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, 2013, 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 Douglas Weir, Central Energy Partners LP, 4809 Cole Ave., Suite 108, Dallas, Texas 75205.

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.

2

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, 2014, the unaudited consolidated statement of operations for the three months and nine months ended September 30, 2013 and 2014 and the unaudited consolidated statements of cash flows and of partners’ deficit for the nine months ended September 30, 2014. 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 inquiries 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 Accounting 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.

As indicated in Note K 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, 2014

3

Central Energy Partners LP and Subsidiaries

CONSOLIDATED BALANCE SHEETS

(Unaudited)

ASSETS

	December 31,		September 30,
	2013		2014
Current Assets
Cash	$	103,000	$	66,000
Trade accounts receivable (less allowance for doubtful accounts of $0 at 2013 and 2014)		312,000		371,000
Prepaid expenses and other current assets		427,000		200,000
Total current assets		842,000		637,000
Property, plant and equipment – net		3,158,000		3,545,000
Other assets		128,000		128,000
Goodwill		3,941,000		3,941,000
Total assets	$	8,069,000	$	8,251,000

LIABILITIES AND PARTNERS’ DEFICIT

	December 31, 2013			September 30, 2014
Current Liabilities
Current maturities of long-term debt	$	188,000		$	287,000
Accounts payable		1,418,000			1,078,000
Taxes payable		40,000			16,000
Unearned revenue		168,000			176,000
Accrued liabilities		424,000			265,000
Total current liabilities		2,238,000			1,822,000
Long-term debt obligations		2,312,000			2,213,000
Due to General Partner		3,000,000			4,177,000
Deferred income taxes		845,000			845,000
Commitments and contingencies		-			-
Partners’ deficit
Common units		(319,000	)		(789,000	)
General Partner’s deficit		(7,000	)		(17,000	)
Total partners’ deficit		(326,000	)		(806,000	)
Total liabilities and partners’ deficit	$	8,069,000		$	8,251,000

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

4

Central Energy Partners LP and Subsidiaries

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

	Three Months Ended September 30, 2013			Three Months Ended September 30, 2014			Nine Months Ended September 30, 2013			Nine Months Ended September 30, 2014
Revenues	$	1,044,000		$	1,456,000		$	3,480,000		$	4,004,000
Cost of goods sold		838,000			1,061,000			2,946,000			3,073,000
Gross profit		206,000			395,000			534,000			931,000
Selling, general and administrative expenses and other
Legal and professional fees		182,000			61,000			430,000			146,000
Salaries and payroll related expenses		180,000			141,000			633,000			478,000
Other		(211,000	)		156,000			(669,000	)		480,000
		151,000			358,000			394,000			1,104,000
Operating income (loss) from continuing operations		55,000			37,000			140,000			(173,000	)
Other expense
Interest expense, net		(106,000	)		(170,000	)		(272,000	)		(367,000	)
Loss before taxes		(51,000	)		(133,000	)		(132,000	)		(540,000	)
Provision for income taxes		(62,000	)		-			(67,000	)		-
Net Loss	$	(113,000	)	$	(133,000	)	$	(199,000	)	$	(540,000	)
Net Loss allocable to the partners	$	(113,000	)	$	(133,000	)	$	(199,000	)	$	(540,000	)
Less General Partner’s interest in net loss		(2,000	)		(3,000	)		(4,000	)		(11,000	)
Net loss allocable to the common units	$	(111,000	)	$	(130,000	)	$	(195,000	)	$	(529,000	)
Net loss per common unit	$	(0.01	)	$	(0.01	)	$	(0.01	)	$	(0.03	)
Weighted average common units outstanding		16,066,482			19,591,482			16,066,482			19,299,815

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

5

Central Energy Partners LP and Subsidiaries

CONSOLIDATED STATEMENT OF PARTNERS’ DEFICIT

(Unaudited)

	Common Units
	Units		Amount			General Partner’s Deficit			Total Partners’ Deficit
Balance as of December 31, 2013		19,066,482	$	(319,000	)	$	(7,000	)	$	(326,000	)
Unit based compensation		525,000		59,000			1,000			60,000
Net loss		-		(529,000	)		(11,000	)		(540,000	)
Balance as of September 30, 2014		19,591,482	$	(789,000	)	$	(17,000	)	$	(806,000	)

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

6

Central Energy Partners LP and Subsidiaries

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Nine Months Ended September 30,
	2013			2014
Cash flows from operating activities:
Net loss	$	(199,000	)	$	(540,000	)
Adjustments to reconcile net loss to net cash (used in) provided by operating activities:
Depreciation and amortization		402,000			413,000
Reduction in accrued tax penalties assessed		(1,119,000	)		-
Unit based compensation		16,000			60,000
Changes in current assets and liabilities:
Trade accounts receivable		286,000			(59,000	)
Prepaid and other current assets		479,000			227,000
Due to/from General Partner, net		445,000			1,177,000
Trade accounts payable		(924,000	)		(340,000	)
Unearned revenue		(33,000	)		8,000
Accrued liabilities and other		126,000			(159,000	)
U.S. and foreign taxes payable		(25,000	)		(24,000	)
Net cash provided by (used in) operating activities		(546,000	)		763,000
Cash flows from investing activities:
Capital expenditures		(6,000	)		(800,000	)
Proceeds from sale of assets		31,000			-
Net cash provided by (used in) investing activities		25,000			(800,000	)
Cash flows from financing activities:
Issuance of debt		2,500,000			-
Payment of debt		(1,970,000	)		-
Net cash provided by financing activities		530,000			-
Net (decrease) increase in cash		9,000			(37,000	)
Cash at beginning of period		22,000			103,000
Cash at end of period	$	31,000		$	66,000
Supplemental disclosures of cash flow information:
Cash paid during the year for:
Interest	$	222,000		$	240,000
Taxes	$	84,000		$	35,000

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

7

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE A –BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

Business

Central Energy Partners LP, a publicly traded Delaware limited partnership, was formed in July 2003. As used in this report, the terms “Central Energy” and “the Partnership” refer to Central Energy Partners LP, and the terms “Central,” “the Company,” “we,” “our” and “us” are used in this report to refer to Central Energy, its sole general partner Central Energy GP LLC, and its consolidated subsidiaries as a whole.

We conduct our operations through our wholly-owned subsidiary, 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 18 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 limited partnership interests in the Partnership (“Common Units”) represent 98% of the Partnership’s outstanding capital and 100% of the Partnership’s limited partnership interests. We are controlled by our general partner, Central Energy GP LLC (“General Partner”), 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 as provided in the partnership agreement. 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.

Effective November 26, 2013, CEGP Acquisition, LLC (“CEGP”) acquired 55% of the issued and outstanding membership interests in the General Partner and 3,000,000 Common Units, which represents 15% of the issued and outstanding Common Units of the Partnership (the “CEGP Investment”). CEGP appoints five (5) of the nine (9) members of the Board of Directors of the General Partner. As a result, CEGP controls the General Partner. CEGP is a Texas limited liability company controlled by John L. Denman, Jr. and G. Thomas Graves III. Upon completion of the CEGP Investment, Mr. Denman replaced Mr. Imad K. Anbouba as CEO and President of the General Partner, and Mr. Graves was appointed as the Chairman of the Board of Directors replacing Mr. Jerry V. Swank, a principal of the controlling entity of The Cushing MLP Opportunity Fund, L.P. which holds 39.1% of the Common Units of the Partnership (the “Cushing Fund”). JLD Services, Ltd., a company controlled by Mr. Denman, and Mr. Graves were each granted a Performance Warrant which, when exercised and combined with the Common Units acquired by CEGP in connection with the CEGP Investment, would represent 26.6% of the issued and outstanding Common Units of the Partnership. The Performance Warrants expire on November 25, 2014 and it is unlikely that the performance requirements will be satisfied.

Basis of Presentation

The accompanying consolidated financial statements include the Partnership and its only operating subsidiary, Regional. We have two other subsidiaries that have no operations – Rio Vista Operating Partnership, LP (“RVOP”) and Rio Vista Operating GP LLC. All significant intercompany accounts and transactions are eliminated.

The unaudited consolidated balance sheet as of September 30, 2014, the unaudited consolidated statements of operations for the three months and nine months ended September 30, 2013 and 2014 and the unaudited consolidated statements of cash flows and of partners’ deficit for the nine months ended September 30, 2014, have been prepared by us without audit. In our opinion, 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, 2014, the unaudited consolidated results of operations for the three months and nine months ended September 30, 2013 and 2014 and the unaudited consolidated statements of cash flows and of partners’ deficit for the nine months ended September 30, 2014.

8

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

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 we believe that the disclosures made are adequate to make the information not misleading. These unaudited consolidated financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2013 filed with the Securities and Exchange Commission.

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.

Use of Estimates

The preparation of financial statements in conformity with generally accepted accounting principles requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclose contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates, and such differences could be material.

Cash Equivalents

We consider all highly liquid investments with maturities of three months or less when purchased to be cash equivalents.

Financial Instruments

The fair values of our financial instruments, which may include cash, accounts receivable, accounts payable and long-term debt, approximate their carrying amounts.

Distributions of Available Cash

In March 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 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 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 General Partner for making such distributions.

Environmental Obligations

We are subject to various federal, state and local laws and regulations relating to the protection of the environment. We have established procedures for the ongoing evaluation of our operations, to identify potential environmental exposures, and to comply with regulatory policies and procedures. We account 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. We maintain insurance which may cover in whole or in part certain types of environmental contingencies. For the quarters ended September 30, 2013 and 2014, we had no environmental contingencies requiring specific disclosure or the recording of a liability.

Unit Based Compensation

We 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. We apply 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. We did not record any costs for unit-based payment costs for non-employees for the nine months ended September 30, 2013 and 2014, respectively under the fair-value provisions of ASC 505.

9

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

The Partnership applies ASC 718 for options, Common Units or other equity-based grants to our employees and directors of the General Partner. 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, we 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. We recorded $16,000 and $60,000 for unit-based payment costs for employees and directors for the nine months ended September 30, 2013 and 2014, respectively, under the fair-value provisions of ASC 718. See “Note F – Unit Options and Equity Incentive Plan – Incentive Plans” below for information regarding equity-based grants made during the nine months ended September 30, 2014.

NOTE B – PARTNERS’ DEFICIT

The number of Common Units outstanding at September 30, 2014 was 19,591,482. The Common Units represent 98% of the Partnership’s outstanding capital and 100% of the Partnership’s limited partnership interests. We are controlled by our general partner, Central Energy GP LLC, which holds a 2% interest in the Partnership. At September 30, 2014, the Partners’ deficit was $806,000, of which $17,000 is attributable to the General Partner’s interest in the Partnership.

NOTE C – Loss Per Common UNIT

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

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

10

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

	For the three months ended September 30, 2014
	(Loss) (Numerator)			Units (Denominator)		Per-Unit Amount
Net (loss) available to the Common Units	$	(130,000	)
Basic EPS
Net (loss) available to the Common Units		(130,000	)		19,591,482	$	(0.01	)
Effect of Dilutive Securities
Options		—			—
Diluted EPS
Net income available to the Common Units		N/A			N/A		N/A

	For the nine months ended September 30, 2013
	(Loss) (Numerator)			Units (Denominator)		Per-Unit 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 income available to the Common Units		N/A			N/A		N/A

	For the nine months ended September 30, 2014
	(Loss) (Numerator)			Units (Denominator)		Per-Unit Amount
Net (loss) available to the Common Units	$	(529,000	)
Basic EPS
Net (loss) available to the Common Units		(529,000	)		19,299,815	$	(0.03	)
Effect of Dilutive Securities
Options		—			—
Diluted EPS
Net (loss) available to the Common Units		N/A			N/A		N/A

Allocation of Net Income

Our net loss is allocated to partners’ capital accounts in accordance with the provisions of the partnership agreement.

11

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE D - PROPERTY, PLANT AND EQUIPMENT

	December 31, 2013			September 30, 2014
Land	$	512,000		$	512,000
Terminal and improvements		4,955,000			5,755,000
Automotive equipment		1,297,000			1,297,000
		6,764,000			7,564,000
Less: accumulated depreciation and amortization		(3,606,000	)		(4,019,000	)
	$	3,158,000		$	3,545,000

Depreciation expense of property, plant and equipment totaled $134,000 and $140,000 for the three months ended September 30, 2013 and 2014 and $402,000 and $413,000 for the nine months ended September 30, 2013 and 2014, respectively.

NOTE E — DEBT OBLIGATIONS

	December 31, 2013		September 30, 2014
Long-term debt obligations were as follows:
Hopewell Note	$	2,500,000	$	2,500,000
		-		-
		2,500,000		2,500,000
Less current portion		188,000		287,000
	$	2,312,000	$	2,213,000

Hopewell Note

On March 20, 2013, we 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”), all of which was advanced in 2013. William M. Comegys III, a member of the Board of Directors of the General Partner, is a member of Hopewell. As a result of this affiliation, the terms of the Hopewell Loan were reviewed by the Conflicts Committee of the Board of Directors of the General Partner. The committee determined that the Hopewell Loan was on terms better than could be obtained from a third-party lender.

In connection with the Hopewell Loan, we issued Hopewell a promissory note (“Hopewell Note”) along with 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, we also 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, we 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 our previous lender in the amount of $1,970,000. The remaining amounts provided under the Hopewell Loan were used for working capital.

The Hopewell Loan matures March 19, 2016 and carries a fixed annual rate of interest of 12%. Under the terms of the Hopewell Loan, as amended, we are required to make interest payments only through December 2014 and then 14 equal monthly payments of $56,000 (principal and interest) from January 2015 through February 2016 with a balloon payment of approximately $2 million due on March 19, 2016.

We are also 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 us, declare the Hopewell Note immediately due and payable. We have provided all required financial statements to Hopewell.

12

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

NOTE F – UNIT OPTIONS AND EQUITY INCENTIVE PLAN

Performance Warrants

On November 26, 2013, we issued Performance Warrants to JLD Services, Ltd., a company controlled by Mr. Jack Denman, the Chief Executive Officer and President of the General Partner, and Mr. G. Thomas Graves III, the Chairman of the General Partner, for consideration of $500 each. Each Performance Warrant, grants the holder thereof the right, but not the obligation, to acquire up to 1,500,000 Common Units at a price of $0.093478, which was the average closing bid price for a Common Unit as reported by the “Pink Sheets” published by OTC Pink for the 30-day period ended November 22, 2013, in the event the Partnership successfully completes one or more asset acquisition transactions, approved by the General Partner, with an aggregate gross purchase price of at least $20 million within 12 months after the closing of the CEGP Investment. The Performance Warrants provide certain anti-dilution protections in the event of a distribution of additional Common Units or subdivision of outstanding Common Units, a capital reorganization of the Partnership, a reclassification of the units of the Partnership, the consolidation or merger of the Partnership with or into another entity, or other similar transaction. Each holder or its assigns is granted registration rights with respect to the Common Units issuable upon exercise of a Performance Warrant. It is not anticipated that these performance milestones will be achieved prior to the expiration of the Performance Warrants.

