UNITED STATES SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D.C. 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, 2003 OR [ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission File Number	Exact name of registrants as specified in their charters, State of Organization, address of principal executive offices and registrants' telephone number	IRS Employer Identification Number

33-87902	ESI TRACTEBEL FUNDING CORP. (a Delaware corporation)	04-3255377
33-87902-02	NORTHEAST ENERGY ASSOCIATES, A LIMITED PARTNERSHIP (a Massachusetts limited partnership)	04-2955642
33-87902-01	NORTH JERSEY ENERGY ASSOCIATES, A LIMITED PARTNERSHIP (a New Jersey limited partnership)	04-2955646
333-52397	ESI TRACTEBEL ACQUISITION CORP. (a Delaware corporation)	65-0827005
333-52397-01	NORTHEAST ENERGY, LP (a Delaware limited partnership)	65-0811248
c/o FPL Energy, LLC 700 Universe Boulevard Juno Beach, Florida 33408 (561) 691-7171

Indicate by check mark whether the registrants (1) have 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 and (2) have been subject to such filing requirements for the past 90 days. Yes [X] No [ ]
Indicate by check mark whether the registrants are accelerated filers (as defined in Rule 12b-2 of the Securities Exchange Act of 1934). Yes [ ] No [X]

APPLICABLE ONLY TO CORPORATE ISSUERS:
As of October 31, 2003, there were issued and outstanding 10,000 shares of ESI Tractebel Funding Corp.'s common stock. As of October 31, 2003, there were issued and outstanding 20 shares of ESI Tractebel Acquisition Corp.'s common stock.

This combined Form 10-Q represents separate filings by ESI Tractebel Funding Corp., Northeast Energy Associates, a limited partnership, North Jersey Energy Associates, a limited partnership, ESI Tractebel Acquisition Corp. and Northeast Energy, LP. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Each registrant makes representations only as to itself and makes no representations whatsoever as to any other registrant.

CAUTIONARY STATEMENTS AND RISK FACTORS THAT MAY AFFECT FUTURE RESULTS
In connection with the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 (Reform Act), ESI Tractebel Funding Corp. (Funding Corp.), Northeast Energy Associates, a limited partnership (NEA) and North Jersey Energy Associates, a limited partnership (NJEA) (collectively, the Partnerships), ESI Tractebel Acquisition Corp. (Acquisition Corp.) and