Incentive Plans

On March 9, 2005, we established the 2005 Equity Incentive Plan of Rio Vista Energy Partners L.P. (“2005 Plan”). The 2005 Plan permits the grant of options, appreciation rights, restricted common units and phantom units of Common Units of the Partnership to any person who is an employee or director of, or consultant to, the Partnership or the General Partner or any affiliate of the Partnership (the “Partnership Entities”). The plan provides anti-dilution protection as determined by the Compensation Committee for a combination, exchange or extra-ordinary distribution of Common Units, or reorganization, recapitalization or any similar event affecting the Common Units or other securities of the Partnership. There were 750,000 Common Units authorized for issuance as awards under the 2005 Plan. The 2005 Plan remains available for the grant of awards until March 9, 2015, or such earlier date as the Board of the General Partner may determine. As the result of the grant of Common Units to non-executive directors of the General Partner as described below, there are 47,310 Common Units remaining for issuance under the 2005 Plan as of September 30, 2014.

On March 26, 2014, the Board of Directors of the General Partner authorized and approved the 2014 Long-Term Incentive Plan of Central Energy Partners, LP (“2014 Plan”). The 2014 Plan permits the grant of incentive and non-incentive Common Unit Options, Common Unit Appreciation Rights, Restricted Common Unit Grants, Common Units, Common Unit Value Equivalents and Substitute Awards to employees and directors of the Partnership Entities. The Compensation Committee may grant the recipient of an award, other than a Common Unit grant, the right to receive an amount equal to the minimum quarterly distributions associated with the Common Units which are the subject of an award. All awards, except an outright grant of Common Units, are subject to forfeiture upon termination of an executive officer, employee or director for any reason unless the Compensation Committee establishes other criteria in the award grant. The 2014 Plan provides anti-dilution protection for the recipient of an award in the case of a reorganization, combination, exchange or extra-ordinary distribution of Common Units, a merger, consolidation or combination of the Partnership with another entity, or a “change of control” of the Partnership or the General Partner. The 2014 Plan remains in effect until December 31, 2023, unless sooner terminated by the Board of Directors of the General Partner in accordance with its terms. The 2014 Plan authorizes the issuance of up to 3,300,000 Common Units, subject to amendment to increase the amount of authorized Common Units. As a result of the grant of Common Units to executive officers of the General Partner, Regional, and directors of the General Partner as summarized below, there are 1,950,000 Common Units remaining for issuance under the 2014 Plan as of September 30, 2014.

Grant of Restricted Common Unit Options to Executive Officers

On March 26, 2014, the Board of Directors of the General Partner approved the recommendation of the Board’s Compensation Committee to grant restricted Common Units (the “Restricted Units”) to the executive officers of the General Partner and Regional. The Compensation Committee finalized the terms of the Restricted Common Unit Restricted Unit Agreement, the form of which is attached to this Report (the “Restricted Unit Agreement”), and delivered such Restricted Unit Agreements to each of the executive officers on May 16, 2014, granting the number of Restricted Units as set forth in the following table:

13

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Award Recipient	Number of Restricted Units
John L. Denman, Jr.		500,000
G. Thomas Graves		300,000
Douglas W. Weir		250,000
Ian T. Bothwell		75,000
Daniel P. Matthews		75,000

The grant of the Restricted Units is made in consideration of the services to be rendered by an executive officer to the Partnership Entities. The Restricted Unit Agreement provides the award recipient the right to purchase the designated number of Common Units at an exercise price established by the final trade price of a Common Unit on the date of grant (May 16, 2014) or, if no trade occurred on the date of grant, the average bid and asked price on that date as quoted by OTC Pink. There was no trade in the Common Units on May 16, 2014, and the average bid and asked price on that date was $0.09. Each grant of Restricted Units expires on May 16, 2019.

The Restricted Units are awards of Common Units that are subject to restrictions on transferability and a substantial risk of forfeiture and are intended to retain and motivate members of management of the Partnership Entities. Award recipients have all the rights of a Unitholder in the Partnership with respect to the Restricted Units, including the right to receive distributions thereon if and when distributions are made by the Partnership to other Unitholders. The Restricted Units vest and the forfeiture restrictions lapse in substantially equal one-third (1/3) increments on each of May 16, 2015, May 16, 2016, and May 16, 2017.

If an award recipient’s service with the Partnership Entities is terminated prior to full vesting of the Restricted Units due to death or “disability” (as defined in the Restricted Unit Agreement) or if the award recipient’s employment with the Partnership Entities is terminated for “good reason” (as defined in the Restricted Unit Agreement) or by a Partnership Entity without “cause” (as defined in the Restricted Unit Agreement), then all Restricted Units will immediately vest in full as of the date of such termination. If an award recipient’s service with a Partnership Entity is terminated prior to full vesting of the Restricted Units for any other reason, then the award recipient will forfeit all unvested Restricted Units to the Partnership. In the event of an award recipient’s termination from service without “cause” or for “good reason” within two (2) years following the occurrence of a change of control, all unvested Restricted Units will become immediately vested in full. The Restricted Units are subject to anti-dilution protections as provided in the Restricted Unit Agreement. The Partnership is obligated to register the Restricted Units with the U.S. Securities and Exchange Commission (the “Commission”) pursuant to a Form S-8 registration statement.

Grant of Common Units to Directors under the 2005 Plan

At meetings held on December 19, 2013 and March 26, 2014, the Board of Directors of the General Partner approved the recommendation of its Compensation Committee to grant 375,000 Common Units to its non-executive directors under the 2005 Plan. The Compensation Committee finalized the terms of the Common Unit Grant Agreement (the “Grant Agreement”) and delivered such Grant Agreements to each of the non-executive directors on May 16, 2014, granting the number of Common Units as set forth in the following table:

Award Recipient	Number of Common Units
Alan D. Bell		75,000
Alexander C. Chae		75,000
William M. Comegys III		75,000
Robert H. Lutz		75,000
Michael T. Wilhite		75,000

14

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

The Common Units have been awarded to each of the directors for their service to the Partnership Entities in lieu of cash compensation. The Common Units awarded to each director have the value per Common Unit as established by the final trade price of a Common Unit on May 16, 2014 or, if no trade occurred on that date, the average bid and asked price on such date. The award recipient is the owner of the Common Units effective May 16, 2014 until such date as the Common Units are sold by such recipient and shall have all of the rights of a Unitholder of the Partnership. The Common Units are subject to anti-dilution protections as provided in the Restricted Unit Agreements. The Partnership is obligated to register the Common Units with the Commission pursuant to a Form S-8 registration statement.

Grant of Common Units to Directors under the 2014 Plan

On March 26, 2014, the Board of Directors of the General Partner approved the recommendation of its Compensation Committee to grant 75,000 Common Units to each of Imad K. Anbouba, a director of the General Partner and its former Chief Executive Officer, and Swank Investment Partners LP, an affiliate of The Cushing MLP Opportunity Fund I, L.P., which is the largest holder of Common Units and for which Daniel L. Spears, one of the directors of the General Partner, serves as portfolio manager. The Compensation Committee finalized the terms of the Common Unit Grant Agreements for such awards, the form of which is attached to this Report, and delivered such grant agreements to each of Mr. Anbouba and Swank Investment Partners on May 16, 2014. These grant agreements have the same terms and conditions as the Grant Agreements issued under the 2005 Plan.

Each of the 2005 Plan and the 2014 Plan are administered by the Compensation Committee of the Board. In addition, the Board may exercise any authority of the Compensation Committee under the 2005 Plan. The Compensation Committee has broad discretion in issuing awards under either plan and amending or terminating either plan. Under the terms of the Partnership Agreement, no approval of either the 2005 Plan or the 2014 Plan by the Limited Partners of the Partnership is required.

NOTE G - COMMITMENTS AND CONTINGENCIES

Legal Proceedings

We are involved with legal proceedings, lawsuits and claims in the ordinary course of our business. We believe that the liabilities, if any, ultimately resulting from such proceedings, lawsuits and claims should not materially affect its consolidated financial results.

Leases

Penske Truck Lease

Effective January 18, 2012, we entered into a Vehicle Maintenance Agreement (“Maintenance Agreement”) with Penske Truck Leasing Co., L. P. (“Penske”) for the maintenance of our 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, 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 to Penske, maintenance of Regional’s insurance obligation, or any other breach of the terms of the agreement.

15

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

On February 17, 2012, we entered into a seven-year Vehicle Lease Service Agreement with Penske for the outsourcing of 20 new Volvo tractors (“Leased Tractors”) to be acquired by Penske and leased to us for seven years, and the outsourcing of the maintenance of the Leased Tractors to Penske (“Lease Agreement”). Under the terms of the Lease Agreement, we 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 Leased Tractors in good repair and operating condition. Any replacement parts and labor for repairs which are not ordinary wear and tear are to be charged to Regional 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 has obtained all operating permits and licenses with respect to the use of the Leased Tractors by Regional. In connection with the delivery of the Leased Tractors, we sold our remaining owned tractor fleet, except for several owned tractor units which were retained to be used for terminal site logistics.

Under the terms of the Lease Agreement, Regional (i) may acquire any or all of the Leased 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 Leased Tractors 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 Leased Tractors as provided in the Lease Agreement due to a decline in Regional’s transportation business. As a result of this partial termination, Regional now operates 15 Leased Tractors pursuant to the Lease Agreement. Regional is obligated to maintain liability insurance coverage on all Leased Tractors.

NOTE H – MAJOR CUSTOMERS AND CONCENTRATIONS OF CREDIT RISK

Major Customers

For the three months ended September 30, 2014, Rubicon Energy LLC, Suffolk Sales, and MeadWestvaco Specialty Chemicals, Inc., accounted for approximately 29%, 17% and 14% of Regional’s revenues, respectively, and approximately 20%, 22% and 25% of its account receivables, respectively.

For the nine months ended September 30, 2014, Associated Asphalt Hopewell LLC, Suffolk Sales, and MeadWestvaco Specialty Chemicals, Inc., accounted for approximately 20%, 20% and 16% of Regional’s revenues, respectively, and approximately 0%, 16% and 21% of Regional’s accounts receivable, respectively.

Concentrations of Credit Risk

The balance sheet items that potentially subject us to concentrations of credit risk are primarily cash and cash equivalents and accounts receivable. We maintain 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, 2014, we did not have any cash balances in financial institutions in excess of FDIC insurance coverage. Concentrations of credit risk with our accounts receivable are mitigated by our ongoing credit evaluations of our customers.

NOTE I — INCOME TAXES

Federal Tax Liabilities

Failure to File Electronically and Delivery of Schedules K-1 to Unitholders

During November 2013, we received a notice from the IRS that we were liable for penalties (“2012 IRS Penalties”) of approximately $296,000 in connection with the late filing of the 2012 federal partnership tax return (“2012 Tax Return”) and approximately $142,000 in connection with failing to file the 2012 Tax Return electronically. We timely filed the 2012 Tax Return manually. During January 2014, we submitted an appeal to the IRS to have the 2012 IRS Penalties removed. On February 25, 2014, we received written notice from the IRS that the appeal of the late filing penalty was approved and the appeal of the failure to file the 2012 Tax Return electronically was denied. We believe that there existed reasonable cause for the Partnership’s failure to file the 2012 Tax Return electronically and we have notified the IRS that we are appealing their decision subject to the IRS completing its review of the matter, which remains pending. As of September 30, 2014, we have accrued a reserve of $142,000 in connection with the remaining 2012 IRS Penalties.

16

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

There can be no assurance that our request for relief from the remaining outstanding 2012 IRS Penalties will be approved by the IRS or that we will have adequate financial resources to pay the remaining outstanding 2012 IRS Penalties.

NOTE J — RELATED PARTY TRANSACTIONS

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

Advances from General Partner

All funds advanced to the Partnership by the General Partner since November 17, 2010 have been treated as a loan. Effective March 1, 2012, the Genreal Partner and the Partnership executed an Intercompany Demand Promissory Note to evidence the indebtedness, which note was amended during March 2014 and November 2014. The intercompany demand note provides for advances from time to time by the General Partner to the Partnership of up to $5,000,000 to fund working capital needs of the Partnership and its subsidiaries. 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 bore interest at the imputed rate of the IRS for medium-term notes. The November 2014 amendment increased the interest rate to a flat 10% per annum for all periods from and after July 1, 2014. At September 30, 2014, the total amount owed to the General Partner by the Partnership, including accrued interest, was $4,177,000.

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 order to provide 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, 2014 is $4,296,000. 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. 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, 2014, the intercompany balance owed by Regional to the Partnership and/or RVOP is approximately $2,957,000, which includes interest. This amount is due to the Partnership and RVOP on demand; however, as is the case with the Central Promissory Note, payment of these amounts is also subordinated to payment of the Hopewell Note by Regional.

Allocated Expenses Charged to Subsidiary

Regional is charged for direct expenses paid by the Partnership on its behalf, as well as its share of allocable overhead for expenses incurred by the Partnership which are indirectly attributable to Regional related activities. For the three months and nine months ended September 30, 2013 and 2014, Regional recorded allocable expenses of $64,000, $45,000, $177,000 and $165,000, respectively.

17

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

Reimbursement Agreements

Effective December 31, 2013, in connection with the CEGP Investment and the resulting change in control of the General Partner, the Partnership moved its principal executive offices to another office location within Dallas, Texas that is leased from Katy Resources LLC (“Katy”), an entity controlled by G. Thomas Graves III, the Chairman of the Board of the General Partner. As a result, we entered into a new reimbursement agreement with Katy on a month-to-month basis for reimbursement of allocable “overhead costs” 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 Senior Vice President 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. In connection with the CEGP Investment, the Partnership reimbursed Rover Technologies LLC for the outstanding unpaid overhead costs as of the date of the CEGP Investment. For the three months and nine months ended September 30, 2013 and 2014, expenses billed in connection with the reimbursement agreements were $12,000, $12,000, $42,000 and $47,000, respectively.

NOTE K — REALIZATION OF ASSETS

Our unaudited consolidated balance sheets have been prepared in conformity with accounting principles generally accepted in the United States of America, which contemplate our continuation as a going concern. We had a loss from operations for the year ended December 31, 2013 and the nine months ended September 30, 2014 of $521,000 and $540,000, respectively.

During the period since December 31, 2012, we improved our overall liquidity. Our deficit in working capital, excluding current maturities of long-term debt, totaled $898,000 at September 30, 2014 compared with $3,163,000 at December 31, 2012, a reduction of $2,265,000. In addition, we were successful in reducing our obligations owing under the Penske Lease Agreement and extending the interest only payment period under the Hopewell Loan Agreement. During 2013, we also satisfactorily resolved the TransMontaigne Dispute, the contingencies associated with the late filing tax matters, and paid down and/or obtained payment arrangements with critical accounts payable vendors.

During November 2013, we completed the CEGP Investment, which provided working capital of $2.75 million to the General Partner and Central Energy. We also recently amended the note agreement with the General Partner which provides for an increase in the amount of advances from the General Partner from $2.0 million to $4.0 million.

At September 30, 2014, we had cash available to fund ongoing working capital requirements of $66,000. In August 2014, the Board of Directors of the General Partner recommended a capital call of $750,000 to fund working capital needs. This recommendation was approved by the requisite percentage of members on August 7, 2014. As of November 14, 2014, the capital call was fully subscribed and funded. We anticipate that this amount, together with cash flow from operations, will be sufficient to meet the Company’s working capital requirements for approximately 12 months.

In connection with the Hopewell Note, Regional is currently required to make interest payments only of $25,000 per month until December 2014 and then equal monthly payments of $56,000 (principal and interest) each month thereafter until March 2016 at which time a balloon payment of approximately $2 million will be due. Regional also is required to make minimum monthly payments under the Penske Lease Agreement of approximately $30,000 until May 2019. Payments under the Hopewell Note and the Penske Lease Agreement could be accelerated in the event of a default. The amount of penalties related to the remaining 2012 Tax Return is $142,000 and will be required to be paid if our appeal is unsuccessful. Since the closing of the CEGP Investment, Messrs. Denman, Graves and Weir have agreed to forego receipt of any compensation as a result of concerns over available cash resources.

Substantially all of our assets are pledged as collateral for the Hopewell Loan, and therefore, we are unable to obtain additional financing collateralized by those assets without repayment of the Hopewell Loan. In addition, we have obligations under existing registrations rights agreements. These rights may be a deterrent to any future equity financings.

18

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

In view of the matters described in the preceding paragraphs, recoverability of the recorded asset amounts shown in the accompanying consolidated balance sheet assumes that: (1) we do not experience any significant disruptions in storage revenues resulting from the timing of termination of storage tank lease agreements and identifying replacement customers and/or disruptions resulting from the performance of maintenance on our facilities; (2) our hauling revenues remain at current levels; (3) obligations to creditors are not accelerated; (4) our pending facility upgrades are completed timely and within estimated budgets; (5) our operating expenses remain at current levels; (6) we obtain additional working capital to meet our contractual commitments through future intercompany advances or a refinancing of the Hopewell Loan; and/or (7) the Partnership is able to receive future distributions from Regional or future advances from the General Partner in amounts necessary to fund working capital until an acquisition transaction is completed by the Partnership.

There is no assurance that we will have sufficient working capital to cover ongoing cash requirements for the period of time we believe is necessary to complete an acquisition that will provide additional working capital for us. If we do not have sufficient cash reserves, our ability to pursue additional acquisition transactions will be adversely impacted. Furthermore, despite significant effort, we have thus far been unsuccessful in completing an acquisition transaction. There can be no assurance that we 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, we 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.

It is our intention to acquire additional assets during 2015 on terms that will enable us to expand our assets and generate additional cash from operations. We are also seeking to obtain additional funding through a refinancing of the Hopewell Loan or from an alternative funding transaction. The accompanying 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 we be unable to obtain adequate funding to maintain operations and to continue in existence.

NOTE L - 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 M - SEGMENT INFORMATION

We report 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. We had only one operating segment (the transportation and terminaling business of Regional) during the three months and nine months ended September, 2013 and 2014.

The following are amounts related to the Regional transportation and terminaling business included in the accompanying consolidated financial statements for the three months and nine months ended September 30, 2013 and 2014 and at December 31, 2013 and September 30, 2014:

19

CENTRAL ENERGY PARTNERS LP AND SUBIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

	Three months ended September 30, 2013			Three months ended September 30, 2014			Nine months ended September 30, 2013			Nine months ended September 30, 2014
Revenue from external customers	$	1,044,000		$	1,456,000		$	3,480,000		$	4,003,000
Interest expense		99,000			202,000			257,000			539,000
Depreciation and amortization		134,000			140,000			402,000			413,000
Income tax expense (benefit)		(62,000	)		-			67,000			-
Net (loss)	$	(256,000	)	$	(203,000	)	$	(879,000	)	$	(356,000	)

	December 31, 2013		September 30, 2014
Total assets	$	8,069,000	$	8,218,000

20

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

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

Current Assets and Operations

Regional

On July 27 2007, we 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. 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 18 rail cars at any one time for the trans-loading of chemical and petroleum liquids. In addition to its facility-based services, 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.

Prior to March 31, 2013, Regional also operated a trans-loading facility in Johnson City, Tennessee, with 6 rail car slots. This facility was closed effective March 31, 2013 due to Regional’s sole customer for this facility not renewing 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’s revenues for the three months and nine months ended September 30, 2013 and 2014 were divided as set forth below. All dollar amounts are in thousands.

	Three Months Ended September 30,
	2013					2014
	Revenue		%			Revenue		%
Hauling	$	498		48	%	$	744		51	%
Storage		446		43	%		606		42	%
Terminal		95		9	%		106		7	%
Other		5		0	%		-		0	%
Total	$	1,044		100	%	$	1,456		100	%

	Nine Months Ended September 30,
	2013					2014
	Revenue		%			Revenue		%
Hauling	$	1,841		53	%	$	1,764		44	%
Storage		1,329		38	%		1,656		41	%
Terminal		294		8	%		584		15	%
Other		16		1	%		-		0	%
Total	$	3,480		100	%	$	4,004		100	%

21

Recent Developments

Executive Officers

Effective May 1, 2014, Mr. Douglas W. Weir was appointed Chief Financial Officer and Chief Accounting Officer of the General Partner. Ian T. Bothwell was appointed as Senior Vice President of the General Partner and President of Regional in recognition of Mr. Bothwell’s new focus on identifying potential asset investment opportunities for the Partnership and growing and expanding Regional’s existing business.

Results of Operations

The unaudited consolidated results of operations from continuing operations during the three months ended September 30, 2013 and 2014, 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, 2014 and 2013 (all amounts in thousands)

																			Change Three Months Ended
	Three Months Ended									Three Months Ended									September 30, 2014 versus
	September 30, 2014									September 30, 2013									September 30, 2013
	Regional			Corporate			Total			Regional			Corporate			Total			Regional			Corporate			Total
Revenues	$	1,456		$	-		$	1,456		$	1,044		$	-		$	1,044		$	412		$	-		$	412
Costs Of Goods Sold		1,061			-			1,061			838			-			838			223			-			223
Gross Profit		395			-			395			206			-			206			189			-			189
Selling, General and Administrative Expenses		267			91			358			300			(149	)		151			(33	)		240			207
Operating Income (Loss)		128			(91	)		37			(94	)		149			55			222			(240	)		(18	)
Interest Expense, net		(67	)		(103	)		(170	)		(99	)		(7	)		(106	)		32			(96	)		(64	)
Income (Loss)  Before Taxes		61			(194	)		(133	)		(193	)		142			(51	)		254			(336	)		(82	)
Provision (Benefit) For Income Taxes		-			-			-			62			-			62			(62	)		-			(62	)
Net Income (Loss)	$	61		$	(194	)	$	(133	)	$	(255	)	$	142		$	(113	)	$	316		$	(336	)	$	(20	)

Revenues. Our revenues for the three months ended September 30, 2014 increased by $0.412 million over the revenues for the three months ended September 30, 2013. The increase was due to adding a new customer in May that has taken Regional to full capacity for the entire quarter.

Cost of Goods Sold. Our cost of goods sold for the three months ended September 30, 2014 increased by 27% from the same period in 2013, but was still accretive to the profit margin relative to the revenue added. The increase was entirely due to being at full capacity. The resulting gross profit margin increased to 27% for the 2014 quarter versus 20% for the 2013 quarter.

Selling, General and Administrative Expenses. Selling, general and administrative expenses (“SG&A”) during the three months ended September 30, 2014 were $0.358 million compared to $0.151 million for the three months ended September 30, 2013, an increase of approximately $0.2 million (137%). The increase was the result of recording $0.3 million for the abatement of California tax penalties during the three months ended September 30, 2013. Disregarding the effect of the abatement, overall SG&A decreased by $0.1 million during the same period.

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Nine Months Ended September 30, 2014 and 2013 (all amounts in thousands)

																			Change Nine Months Ended
	Nine Months Ended									Nine Months Ended									September 30, 2014 versus
	September 30, 2014									September 30, 2013									September 30, 2013
	Regional			Corporate			Total			Regional			Corporate			Total			Regional			Corporate			Total
Revenues	$	4,004		$	-		$	4,004		$	3,480		$	-		$	3,480		$	524		$	-		$	524
Costs Of Goods Sold		3,073			-			3,073			2,946			-			2,946			127			-			127
Gross Profit		931			-			931			534			-			534			397			-			397
Selling, General and Administrative Expenses		792			312			1,104			1,088			(694	)		394			(296	)		1,006			710
Operating Income (Loss)		139			(312	)		(173	)		(554	)		694			140			693			(1,006	)		(313	)
Interest Expense, net		(231	)		(136	)		(367	)		(257	)		(15	)		(272	)		26			(121	)		(95	)
Income (Loss)  Before Taxes		(92	)		(448	)		(540	)		(811	)		679			(132	)		719			(1,127	)		(408	)
Provision (Benefit) For Income Taxes		-			-			-			67			-			67			(67	)		-			(67	)
Net Income (Loss)	$	(92	)	$	(448	)	$	(540	)	$	(878	)	$	679		$	(199	)	$	786		$	(1,127	)	$	(341	)

Revenues. Our revenues for the nine months ended September 30, 2014 increased by $0.524 million over the revenues for the nine months ended September 30, 2013. The increase was due to adding a new customer in May that has taken Regional to full capacity.

Cost of Goods Sold. Our cost of goods sold for the nine months ended September 30, 2014 increased by 4.3% from 2013. The increase was very low relative to the revenue that was added for the year.

Selling, General and Administrative Expenses. SG&A during the nine months ended September 30, 2014 was $1.104 million compared to $0.394 million for the nine months ended September 30, 2013, an increase of approximately $0.7 million. The increase was mainly the result of the abatement of tax penalties during the nine months ended September 30, 2013 totaling $1.1 million. Recurring SG&A actually decreased by nearly $0.4 million in 2014 as compared to 2013.

Liquidity and Capital Resources

On November 26, 2013 (“Closing”), the Partnership, the General Partner and CEGP Acquisition, LLC (“CEGP”) executed a definitive Purchase and Sale Agreement (“PSA”) and certain other transaction documents (“Other Transaction Documents”) providing for the sale of a 55% interest in the General Partner to CEGP through the purchase of newly issued membership interests of the General Partner by CEGP and the issuance of 3,000,000 Common Units to CEGP for $2,750,000 (the “Purchase Price”), In addition, the Partnership issued performance warrants for $500 each to affiliates of CEGP that provide the holders thereof with the opportunity, but not the obligation, to acquire, in the aggregate, an additional 3,000,000 Common Units at an exercise price of $0.093478, subject to adjustment, in the event the Partnership successfully completes one or more asset acquisition transactions with an aggregate gross purchase price of at least $20 million within 12 months after Closing (“Performance Warrants”). In connection with the purchase of the equity securities by CEGP and the issuance of the Performance Warrants, the Partnership amended and restated (1) its Registration Rights Agreement to include the Common Units purchased by CEGP and issuable upon exercise of the Performance Warrants. (2) the General Partner Company Agreement, and Partnership Agreement, copies of which have been filed as exhibits to this report. At the Closing, net proceeds of $2,350,000 (“Net Proceeds”) were delivered to the General Partner and the Partnership (the Purchase Price less credits for prior payments of $400,000 made to the General Partner in connection with stand-still agreements in place until the execution of the PSA) (“Stand-Still Payments”). Of the total Purchase Price, the amount of $280,434 was allocated to the price paid for the 3,000,000 Common Units. CEGP paid $240,434 to the Partnership at Closing from the Net Proceeds, with the $40,000 balance of the purchase price for the 3,000,000 Common Units being a portion of the Stand-Still Payments. The remaining amount of the Purchase Price, or $2,469,566, was allocated to the value of the 55% Membership Interest of the General Partner, represented by 136,888.89 Units issued to CEGP, and $2,109,566 was paid to the General Partner at Closing from the Net Proceeds with the balance of $360,000 being the attributed portion of the Stand-Still Payments.

With the completion of the CEGP Investment, CEGP now holds 55% of the issued and outstanding membership interests in the General Partner, and appoints five (5) of the nine (9) members of the Board of the General Partner. As a result, CEGP controls the General Partner. In addition, CEGP holds 3,000,000 Common Units, which represent 15.7% of the issued and outstanding Common Units of the Partnership. Prior to execution of the PSA, Messrs. Imad K. Anbouba and Carter R. Montgomery and The Cushing MLP Opportunity Fund I, L. P. (the “Cushing Fund”) controlled the General Partner and had controlling authority over the Partnership. CEGP is a newly-formed Texas limited liability company controlled by John L. Denman, Jr. and G. Thomas Graves III. Upon completion of the CEGP Investment, Mr. Denman replaced Mr. Anbouba as CEO and President of the General Partner and Mr. Graves was appointed as the Chairman of the Board replacing Mr. Jerry V. Swank. JLD Services, Ltd., a company controlled by Mr. Denman, and Mr. Graves were each granted a Performance Warrant. Assuming exercise of the Performance Warrants, Messrs. Denman and Graves would be deemed the beneficial owners of 27.1% of the issued and outstanding Common Units of the Partnership.

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At September 30, 2014, we had cash available to fund ongoing working capital requirements of $66,000. In August 2014, the Board of Directors of the General Partner recommended a capital call of $750,000 to fund working capital needs. This recommendation was approved by the requisite percentage of members on August 7, 2014. As of November 14, 2014, the capital call was fully subscribed and funded. With the capital call completed, CEGP continues to hold 55% of the issued and outstanding membership interests in the General Partner. The Cushing Fund and Messrs. Anbouba and Montgomery hold 15.90%, 11.28% and 11.28%, respectively.

Tax Liabilities

Failure to File Electronically and Delivery of Schedules K-1 to Unitholders

During November 2013, we received a notice from the IRS that we were liable for penalties (“2012 IRS Penalties”) of approximately $296,000 in connection with the late filing of the 2012 federal partnership tax return (“2012 Tax Return”), and approximately $142,000 in connection with failing to file the 2012 Tax Return electronically. We timely filed the 2012 Tax Return with the IRS manually. During January 2014, we submitted an appeal to the IRS to have the 2012 IRS Penalties removed. On February 25, 2014, we received written notice from the IRS that the appeal of the late filing penalty was approved, and the appeal of the failure to file the 2012 Tax Return electronically was denied. We believe that there existed reasonable cause for the Partnership’s failure to file the 2012 Tax Return electronically and as a result we intend to appeal the decision to deny. During the year ended December 31, 2013, we accrued a reserve of $142,000 in connection with the remaining 2012 IRS Penalties. There can be no assurance that our request for relief from the remaining outstanding 2012 IRS Penalties will be approved by the IRS or that we will have adequate financial resources to pay the remaining outstanding 2012 IRS Penalties.

Disputes

We may be involved with other proceedings, lawsuits and claims in the ordinary course of its business. We believe that the liabilities, if any, ultimately resulting from such proceedings, lawsuits and claims should not materially affect our consolidated financial results.

Debt Obligations

Hopewell Note

On March 20, 2013, we 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”), all of which was advanced in 2013. William M. Comegys III, a member of the Board of Directors of the General Partner, is a member of Hopewell. As a result of this affiliation, the terms of the Hopewell Loan were reviewed by the Conflicts Committee of the Board of Directors of the General Partner. The committee determined that the Hopewell Loan was on terms better than could be obtained from a third-party lender.

In connection with the Hopewell Loan, we issued Hopewell a promissory note (“Hopewell Note”) along with 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, we also 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, we 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 our previous lender. The remaining amounts provided under the Hopewell Loan were used for working capital.

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The Hopewell Loan matures in March 19, 2016 and carries a fixed annual rate of interest of 12%. Under the terms of the Hopewell Loan, as amended, we are required to make interest payments only through December 2014 and then 14 equal monthly payments of $56,000 (principal and interest) from January 2015 through the February 2016 with a balloon payment of approximately $2 million due on March 19, 2016.

We are also 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 us, declare the Hopewell Note immediately due and payable. We have provided all required financial statements to Hopewell.

Advances from General Partner

All funds advanced to the Partnership by the General Partner since November 17, 2010 have been treated as a loan. Effective March 1, 2012, the Genreal Partner and the Partnership executed an Intercompany Demand Promissory Note to evidence the indebtedness, which note was amended during March 2014 and November 2014. The intercompany demand note provides for advances from time to time by the General Partner to the Partnership of up to $5,000,000 to fund working capital needs of the Partnership and its subsidiaries. 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 bore interest at the imputed rate of the IRS for medium-term notes. The November 2014 amendment increased the interest rate to a flat 10% per annum for all periods from and after July 1, 2014. At September 30, 2014, the total amount owed to the General Partner by the Partnership, including accrued interest, was $4,177,000.

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 order to provide 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, 2014 is $4,296,000. 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. 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, 2014, the intercompany balance owed by Regional to the Partnership and/or RVOP is approximately $2,957,000, 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

Tank Storage and Terminal Services Agreement

Regional currently has approximately 10 million gallons of storage capacity at its Hopewell facility, all of which were leased at September 30, 2014. All of our tanks are under contract with expiration dates ranging from ten months to three years from September 30, 2014. We expect to renew each contract on or before expiration; however there are no assurances that we will be successful.

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Equipment Leases

Effective January 18, 2012, we entered into a Vehicle Maintenance Agreement (“Maintenance Agreement”) with Penske Truck Leasing Co., L. P. (“Penske”) for the maintenance of our 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, 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, we entered into a seven-year Vehicle Lease Service Agreement with Penske for the outsourcing of 20 new Volvo tractors (“Leased Tractors”) to be acquired by Penske and leased to us for seven years, and the outsourcing of the maintenance of the Leased Tractors to Penske (“Lease Agreement”). Under the terms of the Lease Agreement, we 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 Leased 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 Leased Tractors by Regional. In connection with the delivery of the Leased Tractors, we sold our remaining owned tractor fleet, except for several owned tractor units which were retained to be used for terminal site logistics.

Under the terms of the Lease Agreement, Regional (i) may acquire any or all of the Leased 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 Leased Tractors 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 Leased Tractors as provided in the Lease Agreement due to a decline in Regional’s transportation business. As a result of this partial termination, Regional now leases 15 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.

Reimbursement Agreements

Effective December 31, 2013, in connection with the CEGP Investment and the resulting change in control of the General Partner, the Partnership moved its principal executive offices to another office location within Dallas, Texas that is leased from Katy Resources LLC (“Katy”), an entity controlled by G. Thomas Graves III, the Chairman of the Board of the General Partner. As a result, we entered into a new reimbursement agreement with Katy on a month-to-month basis for reimbursement of allocable “overhead costs” 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 Senior Vice President 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. In connection with the CEGP Investment, the Partnership reimbursed Rover Technologies LLC for the outstanding unpaid overhead costs as of the date of the CEGP Investment. For the three months and nine months ended September 30, 2013 and 2014, expenses billed in connection with the reimbursement agreements were $12,000, $12,000, $42,000 and $47,000, respectively.

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 to Regional related activities. For the three months and nine months ended September 30, 2013 and 2014, Regional recorded allocable expenses of $64,000, $45,000, $177,000 and $165,000, respectively.

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Registration Rights Agreements

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 Common Units of the Partnership. On May 26, 2011, Central Energy, LP distributed 12,724,019 Common Units to its limited partners pursuant to the terms of the Central Energy, LP partnership agreement. As a result, Central Energy, LP no longer holds any Common Units of the Partnership. The limited partners of Central Energy, LP, which are also the members of the General Partner, are referred to herein as the “Purchasers.”

The Registration Rights Agreement provides the Purchasers with shelf registration rights and piggyback registration rights, with certain restrictions, with respect to the Common Units held by them (“Registrable Securities”). The Partnership is required to file a shelf registration statement with the SEC on behalf of the Purchasers as soon as practicable after April 15, 2012 and maintain an effective shelf registration statement 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.

In connection with the CEGP Investment, CEGP and each of the Warrant Purchasers were added as a Holder of Registrable Securities to the Registration Rights Agreement. In order to include CEGP and the Warrant Purchasers as parties to the Registration Rights Agreement, the parties agreed to amend and restate the Registration Rights Agreement in its entirety. The Amended and Restated Registration Rights Agreement (“Registration Rights Agreement”) was approved by more than the needed majority of the parties to the agreement on November 20, 2013, and Registration Rights Agreement became effective upon its execution by all parties on November 26, 2013. The major changes incorporated into the Registration Rights Agreement include the following:

· The holders of Registrable Securities were redefined to include CEGP, each Warrant Purchaser and the members of the General Partner holding Common Units.

· The holders were granted two demand registration rights, with certain restrictions, and piggyback registration rights with respect to Common Units held by each of them.

· The Partnership is required to file a shelf registration statement with the SEC on behalf of the holders within 180 days after it becomes eligible to use Form S-3 and maintain as effective such shelf registration statement 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) three years from the date on which the shelf registration statement was first filed. At the present time the Partnership is not eligible to file a registration statement using Form S-3 since its market capitalization does not meet the threshold established by the SEC.

· The demand registration rights permit the holders of at least 3,000,000 of the Registrable Securities to demand that the Partnership file a registration statement to register such holders’ Registrable Securities and those of all other holders who elect to sell Registrable Securities, subject to certain conditions including the right of the Partnership to postpone a demand registration in the event that such demand would (i) materially interfere with a significant acquisition, merger, consolidation or reorganization involving the Partnership, (ii) require the premature disclosure of material information regarding the Registrant, or (iii) render the Partnership unable to comply with requirements of the Securities Act or the Exchange Act of 1934 and the rules and regulations promulgated thereunder. The piggyback registration rights permit a holder to elect to participate in an underwritten offering of the Partnership’s Common Units or other registrable securities. The amount of Registrable Securities that the holders can offer for sale in a piggyback registration is subject to certain restrictions as set forth in the Registration Rights Agreement.

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We are 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. We are 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 us 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 our current financial condition, as well as the current bid/ask price of the Common Units, we do not anticipate filing the shelf registration statement for the foreseeable future. We will seek to amend the Registration Rights Agreement to extend such filing requirement to a later date.

Realization of Assets

Our unaudited consolidated balance sheets have been prepared in conformity with accounting principles generally accepted in the United States of America, which contemplate our continuation as a going concern. We had a loss from operations for the year ended December 31, 2013 and the nine months ended September 30, 2014 of $521,000 and $540,000, respectively.

During the period since December 31, 2012, we improved our overall liquidity. Our deficit in working capital, excluding current maturities of long-term debt, totaled $898,000 at September 30, 2014 compared with $3,163,000 at December 31, 2012, a reduction of $2,265,000. In addition, we were successful in reducing our obligations owing under the Penske Lease Agreement and extending the interest only payment period under the Hopewell Loan Agreement. During 2013, we also satisfactorily resolved the TransMontaigne Dispute, the contingencies associated with the late filing tax matters, and paid down and/or obtained payment arrangements with critical accounts payable vendors.

During November 2013, we completed the CEGP Investment, which provided working capital of $2.75 million to the General Partner and Central Energy. We also recently amended the note agreement with the General Partner which provides for an increase in the amount of advances from the General Partner from $2.0 million to $4.0 million and extends the commencement date for amortization of the note with the General Partner to the quarter ended March 2017.

At September 30, 2014, we had cash available to fund ongoing working capital requirements of $66,000. In August 2014, the Board of Directors of the General Partner recommended a capital call of $750,000 to fund working capital needs. This recommendation was approved by the requisite percentage of members on August 7, 2014. As of November 14, 2014, the capital call was fully subscribed and funded. We anticipate that this amount, together with cash flow from operations, will be sufficient to meet the Company’s working capital requirements for approximately 12 months.

In connection with the Hopewell Note, Regional is currently required to make interest payments only of $25,000 per month until December 2014 and then equal monthly payments of $56,000 (principal and interest) each month thereafter until March 2016 at which time a balloon payment of approximately $2 million will be due. Regional also is required to make minimum monthly payments under the Penske Lease Agreement of approximately $30,000 until May 2019. Payments under the Hopewell Note and the Penske Lease Agreement could be accelerated in the event of a default. The amount of penalties related to the remaining 2012 Tax Return is $142,000 and will be required to be paid if our appeal is unsuccessful. Since the closing of the CEGP Investment, Messrs. Denman, Graves and Weir have agreed to forego receipt of any compensation as a result of concerns over available cash resources.

Substantially all of our assets are pledged as collateral for the Hopewell Loan, and therefore, we are unable to obtain additional financing collateralized by those assets without repayment of the Hopewell Loan. In addition, we have obligations under existing registrations rights agreements. These rights may be a deterrent to any future equity financings.

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In view of the matters described in the preceding paragraphs, recoverability of the recorded asset amounts shown in the accompanying consolidated balance sheet assumes that: (1) we do not experience any significant disruptions in storage revenues resulting from the timing of termination of storage tank lease agreements and identifying replacement customers and/or disruptions resulting from the performance of maintenance on our facilities; (2) our hauling revenues remain at current levels; (3) obligations to creditors are not accelerated; (4) our pending facility upgrades are completed timely and within estimated budgets; (5) our operating expenses remain at current levels; (6) we obtain additional working capital to meet our contractual commitments through future intercompany advances or a refinancing of the Hopewell Loan; and/or (7) the Partnership is able to receive future distributions from Regional or future advances from the General Partner in amounts necessary to fund working capital until an acquisition transaction is completed by the Partnership.

There is no assurance that we will have sufficient working capital to cover ongoing cash requirements for the period of time we believe is necessary to complete an acquisition that will provide additional working capital for us. If we do not have sufficient cash reserves, our ability to pursue additional acquisition transactions will be adversely impacted. Furthermore, despite significant effort, we have thus far been unsuccessful in completing an acquisition transaction. There can be no assurance that we 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, we 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.

It is our intention to acquire additional assets during 2015 on terms that will enable us to expand our assets and generate additional cash from operations. We are also seeking to obtain additional funding through a refinancing of the Hopewell Loan or from an alternative funding transaction. The accompanying 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 we be unable to obtain adequate funding to maintain operations and to continue in existence.

Off-Balance Sheet Arrangements

We 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

Our unaudited consolidated financial statements reflect the selection and application of accounting policies which require us to make significant estimates and judgments. See note B to our audited consolidated financial statements included in our Annual Report on Form 10-K for the fiscal year ended December 31, 2013, “Summary of Significant Accounting Policies”.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

Not applicable.

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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 our assessment and those criteria, we concluded that Central’s disclosure controls and procedures over financial reporting were not effective as of September 30, 2014.

Changes in Internal Control Over Financial Reporting

As of the end of the period covered by this report, there were no changes in our internal controls over financial reporting, or in other factors that could significantly affect these controls, that materially affected, or are reasonably likely to affect, our internal control over financial reporting.

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

Not applicable.

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

See “Note F – Unit Options and Equity Incentive Plan” to the unaudited consolidated financial statements included in this report for a more detailed discussion of the issuance of Common Unit Options and Common Unit Grants issued by the Company to its employees and directors.

In August 2014, the Board of Directors of the General Partner recommended a capital call of $750,000 to fund working capital needs. This recommendation was approved by the requisite percentage of members on August 7, 2014 pursuant to the terms of the General Partner’s company agreement. On September 8, 2014, the General Partners offered 15,000 membership interests at a value of $50.00 per interest to each of its members in accordance with the provisions of its company agreement. As of November 3, 2014, the offered membership interests were fully subscribed. The offer of the membership interests was made in accordance with Section 4(2) of the Securities Act of 1933, as amended, and Regulation D. No broker was involved in the transaction.

Item 3. Defaults upon Senior Securities

Not applicable.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

At its quarterly meeting held on November 11, 2014, the Board of Directors of the General Partner reconstituted its Audit Committee and its Compensation Committee. Mr. Robert L. Lutz agreed to serve on the Audit Committee to replace Mr. William M. Comegys III, who agreed to serve as Chairman and a member of the Compensation Committee. The Board has determined that each of Messrs. Lutz and Comegys are “independent” directors and each meet the respective requirements of Section 10A(3) and Section 10C of the Securities Exchange Act of 1934 and the rules and regulations promulgated thereunder and is qualified to act in their respective positions. As a result of these actions, the members of the Audit Committee include Messrs. Alan D. Bell (Chairman), Robert L. Lutz and Michael T. Wilhite. The members of the Compensation Committee are Messrs. Alan D. Bell, William M. Comegys III (Chairman), Daniel L Spears and Michael T. Wilhite, Jr.

30

Item 6. Exhibits

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

Exhibit No.	Description
2.1	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.)
2.2	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.)
2.3	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	Third Amended and Restated Agreement of Limited Partnership of Central Energy Partners LP dated November 26, 2013. (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on December 2, 2013, SEC File No. 000-50394.)
3.2	Third Amended and Restated Limited Liability Company Agreement of Central Energy GP LLC dated November 26, 2013. (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on December 2, 2013, SEC File No. 000-50394.)
4.1	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.)
4.2	Amended and Restated Registration Rights Agreement by and among Central Energy Partners LP, the Group I Investors, CEGP Acquisition, LLC, JLD Investors, Ltd, and G. Thomas Graves III, dated November 26, 2013. (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on December 2, 2013, SEC File No. 000-50394.)
4.3	Warrant Agreement issued by Central Energy Partners LP to JLD Services, Ltd. dated November 26, 2013. (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on December 2, 2013, SEC File No. 000-50394.)
4.4	Warrant Agreement issued by Central Energy Partners LP to G. Thomas Graves III dated November 26, 2013. (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on December 2, 2013, SEC File No. 000-50394.)
10.1*	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).
10.2	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.)

31

Exhibit No.	Description
10.3	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.)
10.4	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.)
10.5	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.)
10.6	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.)
10.7	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.)
10.8	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.)
10.9	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.)
10.10	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.)
10.11	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.)
10.12	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.)
10.13	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.)
10.14*	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.)

32

Exhibit No.	Description
10.15	Purchase and Sale Agreement by and among Central Energy GP LLC, Central Energy Partners LP and CEGP Acquisition, LLC, dated November 26, 2013. (Incorporated by reference to the Partnership’s Current Report on Form 8-K filed on December 2, 2013, SEC File No. 000-50394.)
10.16*	Central Energy Partners LP 2014 Incentive Compensation Plan of the Registrant. (Incorporated by reference to the Partnership’s Annual Report on Form 10-K filed on April 15, 2014, SEC File No. 000-50394).
10.17	Amended and Restated Intercompany Demand Promissory Note dated March 15, 2014. (Incorporated by reference to the Partnership’s Annual Report on Form 10-K filed on April 15, 2014, SEC File No. 000-50394).
10.18	Reimbursement Agreement effective December 1, 2013 by and between Central Energy GP LLC and Katy Resources, L.L.C. (Incorporated by reference to the Partnership’s Quarterly Report on Form 10-Q filed on May 15, 2014, SEC File No. 000-50394).
10.19*	First Amendment to Employment Agreement of Ian T. Bothwell effective December 19, 2013. (Incorporated by reference to the Partnership’s Quarterly Report on Form 10-Q filed on May 15, 2014, 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
10.20	Second Amended and Restated Intercompany Demand Promissory Note dated November 11, 2014
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 Douglas Weir, Central Energy Partners LP, 4809 Cole Ave., Suite 108, Dallas, Texas 75205.

33

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, 2014		By:	/s/ John L. Denman, Jr.
		John L. Denman, Jr.
		Chief Executive Officer and President
November 14, 2014		By:	/s/ Douglas W. Weir
		Douglas W. Weir
		Chief Financial Officer (Principal Financial and Accounting Officer)

34

EX-10.20

EXHIBIT 10.20

SECOND AMENDED AND RESTATED INTERCOMPANY DEMAND PROMISSORY NOTE

$5,000,000 Dated:  November 11, 2014

FOR VALUE RECEIVED, the undersigned, Central Energy Partners LP, a Delaware limited partnership (“Borrower”), HEREBY PROMISES TO PAY to the order of Central Energy GP LLC, a Delaware limited liability company (“Lender”), the principal amount of $5,000,000 or, if less, the aggregate principal amount of all advances heretofore and hereafter made by Lender to Borrower as evidenced by the endorsement of such Advances on Schedule A hereto or in the books and records of Borrower (the “Advances”), which is deemed a part of this Promissory Note, commencing with the quarter ended March 31, 2017 (the “Termination Date”) in twelve (12) substantially equal consecutive quarterly installments on the last day of June, September, December and March in each year commencing on January 1, 2017 and ending on March 31, 2020; provided, that the last such installment shall be in the amount necessary to repay in full the outstanding principal amount hereof, together with interest on the principal amount hereof from time to time outstanding from the date hereof until such principal amount is paid in full.

Interest shall accumulate and be calculated daily on the basis of a 360-day year at a rate per annum, compounded quarterly, at the rate of ten percent (10%) per annum. Interest shall accumulate until payment of such accumulated and unpaid interest becomes due commencing on the first day immediately after the Termination Date and payable on each of the dates principal payments are due as set forth above, with the last payment including that amount of interest due on the remaining outstanding principal amount at March 31, 2020.

Both principal and interest are payable in lawful money of the United States of America to Lender at 4809 Cole Avenue, Suite 108, Dallas, Texas 75205, or such other address as Lender shall notify Borrower, in same day funds. All Advances made by Lender to Borrower, and all payments made on account of the principal amount hereof, shall be recorded by Lender on Schedule A hereto which is part of this Amended and Restated Intercompany Demand Promissory Note (“Promissory Note”) for all purposes. The failure to show any such Advances or any error in showing such Advances shall not affect the obligations of Borrower hereunder.

Borrower may, upon at least three (3) Business Days’ notice to Lender stating the proposed date and principal amount of the prepayment, and if such notice is given Lender shall, prepay the Promissory Note in whole or in part together with accrued interest to the date of such prepayment on the amount prepaid.

No amendment or waiver of any provision of this Promissory Note, nor consent to any departure by Borrower herefrom, shall in any event be effective unless the same shall be in writing and signed by Lender, and then such waiver or consent shall be effective only in the specific instance and for the specific purpose for which given.

Borrower hereby waives (to the extent permitted by applicable laws) presentment, demand, protest and notice of any kind. No failure on Lender’s part to exercise, and no delay in exercising, any right hereunder shall operate as a waiver of such right; nor shall any single or partial exercise of any right hereunder preclude any other or further exercise thereof or the exercise of any other right. The remedies herein provided are cumulative and not exclusive of any remedies provided by law.

1

This Promissory Note shall be binding upon Borrower and its successors and assigns, and the terms and provisions of this Promissory Note shall inure to the benefit of Lender and its respective successors and assigns, including subsequent holders hereof.

This Promissory Note amends and restates in its entirety that certain Intercompany Demand Promissory Note by and between Borrower and Lender dated March 15, 2014, and supersedes such promissory note in all respects.

THIS PROMISSORY NOTE AND THE RIGHTS AND OBLIGATIONS OF THE PARTIES UNDER THIS PROMISSORY NOTE SHALL BE GOVERNED BY, AND CONSTRUED AND INTERPRETED IN ACCORDANCE WITH, THE LAW OF THE STATE OF TEXAS WITHOUT GIVING EFFECT TO CONFLICTS OF LAW PRINCIPLES THAT WOULD REQUIRE THE APPLICATION OF THE LAWS OF ANOTHER JURISDICTION.

The terms and provisions of this Promissory Note are severable, and if any term or provision shall be determined to be superseded, illegal, invalid or otherwise unenforceable in whole or in part pursuant to applicable law, such determination shall not in any manner impair or otherwise affect the validity, legality or enforceability of that term or provision in any other jurisdiction or any of the remaining terms and provisions of this Promissory Note in any jurisdiction.

This Promissory Note represents the entire agreement between the parties regarding the subject matter hereof and may not be contradicted by evidence of prior, contemporaneous or subsequent oral agreements of the parties. There are no unwritten oral agreements between the parties.

CENTRAL ENERGY PARTNERS LP
By:	Central Energy GP LLC, its General Partner
By:	/s/ John L. Denman, Jr.
	John L. Denman, Jr.,
	Chief Executive Officer and President

2

EX-15

Exhibit 15

ACCOUNTANT’S ACKNOWLEDGMENT

We acknowledge the incorporation by reference in the Registration Statement on Form S-3 (333-149238) and Form S-8 (333-149248) of Central Energy Partners LP of our report dated November 14, which appears on page 4 of the quarterly report on Form 10-Q for the quarter ended September 30, 2014.

/s/ MONGOMERY COSCIA GREILICH, LLP

Plano, Texas

November 14, 2014

EX-31.1

Exhibit 31.1

CERTIFICATION

I, John L. Denman, Jr., Chief Executive Officer and President of Central Energy GP LLC, the General Partner of Central Energy Partners LP, certify that:

1. I have reviewed this report on Form 10-Q of Central Energy Partners LP;

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

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

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

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

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

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

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

5. The registrant’s other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s Board of Managers or persons performing:

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

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

Date: November 14, 2014

/s/ John L. Denman, Jr.

John L. Denman, Jr.,

Chief Executive Officer and President

of Central Energy GP LLC, the

General Partner of

Central Energy Partners LP

EX-31.2

Exhibit 31.2

CERTIFICATION

I, Douglas W. Weir, Chief Financial Officer, certify that:

1. I have reviewed this report on Form 10-Q of Central Energy Partners LP;

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

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

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

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

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

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

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

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

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

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

Date: November 14, 2014

 /s/ Douglas W. Weir

Douglas W. Weir,

Chief Financial Officer

of Central Energy GP LLC, the

General Partner of

Central Energy Partners LP

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Central Energy Partners LP (“Central Energy”) on Form 10-Q for the three and nine months ended September 30, 2014 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), the undersigned, John L. Denman, Jr., Chief Executive Officer and President of Central Energy GP LLC, the General Partner of Central Energy and Douglas Weir, Chief Financial Officer of Central Energy GP LLC, the General Partner of Central Energy, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Central Energy.

/s/ John L. Denman, Jr.

John L. Denman, Jr.,

Chief Executive Officer and President of

Central Energy GP LLC, the

General Partner of

Central Energy Partners LP

November 14, 2014

/s/  Douglas W. Weir

Douglas W. Weir,

Chief Financial Officer of

Central Energy GP LLC, the

General Partner of

Central Energy Partners LP

November 14, 2014

XML

RELATED PARTY TRANSACTIONS (Additional Information) (Details) (USD $)	3 Months Ended		9 Months Ended				9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Jul. 26, 2007 Regional Enterprises, Inc. [Member]	Jan. 31, 2011 Regional Enterprises, Inc. [Member] Central Promissory Note [Member]	Sep. 30, 2014 General Partner [Member]	Sep. 30, 2014 General Partner [Member] Maximum [Member]	Sep. 30, 2014 Partnership and Rvop [Member]	Jul. 26, 2007 Partnership and Rvop [Member]
Related Party Transaction [Line Items]
Amounts paid under reimbursement agreements	$ 12,000	$ 12,000	$ 47,000	$ 42,000
Maximum Amount Allowed To Be Advanced By General Partner To Partnership								5,000,000
Interest rate on note							10.00%
Advances From General Partner							4,177,000
Debt instrument, face amount					2,500,000
Debt instrument, interest rate						10.00%				10.00%
Debt instrument, carrying amount	4,296,000		4,296,000
Allocated Partnership Expenses Charged To Subsidiary	45,000	64,000	165,000	177,000
Notes Payable, Related Parties									$ 2,957,000
Termination period			30 days

XML

UNIT OPTIONS AND EQUITY INCENTIVE PLAN (Grant of Restricted Common Unit Options to Executive Officers) (Details) (Restricted Stock Units (RSUs) [Member])	9 Months Ended
	Sep. 30, 2014
John L. Denman, Jr [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	500,000
G. Thomas Graves [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	300,000
Douglas W. Weir [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	250,000
Ian T. Bothwell [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	75,000
Daniel P. Matthews [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	75,000

XML

SEGMENT INFORMATION (Tables)

9 Months Ended

Sep. 30, 2014

Segment Reporting [Abstract]

Schedule of Segment Reporting

The following are amounts related to the Regional transportation and terminaling business included in the accompanying consolidated financial statements for the three months and nine months ended September 30, 2013 and 2014 and at December 31, 2013 and September 30, 2014:

	Three months		Three months		Nine  months		Nine  months
	ended		ended		ended		ended
	September 30,		September 30,		September 30,		September 30,
	2013		2014		2013		2014
Revenue from external customers	$	1,044,000	$	1,456,000	$	3,480,000	$	4,003,000
Interest expense		99,000		202,000		257,000		539,000
Depreciation and amortization		134,000		140,000		402,000		413,000
Income tax expense (benefit)		(62,000)		-		67,000		-
Net (loss)	$	(256,000)	$	(203,000)	$	(879,000)	$	(356,000)

	December 31,		September 30,
	2013		2014
Total assets	$	8,069,000	$	8,218,000

XML

SEGMENT INFORMATION (Amounts Related to Transportation and Terminating Business) (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Segment Reporting Information [Line Items]
Revenue from external customers	$ 1,456,000	$ 1,044,000	$ 4,004,000	$ 3,480,000
Interest expense	170,000	106,000	367,000	272,000
Depreciation and amortization			413,000	402,000
Income tax expense (benefit)	0	62,000	0	67,000
Net (loss)	(133,000)	(113,000)	(540,000)	(199,000)
Total assets	8,251,000		8,251,000		8,069,000
Transportation and Terminaling Business [Member]
Segment Reporting Information [Line Items]
Revenue from external customers	1,456,000	1,044,000	4,003,000	3,480,000
Interest expense	202,000	99,000	539,000	257,000
Depreciation and amortization	140,000	134,000	413,000	402,000
Income tax expense (benefit)	0	(62,000)	0	67,000
Net (loss)	$ (203,000)	$ (256,000)	$ (356,000)	$ (879,000)

XML

MAJOR CUSTOMERS AND CONCENTRATIONS OF CREDIT RISK (Additional Information) (Details) (USD $)	3 Months Ended	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2014
Maximum [Member]
Amount insured by Federal Deposit Insurance Corporation per institution	$ 250,000	$ 250,000
Suffolk Sales [Member] | Sales Revenue Net [Member]
Concentration risk, revenues percentage	17.00%	20.00%
Suffolk Sales [Member] | Accounts Receivable [Member]
Concentration risk, revenues percentage	22.00%	16.00%
Associated Asphalt Hopewell LLC [Member] | Sales Revenue Net [Member]
Concentration risk, revenues percentage		20.00%
Associated Asphalt Hopewell LLC [Member] | Accounts Receivable [Member]
Concentration risk, revenues percentage		0.00%
MeadWestVaco Specialty Chemicals, Inc [Member] | Sales Revenue Net [Member]
Concentration risk, revenues percentage	14.00%	16.00%
MeadWestVaco Specialty Chemicals, Inc [Member] | Accounts Receivable [Member]
Concentration risk, revenues percentage	25.00%	21.00%
Rubicon Energy LLC [Member] | Sales Revenue Net [Member]
Concentration risk, revenues percentage	29.00%
Rubicon Energy LLC [Member] | Accounts Receivable [Member]
Concentration risk, revenues percentage	20.00%

XML

LOSS PER COMMON UNIT

9 Months Ended

Sep. 30, 2014

Earnings Per Share [Abstract]

INCOME (LOSS) PER COMMON UNIT

NOTE C – Loss Per Common UNIT

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

	For the three months ended September 30, 2013
	(Loss)		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 three months ended September 30, 2014
	(Loss)		Units		Per-Unit
	(Numerator)		(Denominator)		Amount
Net (loss) available to the Common Unit	$	(130,000)
Basic EPS
Net (loss) available to the Common Units		(130,000)		19,591,482	$	(0.01)
Effect of Dilutive Securities
Options		—		—
Diluted EPS
Net income 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 income available to the Common Units		N/A		N/A		N/A

	For the nine months ended September 30, 2014
	(Loss)		Units		Per-Unit
	(Numerator)		(Denominator)		Amount
Net (loss) available to the Common Units	$	(529,000)
Basic EPS
Net (loss) available to the Common Units		(529,000)		19,299,815	$	(0.03)
Effect of Dilutive Securities
Options		—		—
Diluted EPS
Net (loss) available to the Common Units		N/A		N/A		N/A

Allocation of Net Income

Our net loss is allocated to partners’ capital accounts in accordance with the provisions of the partnership agreement.

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SEGMENT INFORMATION (Additional Information) (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Segment Reporting Information [Line Items]
Number of Operating Segments	1	1	1	1

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PROPERTY, PLANT AND EQUIPMENT (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Land	$ 512,000	$ 512,000
Terminal and improvements	5,755,000	4,955,000
Automotive equipment	1,297,000	1,297,000
Property, Plant and Equipment, Gross, Total	7,564,000	6,764,000
Less: accumulated depreciation and amortization	(4,019,000)	(3,606,000)
Property, plant and equipment - net	$ 3,545,000	$ 3,158,000

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LOSS PER COMMON UNIT (Reconciliations From Net Loss Per Common Unit to Loss Per Common Unit Assuming Dilution) (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Basic EPS
Net (loss) available to the Common Units	$ (130,000)	$ (111,000)	$ (529,000)	$ (195,000)
Weighted average common units outstanding	19,591,482	16,066,482	19,299,815	16,066,482
Net income (loss) per common unit	$ (0.01)	$ (0.01)	$ (0.03)	$ (0.01)

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PROPERTY, PLANT AND EQUIPMENT (Additional Information) (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Property, Plant and Equipment [Line Items]
Depreciation expense of property, plant and equipment	$ 140,000	$ 134,000	$ 413,000	$ 402,000

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DEBT OBLIGATIONS (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Long-term debt obligations gross	$ 2,500,000	$ 2,500,000
Less current portion	287,000	188,000
Long-term debt obligations	2,213,000	2,312,000
Hopewell Note [Member]
Debt Instrument [Line Items]
Long-term debt obligations gross	$ 2,500,000	$ 2,500,000

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PARTNERS' DEFICIT

9 Months Ended

Sep. 30, 2014

Equity [Abstract]

PARTNERS' DEFICIT

NOTE B – PARTNERS’ DEFICIT

The number of Common Units outstanding at September 30, 2014 was 19,591,482. The Common Units represent 98% of the Partnership’s outstanding capital and 100% of the Partnership’s limited partnership interests. We are controlled by our general partner, Central Energy GP LLC, which holds a 2% interest in the Partnership. At September 30, 2014, the Partners’ deficit was $806,000, of which $17,000 is attributable to the General Partner’s interest in the Partnership.

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DEBT OBLIGATIONS (Additional Information) (Details) (USD $)	9 Months Ended
	Sep. 30, 2014	Mar. 20, 2013
Hopewell Loan Agreements [Member]
Debt Instrument [Line Items]
Debt Instrument, Periodic Payment Terms, Balloon Payment to be Paid	$ 2,000,000
March 1, 2013 [Member]
Debt Instrument [Line Items]
Proceeds From (Repayments Of) Notes Payable	1,970,000
Hopewell Loan Agreement [Member]
Debt Instrument [Line Items]
Fixed annual rate of interest	12.00%
Debt Instrument, Periodic Payment, Principal	56,000
Long Term Debt Facility Maximum		$ 2,500,000

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REALIZATION OF ASSETS (Additional Information) (Details) (USD $)	9 Months Ended	12 Months Ended							9 Months Ended				9 Months Ended
	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2014 General Partner [Member]	Sep. 30, 2014 March 2016 [Member]	Sep. 30, 2014 Until May 2019 [Member]	Sep. 30, 2014 Tax Year 2012 [Member]	Sep. 30, 2014 Monthly Payments [Member] March 2016 [Member]	Nov. 30, 2013 Investment [Member]	Nov. 30, 2013 Maximum [Member] Amended Note Agreement [Member] General Partner [Member]	Nov. 30, 2013 Minimum [Member] Amended Note Agreement [Member] General Partner [Member]	Sep. 30, 2014 Hopewell Note [Member] Monthly Payments [Member] Until December 2014 [Member]
Limited Partners' Capital Account [Line Items]
Deficit In Working Capital	$ 898,000			$ 3,163,000
Working Capital Deficit Decrease	2,265,000
Working Capital Increase Decrease										2,750,000
Limit Of Advances Allowed Under Note Agreement											4,000,000	2,000,000
Cash	66,000	103,000	31,000	22,000	750,000
Debt Instrument, Periodic Payment, Interest													25,000
Debt Instrument, Periodic Payment									56,000
Debt Instrument, Periodic Payment Terms, Balloon Payment to be Paid						2,000,000
Minimum Monthly Operating Lease Payment Due							30,000
Income Tax Examination, Penalties Accrued								142,000
Disposal Group, Including Discontinued Operation, Operating Income (Loss)	$ 540,000	$ 521,000

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CONSOLIDATED BALANCE SHEETS (USD $)	Sep. 30, 2014	Dec. 31, 2013
Current Assets
Cash	$ 66,000	$ 103,000
Trade accounts receivable (less allowance for doubtful accounts of $0 at 2013 and 2014)	371,000	312,000
Prepaid expenses and other current assets	200,000	427,000
Total current assets	637,000	842,000
Property, plant and equipment - net	3,545,000	3,158,000
Other assets	128,000	128,000
Goodwill	3,941,000	3,941,000
Total assets	8,251,000	8,069,000
Current Liabilities
Current maturities of long-term debt	287,000	188,000
Accounts payable	1,078,000	1,418,000
Taxes payable	16,000	40,000
Unearned revenue	176,000	168,000
Accrued liabilities	265,000	424,000
Total current liabilities	1,822,000	2,238,000
Long-term debt obligations	2,213,000	2,312,000
Due to General Partner	4,177,000	3,000,000
Deferred income taxes	845,000	845,000
Commitments and contingencies
Partners’ deficit
Common units	(789,000)	(319,000)
General Partner’s deficit	(17,000)	(7,000)
Total partners’ deficit	(806,000)	(326,000)
Total liabilities and partners’ deficit	$ 8,251,000	$ 8,069,000

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CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Cash flows from operating activities:
Net loss	$ (540,000)	$ (199,000)
Adjustments to reconcile net loss to net cash (used in) provided by operating activities:
Depreciation and amortization	413,000	402,000
Reduction in accrued tax penalties assessed	0	(1,119,000)
Unit based compensation	60,000	16,000
Changes in current assets and liabilities:
Trade accounts receivable	(59,000)	286,000
Prepaid and other current assets	227,000	479,000
Due to/from General Partner, net	1,177,000	445,000
Trade accounts payable	(340,000)	(924,000)
Unearned revenue	8,000	(33,000)
Accrued liabilities and other	(159,000)	126,000
U.S. and foreign taxes payable	(24,000)	(25,000)
Net cash provided by (used in) operating activities	763,000	(546,000)
Cash flows from investing activities:
Capital expenditures	(800,000)	(6,000)
Proceeds from sale of assets	0	31,000
Net cash provided by (used in) investing activities	(800,000)	25,000
Cash flows from financing activities:
Issuance of debt	0	2,500,000
Payment of debt	0	(1,970,000)
Net cash provided by financing activities	0	530,000
Net (decrease) increase in cash	(37,000)	9,000
Cash at beginning of period	103,000	22,000
Cash at end of period	66,000	31,000
Cash paid during the year for:
Interest	240,000	222,000
Taxes	$ 35,000	$ 84,000

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UNIT OPTIONS AND EQUITY INCENTIVE PLAN (Additional Information) (Details) (USD $)	0 Months Ended		1 Months Ended			0 Months Ended	9 Months Ended		1 Months Ended
	May 16, 2014	Nov. 26, 2013	Nov. 26, 2013 JLD [Member]	Nov. 30, 2013 JLD and Mr. G. Thomas Graves III [Member]	Nov. 26, 2013 JLD and Mr. G. Thomas Graves III [Member]	May 16, 2014 2005 Equity Incentive Plan [Member]	Sep. 30, 2014 2005 Equity Incentive Plan [Member]	Mar. 09, 2005 2005 Equity Incentive Plan [Member]	Mar. 26, 2014 2014 Equity Incentive Plan [Member]	Sep. 30, 2014 2014 Equity Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Partnership Issued Performance Warrants For Consideration			$ 500
Maximum Common Units Acquire By Each Performance Warrant					1,500,000
Average Closing Bid Price For Common Unit	$ 0.09			$ 0.093478
Share-based Compensation Arrangement by Share-based Payment Award, Shares Issued in Period							47,310
Common Units Authorized Subject To Amendment To Increase Authorized Common Units								750,000		3,300,000
Remain Available Common Units For Issuance										1,950,000
Purchase Price For Acquired General Partner Interest And Partnership Units		$ 20,000,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross						375,000			75,000

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PROPERTY, PLANT AND EQUIPMENT (Tables)

9 Months Ended

Sep. 30, 2014

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

	December 31,		September 30,
	2013		2014
Land	$	512,000	$	512,000
Terminal and improvements		4,955,000		5,755,000
Automotive equipment		1,297,000		1,297,000
		6,764,000		7,564,000
Less: accumulated depreciation and amortization		(3,606,000)		(4,019,000)
	$	3,158,000	$	3,545,000

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COMMITMENTS AND CONTINGENCIES (Additional Information) (Details) (USD $)	0 Months Ended	1 Months Ended	0 Months Ended
	Feb. 17, 2012 Lease Agreements [Member] Regional Facilities and Services [Member]	Jan. 31, 2012 Regional Enterprises, Inc. [Member] Maintenance Agreements [Member]	Feb. 17, 2012 Regional Enterprises, Inc. [Member] Lease Agreements [Member]	Feb. 17, 2012 Sgr Energy Llc [Member] Lease Agreements [Member]
Commitments and Contingencies Disclosure [Line Items]
Upward price adjustment percentage		1.00%
Agreement term		36 months
Agreement termination, written notice period		60 days
Number of tractors leased			20
Amount of security deposit provided from the sale of tractors			$ 90,000
Number of tractors sold				6
Lease agreement term	7 years

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UNIT OPTIONS AND EQUITY INCENTIVE PLAN (Tables)

9 Months Ended

Sep. 30, 2014

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Grant of Restricted Common Unit Options to Executive Officers

The Compensation Committee finalized the terms of the Restricted Common Unit Restricted Unit Agreement, the form of which is attached to this Report (the “Restricted Unit Agreement”), and delivered such Restricted Unit Agreements to each of the executive officers on May 16, 2014, granting the number of Restricted Units as set forth in the following table:

Award Recipient	Number of Restricted Units
John L. Denman, Jr.	500,000
G. Thomas Graves	300,000
Douglas W. Weir	250,000
Ian T. Bothwell	75,000
Daniel P. Matthews	75,000

Grant of Common Units to Directors under the 2005 Plan

The Compensation Committee finalized the terms of the Common Unit Grant Agreement (the “Grant Agreement”) and delivered such Grant Agreements to each of the non-executive directors on May 16, 2014, granting the number of Common Units as set forth in the following table:

Award Recipient	Number of Common Units
Alan D. Bell	75,000
Alexander C. Chae	75,000
William M. Comegys III	75,000
Robert H. Lutz	75,000
Michael T. Wilhite	75,000

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BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

9 Months Ended

Sep. 30, 2014

Accounting Policies [Abstract]

BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

NOTE A –BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

Business

Central Energy Partners LP, a publicly traded Delaware limited partnership, was formed in July 2003. As used in this report, the terms “Central Energy” and “the Partnership” refer to Central Energy Partners LP, and the terms “Central,” “the Company,” “we,” “our” and “us” are used in this report to refer to Central Energy, its sole general partner Central Energy GP LLC, and its consolidated subsidiaries as a whole.

We conduct our operations through our wholly-owned subsidiary, 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 18 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 limited partnership interests in the Partnership (“Common Units”) represent 98% of the Partnership’s outstanding capital and 100% of the Partnership’s limited partnership interests. We are controlled by our general partner, Central Energy GP LLC (“General Partner”), 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 as provided in the partnership agreement. 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.

Effective November 26, 2013, CEGP Acquisition, LLC (“CEGP”) acquired 55% of the issued and outstanding membership interests in the General Partner and 3,000,000 Common Units, which represents 15% of the issued and outstanding Common Units of the Partnership (the “CEGP Investment”). CEGP appoints five (5) of the nine (9) members of the Board of Directors of the General Partner. As a result, CEGP controls the General Partner. CEGP is a Texas limited liability company controlled by John L. Denman, Jr. and G. Thomas Graves III. Upon completion of the CEGP Investment, Mr. Denman replaced Mr. Imad K. Anbouba as CEO and President of the General Partner, and Mr. Graves was appointed as the Chairman of the Board of Directors replacing Mr. Jerry V. Swank, a principal of the controlling entity of The Cushing MLP Opportunity Fund, L.P. which holds 39.1% of the Common Units of the Partnership (the “Cushing Fund”). JLD Services, Ltd., a company controlled by Mr. Denman, and Mr. Graves were each granted a Performance Warrant which, when exercised and combined with the Common Units acquired by CEGP in connection with the CEGP Investment, would represent 26.6% of the issued and outstanding Common Units of the Partnership. The Performance Warrants expire on November 25, 2014 and it is unlikely that the performance requirements will be satisfied.

Basis of Presentation

The accompanying consolidated financial statements include the Partnership and its only operating subsidiary, Regional. We have two other subsidiaries that have no operations – Rio Vista Operating Partnership, LP (“RVOP”) and Rio Vista Operating GP LLC. All significant intercompany accounts and transactions are eliminated.

The unaudited consolidated balance sheet as of September 30, 2014, the unaudited consolidated statements of operations for the three months and nine months ended September 30, 2013 and 2014 and the unaudited consolidated statements of cash flows and of partners’ deficit for the nine months ended September 30, 2014, have been prepared by us without audit. In our opinion, 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, 2014, the unaudited consolidated results of operations for the three months and nine months ended September 30, 2013 and 2014 and the unaudited consolidated statements of cash flows and of partners’ deficit for the nine months ended September 30, 2014.

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 we believe that the disclosures made are adequate to make the information not misleading. These unaudited consolidated financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2013 filed with the Securities and Exchange Commission.

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.

Use of Estimates

The preparation of financial statements in conformity with generally accepted accounting principles requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclose contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates, and such differences could be material.

Cash Equivalents

We consider all highly liquid investments with maturities of three months or less when purchased to be cash equivalents.

Financial Instruments

The fair values of our financial instruments, which may include cash, accounts receivable, accounts payable and long-term debt, approximate their carrying amounts.

Distributions of Available Cash

In March 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 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 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 General Partner for making such distributions.

Environmental Obligations

We are subject to various federal, state and local laws and regulations relating to the protection of the environment. We have established procedures for the ongoing evaluation of our operations, to identify potential environmental exposures, and to comply with regulatory policies and procedures. We account 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. We maintain insurance which may cover in whole or in part certain types of environmental contingencies. For the quarters ended September 30, 2013 and 2014, we had no environmental contingencies requiring specific disclosure or the recording of a liability.

Unit Based Compensation

We 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. We apply 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. We did not record any costs for unit-based payment costs for non-employees for the nine months ended September 30, 2013 and 2014, respectively under the fair-value provisions of ASC 505.

The Partnership applies ASC 718 for options, Common Units or other equity-based grants to our employees and directors of the General Partner. 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, we 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. We recorded $16,000 and $60,000 for unit-based payment costs for employees and directors for the nine months ended September 30, 2013 and 2014, respectively, under the fair-value provisions of ASC 718. See “Note F – Unit Options and Equity Incentive Plan – Incentive Plans” below for information regarding equity-based grants made during the nine months ended September 30, 2014.

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CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	Sep. 30, 2014	Dec. 31, 2013
Trade accounts receivable, allowance for doubtful accounts	$ 0	$ 0

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REALIZATION OF ASSETS

9 Months Ended

Sep. 30, 2014

Going Concern Disclosure [Abstract]

REALIZATION OF ASSETS

NOTE K — REALIZATION OF ASSETS

Our unaudited consolidated balance sheets have been prepared in conformity with accounting principles generally accepted in the United States of America, which contemplate our continuation as a going concern. We had a loss from operations for the year ended December 31, 2013 and the nine months ended September 30, 2014 of $521,000 and $540,000, respectively.

During the period since December 31, 2012, we improved our overall liquidity. Our deficit in working capital, excluding current maturities of long-term debt, totaled $898,000 at September 30, 2014 compared with $3,163,000 at December 31, 2012, a reduction of $2,265,000. In addition, we were successful in reducing our obligations owing under the Penske Lease Agreement and extending the interest only payment period under the Hopewell Loan Agreement. During 2013, we also satisfactorily resolved the TransMontaigne Dispute, the contingencies associated with the late filing tax matters, and paid down and/or obtained payment arrangements with critical accounts payable vendors.

During November 2013, we completed the CEGP Investment, which provided working capital of $2.75 million to the General Partner and Central Energy. We also recently amended the note agreement with the General Partner which provides for an increase in the amount of advances from the General Partner from $2.0 million to $4.0 million.

At September 30, 2014, we had cash available to fund ongoing working capital requirements of $66,000. In August 2014, the Board of Directors of the General Partner recommended a capital call of $750,000 to fund working capital needs. This recommendation was approved by the requisite percentage of members on August 7, 2014. As of November 14, 2014, the capital call was fully subscribed and funded. We anticipate that this amount, together with cash flow from operations, will be sufficient to meet the Company’s working capital requirements for approximately 12 months.

In connection with the Hopewell Note, Regional is currently required to make interest payments only of $25,000 per month until December 2014 and then equal monthly payments of $56,000 (principal and interest) each month thereafter until March 2016 at which time a balloon payment of approximately $2 million will be due. Regional also is required to make minimum monthly payments under the Penske Lease Agreement of approximately $30,000 until May 2019. Payments under the Hopewell Note and the Penske Lease Agreement could be accelerated in the event of a default. The amount of penalties related to the remaining 2012 Tax Return is $142,000 and will be required to be paid if our appeal is unsuccessful. Since the closing of the CEGP Investment, Messrs. Denman, Graves and Weir have agreed to forego receipt of any compensation as a result of concerns over available cash resources.

Substantially all of our assets are pledged as collateral for the Hopewell Loan, and therefore, we are unable to obtain additional financing collateralized by those assets without repayment of the Hopewell Loan. In addition, we have obligations under existing registrations rights agreements. These rights may be a deterrent to any future equity financings.

In view of the matters described in the preceding paragraphs, recoverability of the recorded asset amounts shown in the accompanying consolidated balance sheet assumes that: (1) we do not experience any significant disruptions in storage revenues resulting from the timing of termination of storage tank lease agreements and identifying replacement customers and/or disruptions resulting from the performance of maintenance on our facilities; (2) our hauling revenues remain at current levels; (3) obligations to creditors are not accelerated; (4) our pending facility upgrades are completed timely and within estimated budgets; (5) our operating expenses remain at current levels; (6) we obtain additional working capital to meet our contractual commitments through future intercompany advances or a refinancing of the Hopewell Loan; and/or (7) the Partnership is able to receive future distributions from Regional or future advances from the General Partner in amounts necessary to fund working capital until an acquisition transaction is completed by the Partnership.

There is no assurance that we will have sufficient working capital to cover ongoing cash requirements for the period of time we believe is necessary to complete an acquisition that will provide additional working capital for us. If we do not have sufficient cash reserves, our ability to pursue additional acquisition transactions will be adversely impacted. Furthermore, despite significant effort, we have thus far been unsuccessful in completing an acquisition transaction. There can be no assurance that we 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, we 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.

It is our intention to acquire additional assets during 2015 on terms that will enable us to expand our assets and generate additional cash from operations. We are also seeking to obtain additional funding through a refinancing of the Hopewell Loan or from an alternative funding transaction. The accompanying 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 we be unable to obtain adequate funding to maintain operations and to continue in existence.

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Document And Entity Information	9 Months Ended
	Sep. 30, 2014	Nov. 07, 2014
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2014
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	Q3
Entity Registrant Name	CENTRAL ENERGY PARTNERS LP
Entity Central Index Key	0001260828
Current Fiscal Year End Date	--12-31
Entity Filer Category	Smaller Reporting Company
Trading Symbol	ENGY
Entity Common Stock, Shares Outstanding		19,591,482

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401K

9 Months Ended

Sep. 30, 2014

Compensation and Retirement Disclosure [Abstract]

401K

NOTE L - 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.

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CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Revenues	$ 1,456,000	$ 1,044,000	$ 4,004,000	$ 3,480,000
Cost of goods sold	1,061,000	838,000	3,073,000	2,946,000
Gross profit	395,000	206,000	931,000	534,000
Selling, general and administrative expenses and other
Legal and professional fees	61,000	182,000	146,000	430,000
Salaries and payroll related expenses	141,000	180,000	478,000	633,000
Other	156,000	(211,000)	480,000	(669,000)
Selling, General and Administrative Expense, Total	358,000	151,000	1,104,000	394,000
Operating income (loss) from continuing operations	37,000	55,000	(173,000)	140,000
Other expense
Interest expense, net	(170,000)	(106,000)	(367,000)	(272,000)
Loss before taxes	(133,000)	(51,000)	(540,000)	(132,000)
Provision for income taxes	0	(62,000)	0	(67,000)
Net Loss	(133,000)	(113,000)	(540,000)	(199,000)
Net Loss allocable to the partners	(133,000)	(113,000)	(540,000)	(199,000)
Less General Partner’s interest in net loss	(3,000)	(2,000)	(11,000)	(4,000)
Net loss allocable to the common units	$ (130,000)	$ (111,000)	$ (529,000)	$ (195,000)
Net loss per common unit	$ (0.01)	$ (0.01)	$ (0.03)	$ (0.01)
Weighted average common units outstanding	19,591,482	16,066,482	19,299,815	16,066,482

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UNIT OPTIONS AND EQUITY INCENTIVE PLAN

9 Months Ended

Sep. 30, 2014

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

UNIT OPTIONS AND EQUITY INCENTIVE PLAN

NOTE F – UNIT OPTIONS AND EQUITY INCENTIVE PLAN

Performance Warrants

On November 26, 2013, we issued Performance Warrants to JLD Services, Ltd., a company controlled by Mr. Jack Denman, the Chief Executive Officer and President of the General Partner, and Mr. G. Thomas Graves III, the Chairman of the General Partner, for consideration of $500 each. Each Performance Warrant, grants the holder thereof the right, but not the obligation, to acquire up to 1,500,000 Common Units at a price of $0.093478, which was the average closing bid price for a Common Unit as reported by the “Pink Sheets” published by OTC Pink for the 30-day period ended November 22, 2013, in the event the Partnership successfully completes one or more asset acquisition transactions, approved by the General Partner, with an aggregate gross purchase price of at least $20 million within 12 months after the closing of the CEGP Investment. The Performance Warrants provide certain anti-dilution protections in the event of a distribution of additional Common Units or subdivision of outstanding Common Units, a capital reorganization of the Partnership, a reclassification of the units of the Partnership, the consolidation or merger of the Partnership with or into another entity, or other similar transaction. Each holder or its assigns is granted registration rights with respect to the Common Units issuable upon exercise of a Performance Warrant. It is not anticipated that these performance milestones will be achieved prior to the expiration of the Performance Warrants.

Incentive Plans

On March 9, 2005, we established the 2005 Equity Incentive Plan of Rio Vista Energy Partners L.P. (“2005 Plan”). The 2005 Plan permits the grant of options, appreciation rights, restricted common units and phantom units of Common Units of the Partnership to any person who is an employee or director of, or consultant to, the Partnership or the General Partner or any affiliate of the Partnership (the “Partnership Entities”). The plan provides anti-dilution protection as determined by the Compensation Committee for a combination, exchange or extra-ordinary distribution of Common Units, or reorganization, recapitalization or any similar event affecting the Common Units or other securities of the Partnership. There were 750,000 Common Units authorized for issuance as awards under the 2005 Plan. The 2005 Plan remains available for the grant of awards until March 9, 2015, or such earlier date as the Board of the General Partner may determine. As the result of the grant of Common Units to non-executive directors of the General Partner as described below, there are 47,310 Common Units remaining for issuance under the 2005 Plan as of September 30, 2014.

On March 26, 2014, the Board of Directors of the General Partner authorized and approved the 2014 Long-Term Incentive Plan of Central Energy Partners, LP (“2014 Plan”). The 2014 Plan permits the grant of incentive and non-incentive Common Unit Options, Common Unit Appreciation Rights, Restricted Common Unit Grants, Common Units, Common Unit Value Equivalents and Substitute Awards to employees and directors of the Partnership Entities. The Compensation Committee may grant the recipient of an award, other than a Common Unit grant, the right to receive an amount equal to the minimum quarterly distributions associated with the Common Units which are the subject of an award. All awards, except an outright grant of Common Units, are subject to forfeiture upon termination of an executive officer, employee or director for any reason unless the Compensation Committee establishes other criteria in the award grant. The 2014 Plan provides anti-dilution protection for the recipient of an award in the case of a reorganization, combination, exchange or extra-ordinary distribution of Common Units, a merger, consolidation or combination of the Partnership with another entity, or a “change of control” of the Partnership or the General Partner. The 2014 Plan remains in effect until December 31, 2023, unless sooner terminated by the Board of Directors of the General Partner in accordance with its terms. The 2014 Plan authorizes the issuance of up to 3,300,000 Common Units, subject to amendment to increase the amount of authorized Common Units. As a result of the grant of Common Units to executive officers of the General Partner, Regional, and directors of the General Partner as summarized below, there are 1,950,000 Common Units remaining for issuance under the 2014 Plan as of September 30, 2014.

Grant of Restricted Common Unit Options to Executive Officers

On March 26, 2014, the Board of Directors of the General Partner approved the recommendation of the Board’s Compensation Committee to grant restricted Common Units (the “Restricted Units”) to the executive officers of the General Partner and Regional. The Compensation Committee finalized the terms of the Restricted Common Unit Restricted Unit Agreement, the form of which is attached to this Report (the “Restricted Unit Agreement”), and delivered such Restricted Unit Agreements to each of the executive officers on May 16, 2014, granting the number of Restricted Units as set forth in the following table:

Award Recipient	Number of Restricted Units
John L. Denman, Jr.	500,000
G. Thomas Graves	300,000
Douglas W. Weir	250,000
Ian T. Bothwell	75,000
Daniel P. Matthews	75,000

The grant of the Restricted Units is made in consideration of the services to be rendered by an executive officer to the Partnership Entities. The Restricted Unit Agreement provides the award recipient the right to purchase the designated number of Common Units at an exercise price established by the final trade price of a Common Unit on the date of grant (May 16, 2014) or, if no trade occurred on the date of grant, the average bid and asked price on that date as quoted by OTC Pink. There was no trade in the Common Units on May 16, 2014, and the average bid and asked price on that date was $0.09. Each grant of Restricted Units expires on May 16, 2019.

The Restricted Units are awards of Common Units that are subject to restrictions on transferability and a substantial risk of forfeiture and are intended to retain and motivate members of management of the Partnership Entities. Award recipients have all the rights of a Unitholder in the Partnership with respect to the Restricted Units, including the right to receive distributions thereon if and when distributions are made by the Partnership to other Unitholders. The Restricted Units vest and the forfeiture restrictions lapse in substantially equal one-third (1/3) increments on each of May 16, 2015, May 16, 2016, and May 16, 2017.

If an award recipient’s service with the Partnership Entities is terminated prior to full vesting of the Restricted Units due to death or “disability” (as defined in the Restricted Unit Agreement) or if the award recipient’s employment with the Partnership Entities is terminated for “good reason” (as defined in the Restricted Unit Agreement) or by a Partnership Entity without “cause” (as defined in the Restricted Unit Agreement), then all Restricted Units will immediately vest in full as of the date of such termination. If an award recipient’s service with a Partnership Entity is terminated prior to full vesting of the Restricted Units for any other reason, then the award recipient will forfeit all unvested Restricted Units to the Partnership. In the event of an award recipient’s termination from service without “cause” or for “good reason” within two (2) years following the occurrence of a change of control, all unvested Restricted Units will become immediately vested in full. The Restricted Units are subject to anti-dilution protections as provided in the Restricted Unit Agreement. The Partnership is obligated to register the Restricted Units with the U.S. Securities and Exchange Commission (the “Commission”) pursuant to a Form S-8 registration statement.

Grant of Common Units to Directors under the 2005 Plan

At meetings held on December 19, 2013 and March 26, 2014, the Board of Directors of the General Partner approved the recommendation of its Compensation Committee to grant 375,000 Common Units to its non-executive directors under the 2005 Plan. The Compensation Committee finalized the terms of the Common Unit Grant Agreement (the “Grant Agreement”) and delivered such Grant Agreements to each of the non-executive directors on May 16, 2014, granting the number of Common Units as set forth in the following table:

Award Recipient	Number of Common Units
Alan D. Bell	75,000
Alexander C. Chae	75,000
William M. Comegys III	75,000
Robert H. Lutz	75,000
Michael T. Wilhite	75,000

The Common Units have been awarded to each of the directors for their service to the Partnership Entities in lieu of cash compensation. The Common Units awarded to each director have the value per Common Unit as established by the final trade price of a Common Unit on May 16, 2014 or, if no trade occurred on that date, the average bid and asked price on such date. The award recipient is the owner of the Common Units effective May 16, 2014 until such date as the Common Units are sold by such recipient and shall have all of the rights of a Unitholder of the Partnership. The Common Units are subject to anti-dilution protections as provided in the Restricted Unit Agreements. The Partnership is obligated to register the Common Units with the Commission pursuant to a Form S-8 registration statement.

Grant of Common Units to Directors under the 2014 Plan

On March 26, 2014, the Board of Directors of the General Partner approved the recommendation of its Compensation Committee to grant 75,000 Common Units to each of Imad K. Anbouba, a director of the General Partner and its former Chief Executive Officer, and Swank Investment Partners LP, an affiliate of The Cushing MLP Opportunity Fund I, L.P., which is the largest holder of Common Units and for which Daniel L. Spears, one of the directors of the General Partner, serves as portfolio manager. The Compensation Committee finalized the terms of the Common Unit Grant Agreements for such awards, the form of which is attached to this Report, and delivered such grant agreements to each of Mr. Anbouba and Swank Investment Partners on May 16, 2014. These grant agreements have the same terms and conditions as the Grant Agreements issued under the 2005 Plan.

Each of the 2005 Plan and the 2014 Plan are administered by the Compensation Committee of the Board. In addition, the Board may exercise any authority of the Compensation Committee under the 2005 Plan. The Compensation Committee has broad discretion in issuing awards under either plan and amending or terminating either plan. Under the terms of the Partnership Agreement, no approval of either the 2005 Plan or the 2014 Plan by the Limited Partners of the Partnership is required.

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DEBT OBLIGATIONS

9 Months Ended

Sep. 30, 2014

Debt Disclosure [Abstract]

DEBT OBLIGATIONS

NOTE E — DEBT OBLIGATIONS

	December 31,		September 30,
	2013		2014
Long-term debt obligations were as follows:
Hopewell Note	$	2,500,000	$	2,500,000
		-		-
		2,500,000		2,500,000
Less current portion		188,000		287,000
	$	2,312,000	$	2,213,000

Hopewell Note

On March 20, 2013, we 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”), all of which was advanced in 2013. William M. Comegys III, a member of the Board of Directors of the General Partner, is a member of Hopewell. As a result of this affiliation, the terms of the Hopewell Loan were reviewed by the Conflicts Committee of the Board of Directors of the General Partner. The committee determined that the Hopewell Loan was on terms better than could be obtained from a third-party lender.

In connection with the Hopewell Loan, we issued Hopewell a promissory note (“Hopewell Note”) along with 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, we also 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, we 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 our previous lender in the amount of $1,970,000. The remaining amounts provided under the Hopewell Loan were used for working capital.

The Hopewell Loan matures March 19, 2016 and carries a fixed annual rate of interest of 12%. Under the terms of the Hopewell Loan, as amended, we are required to make interest payments only through December 2014 and then 14 equal monthly payments of $56,000 (principal and interest) from January 2015 through February 2016 with a balloon payment of approximately $2 million due on March 19, 2016.

We are also 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 us, declare the Hopewell Note immediately due and payable. We have provided all required financial statements to Hopewell.

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DEBT OBLIGATIONS (Tables)

9 Months Ended

Sep. 30, 2014

Debt Disclosure [Abstract]

Schedule of Debt

	December 31,		September 30,
	2013		2014
Long-term debt obligations were as follows:
Hopewell Note	$	2,500,000	$	2,500,000
		-		-
		2,500,000		2,500,000
Less current portion		188,000		287,000
	$	2,312,000	$	2,213,000

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SEGMENT INFORMATION

9 Months Ended

Sep. 30, 2014

Segment Reporting [Abstract]

SEGMENT INFORMATION

NOTE M - SEGMENT INFORMATION

We report 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. We had only one operating segment (the transportation and terminaling business of Regional) during the three months and nine months ended September, 2013 and 2014.

The following are amounts related to the Regional transportation and terminaling business included in the accompanying consolidated financial statements for the three months and nine months ended September 30, 2013 and 2014 and at December 31, 2013 and September 30, 2014:

	Three months		Three months		Nine  months		Nine  months
	ended		ended		ended		ended
	September 30,		September 30,		September 30,		September 30,
	2013		2014		2013		2014
Revenue from external customers	$	1,044,000	$	1,456,000	$	3,480,000	$	4,003,000
Interest expense		99,000		202,000		257,000		539,000
Depreciation and amortization		134,000		140,000		402,000		413,000
Income tax expense (benefit)		(62,000)		-		67,000		-
Net (loss)	$	(256,000)	$	(203,000)	$	(879,000)	$	(356,000)

	December 31,		September 30,
	2013		2014
Total assets	$	8,069,000	$	8,218,000

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INCOME TAXES

9 Months Ended

Sep. 30, 2014

Income Tax Disclosure [Abstract]

INCOME TAXES

NOTE I — INCOME TAXES

Federal Tax Liabilities

Failure to File Electronically and Delivery of Schedules K-1 to Unitholders

During November 2013, we received a notice from the IRS that we were liable for penalties (“2012 IRS Penalties”) of approximately $296,000 in connection with the late filing of the 2012 federal partnership tax return (“2012 Tax Return”) and approximately $142,000 in connection with failing to file the 2012 Tax Return electronically. We timely filed the 2012 Tax Return manually. During January 2014, we submitted an appeal to the IRS to have the 2012 IRS Penalties removed. On February 25, 2014, we received written notice from the IRS that the appeal of the late filing penalty was approved and the appeal of the failure to file the 2012 Tax Return electronically was denied. We believe that there existed reasonable cause for the Partnership’s failure to file the 2012 Tax Return electronically and we have notified the IRS that we are appealing their decision subject to the IRS completing its review of the matter, which remains pending. As of September 30, 2014, we have accrued a reserve of $142,000 in connection with the remaining 2012 IRS Penalties.

There can be no assurance that our request for relief from the remaining outstanding 2012 IRS Penalties will be approved by the IRS or that we will have adequate financial resources to pay the remaining outstanding 2012 IRS Penalties.

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COMMITMENTS AND CONTINGENCIES

9 Months Ended

Sep. 30, 2014

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

NOTE G - COMMITMENTS AND CONTINGENCIES

Legal Proceedings

We are involved with legal proceedings, lawsuits and claims in the ordinary course of our business. We believe that the liabilities, if any, ultimately resulting from such proceedings, lawsuits and claims should not materially affect its consolidated financial results.

Leases

Penske Truck Lease

Effective January 18, 2012, we entered into a Vehicle Maintenance Agreement (“Maintenance Agreement”) with Penske Truck Leasing Co., L. P. (“Penske”) for the maintenance of our 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, 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 to Penske, maintenance of Regional’s insurance obligation, or any other breach of the terms of the agreement.

On February 17, 2012, we entered into a seven-year Vehicle Lease Service Agreement with Penske for the outsourcing of 20 new Volvo tractors (“Leased Tractors”) to be acquired by Penske and leased to us for seven years, and the outsourcing of the maintenance of the Leased Tractors to Penske (“Lease Agreement”). Under the terms of the Lease Agreement, we 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 Leased Tractors in good repair and operating condition. Any replacement parts and labor for repairs which are not ordinary wear and tear are to be charged to Regional 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 has obtained all operating permits and licenses with respect to the use of the Leased Tractors by Regional. In connection with the delivery of the Leased Tractors, we sold our remaining owned tractor fleet, except for several owned tractor units which were retained to be used for terminal site logistics.

Under the terms of the Lease Agreement, Regional (i) may acquire any or all of the Leased 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 Leased Tractors 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 Leased Tractors as provided in the Lease Agreement due to a decline in Regional’s transportation business. As a result of this partial termination, Regional now operates 15 Leased Tractors pursuant to the Lease Agreement. Regional is obligated to maintain liability insurance coverage on all Leased Tractors.

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MAJOR CUSTOMERS AND CONCENTRATIONS OF CREDIT RISK

9 Months Ended

Sep. 30, 2014

Risks and Uncertainties [Abstract]

MAJOR CUSTOMERS AND CONCENTRATIONS OF CREDIT RISK

NOTE H – MAJOR CUSTOMERS AND CONCENTRATIONS OF CREDIT RISK

Major Customers

For the three months ended September 30, 2014, Rubicon Energy LLC, Suffolk Sales, and MeadWestvaco Specialty Chemicals, Inc., accounted for approximately 29%, 17% and 14% of Regional’s revenues, respectively, and approximately 20%, 22% and 25% of its account receivables, respectively.

For the nine months ended September 30, 2014, Associated Asphalt Hopewell LLC, Suffolk Sales, and MeadWestvaco Specialty Chemicals, Inc., accounted for approximately 20%, 20% and 16% of Regional’s revenues, respectively, and approximately 0%, 16% and 21% of Regional’s accounts receivable, respectively.

Concentrations of Credit Risk

The balance sheet items that potentially subject us to concentrations of credit risk are primarily cash and cash equivalents and accounts receivable. We maintain 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, 2014, we did not have any cash balances in financial institutions in excess of FDIC insurance coverage. Concentrations of credit risk with our accounts receivable are mitigated by our ongoing credit evaluations of our customers.

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RELATED PARTY TRANSACTIONS

9 Months Ended

Sep. 30, 2014

Related Party Transactions [Abstract]

RELATED PARTY TRANSACTIONS

NOTE J — RELATED PARTY TRANSACTIONS

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

Advances from General Partner

All funds advanced to the Partnership by the General Partner since November 17, 2010 have been treated as a loan. Effective March 1, 2012, the Genreal Partner and the Partnership executed an Intercompany Demand Promissory Note to evidence the indebtedness, which note was amended during March 2014 and November 2014. The intercompany demand note provides for advances from time to time by the General Partner to the Partnership of up to $5,000,000 to fund working capital needs of the Partnership and its subsidiaries. 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 bore interest at the imputed rate of the IRS for medium-term notes. The November 2014 amendment increased the interest rate to a flat 10% per annum for all periods from and after July 1, 2014. At September 30, 2014, the total amount owed to the General Partner by the Partnership, including accrued interest, was $4,177,000.

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 order to provide 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, 2014 is $4,296,000. 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. 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, 2014, the intercompany balance owed by Regional to the Partnership and/or RVOP is approximately $2,957,000, which includes interest. This amount is due to the Partnership and RVOP on demand; however, as is the case with the Central Promissory Note, payment of these amounts is also subordinated to payment of the Hopewell Note by Regional.

Allocated Expenses Charged to Subsidiary

Regional is charged for direct expenses paid by the Partnership on its behalf, as well as its share of allocable overhead for expenses incurred by the Partnership which are indirectly attributable to Regional related activities. For the three months and nine months ended September 30, 2013 and 2014, Regional recorded allocable expenses of $64,000, $45,000, $177,000 and $165,000, respectively.

Reimbursement Agreements

Effective December 31, 2013, in connection with the CEGP Investment and the resulting change in control of the General Partner, the Partnership moved its principal executive offices to another office location within Dallas, Texas that is leased from Katy Resources LLC (“Katy”), an entity controlled by G. Thomas Graves III, the Chairman of the Board of the General Partner. As a result, we entered into a new reimbursement agreement with Katy on a month-to-month basis for reimbursement of allocable “overhead costs” 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 Senior Vice President 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. In connection with the CEGP Investment, the Partnership reimbursed Rover Technologies LLC for the outstanding unpaid overhead costs as of the date of the CEGP Investment. For the three months and nine months ended September 30, 2013 and 2014, expenses billed in connection with the reimbursement agreements were $12,000, $12,000, $42,000 and $47,000, respectively.

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UNIT OPTIONS AND EQUITY INCENTIVE PLAN (Grant of Common Units to Directors) (Details)	9 Months Ended
	Sep. 30, 2014
Alan D. Bell [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross	75,000
Alexander C. Chae [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross	75,000
William M. Comegys III [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross	75,000
Robert H. Lutz [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross	75,000
Michael T. Wilhite [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Gross	75,000

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LOSS PER COMMON UNIT (Tables)

9 Months Ended

Sep. 30, 2014

Earnings Per Share [Abstract]

Reconciliations From Net Loss Per Common Unit to Loss Per Common Unit Assuming Dilution

The following tables present reconciliations from net loss per Common Unit to net loss per Common Unit assuming dilution (see Note F – Unit Options and Equity Incentive Plan):

	For the three months ended September 30, 2013
	(Loss)		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 three months ended September 30, 2014
	(Loss)		Units		Per-Unit
	(Numerator)		(Denominator)		Amount
Net (loss) available to the Common Unit	$	(130,000)
Basic EPS
Net (loss) available to the Common Units		(130,000)		19,591,482	$	(0.01)
Effect of Dilutive Securities
Options		—		—
Diluted EPS
Net income 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 income available to the Common Units		N/A		N/A		N/A

	For the nine months ended September 30, 2014
	(Loss)		Units		Per-Unit
	(Numerator)		(Denominator)		Amount
Net (loss) available to the Common Units	$	(529,000)
Basic EPS
Net (loss) available to the Common Units		(529,000)		19,299,815	$	(0.03)
Effect of Dilutive Securities
Options		—		—
Diluted EPS
Net (loss) available to the Common Units		N/A		N/A		N/A

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BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES (Additional Information) (Details) (USD $)	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2014 Employees and Directors [Member]	Sep. 30, 2013 Employees and Directors [Member]	Sep. 30, 2014 Central Energy GP LLC [Member]	Nov. 26, 2013 Central Energy GP LLC [Member]	Nov. 26, 2013 General Partner [Member]	Nov. 26, 2013 General Partner [Member] Common Units And Performance Warrants [Member]	Nov. 26, 2013 General Partner [Member] Common Units [Member]	Nov. 26, 2013 General Partner [Member] Common Units [Member] Cushing MLP Opportunity Fund I [Member]
Accounting Policies [Line Items]
Percentage Of Ownership Of Outstanding Common Shares Or Any Class Of Shares After Amendment Of Articles Of Incorporation	98.00%
Percentage Of Ownership Interests Sold	100.00%
Common Unit Purchased						3,000,000
Percentage Of Ownership Interests				2.00%
Number Of Subsidiaries	2
Sale Of Interest In General Partner					55.00%		26.60%	15.00%	39.10%
Unit-Based Payment Costs		$ 60,000	$ 16,000

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401K (Additional Information) (Details)	9 Months Ended
	Sep. 30, 2014
Four Zero One K Discretionary Match	50.00%
Employer Percentage Match Contribution Of Eligible Compensation Up to Maximum Annual Contribution	6.00%
Percentage Of Maximum Contribution Of Employees	60.00%

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CONSOLIDATED STATEMENT OF PARTNERS' DEFICIT (USD $)	3 Months Ended	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2014
Beginning Balance		$ (326,000)
Unit based compensation		60,000
Net loss	(133,000)	(540,000)
Ending Balance	(806,000)	(806,000)
Common Units [Member]
Beginning Balance		(319,000)
Beginning Balance (in shares)		19,066,482
Unit based compensation		59,000
Unit based compensation (in shares)		525,000
Net loss		(529,000)
Ending Balance	(789,000)	(789,000)
Ending Balance (in shares)	19,591,482	19,591,482
General Partner’s Deficit [Member]
Beginning Balance		(7,000)
Unit based compensation		1,000
Net loss		(11,000)
Ending Balance	$ (17,000)	$ (17,000)

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PROPERTY, PLANT AND EQUIPMENT

9 Months Ended

Sep. 30, 2014

Property, Plant and Equipment [Abstract]

PROPERTY, PLANT AND EQUIPMENT

NOTE D - PROPERTY, PLANT AND EQUIPMENT

	December 31,		September 30,
	2013		2014
Land	$	512,000	$	512,000
Terminal and improvements		4,955,000		5,755,000
Automotive equipment		1,297,000		1,297,000
		6,764,000		7,564,000
Less: accumulated depreciation and amortization		(3,606,000)		(4,019,000)
	$	3,158,000	$	3,545,000

Depreciation expense of property, plant and equipment totaled $134,000 and $140,000 for the three months ended September 30, 2013 and 2014 and $402,000 and $413,000 for the nine months ended September 30, 2013 and 2014, respectively.

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PARTNERS' DEFICIT (Additional Information) (Details) (USD $)	9 Months Ended
	Sep. 30, 2014	Dec. 31, 2013
Limited Partners' Capital Account [Line Items]
Interest Held in General Partner	2.00%
Percentage Of Ownership Of Outstanding Common Shares Or Any Class Of Shares After Amendment Of Articles Of Incorporation	98.00%
Percentage Of Ownership Interests Sold	100.00%
Common Unit, Outstanding	19,591,482
Partners Capital	$ (806,000)	$ (326,000)
General Partners Capital Account	$ (17,000)	$ (7,000)

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INCOME TAXES (Additional Information) (Details) (USD $)	1 Months Ended
	Nov. 30, 2013 Partnership [Member]	Nov. 30, 2013 2012 Tax Return [Member]	Sep. 30, 2014 IRS [Member]
Income Tax Examination, Liability (Refund) Adjustment from Settlement with Taxing Authority		$ 142,000
Income Tax Examination Penalties Expense Under Short Tax Year Return	296,000
Income Tax Examination, Penalties Accrued			$ 142,000

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BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES (Policies)

9 Months Ended

Sep. 30, 2014

Accounting Policies [Abstract]

Basis of Presentation

Basis of Presentation

The accompanying consolidated financial statements include the Partnership and its only operating subsidiary, Regional. We have two other subsidiaries that have no operations – Rio Vista Operating Partnership, LP (“RVOP”) and Rio Vista Operating GP LLC. All significant intercompany accounts and transactions are eliminated.

The unaudited consolidated balance sheet as of September 30, 2014, the unaudited consolidated statements of operations for the three months and nine months ended September 30, 2013 and 2014 and the unaudited consolidated statements of cash flows and of partners’ deficit for the nine months ended September 30, 2014, have been prepared by us without audit. In our opinion, 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, 2014, the unaudited consolidated results of operations for the three months and nine months ended September 30, 2013 and 2014 and the unaudited consolidated statements of cash flows and of partners’ deficit for the nine months ended September 30, 2014.

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 we believe that the disclosures made are adequate to make the information not misleading. These unaudited consolidated financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2013 filed with the Securities and Exchange Commission.

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.

Use of Estimates

Use of Estimates

The preparation of financial statements in conformity with generally accepted accounting principles requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclose contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates, and such differences could be material.

Cash Equivalents

Cash Equivalents

We consider all highly liquid investments with maturities of three months or less when purchased to be cash equivalents.

Financial Instruments

Financial Instruments

The fair values of our financial instruments, which may include cash, accounts receivable, accounts payable and long-term debt, approximate their carrying amounts.

Distributions of Available Cash

Distributions of Available Cash

In March 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 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 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 General Partner for making such distributions.

Environmental Obligations

Environmental Obligations

We are subject to various federal, state and local laws and regulations relating to the protection of the environment. We have established procedures for the ongoing evaluation of our operations, to identify potential environmental exposures, and to comply with regulatory policies and procedures. We account 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. We maintain insurance which may cover in whole or in part certain types of environmental contingencies. For the quarters ended September 30, 2013 and 2014, we had no environmental contingencies requiring specific disclosure or the recording of a liability.

Unit Based Compensation

Unit Based Compensation

We 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. We apply 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. We did not record any costs for unit-based payment costs for non-employees for the nine months ended September 30, 2013 and 2014, respectively under the fair-value provisions of ASC 505.

The Partnership applies ASC 718 for options, Common Units or other equity-based grants to our employees and directors of the General Partner. 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, we 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. We recorded $16,000 and $60,000 for unit-based payment costs for employees and directors for the nine months ended September 30, 2013 and 2014, respectively, under the fair-value provisions of ASC 718. See “Note F – Unit Options and Equity Incentive Plan – Incentive Plans” below for information regarding equity-based grants made during the nine months ended September 30, 2014.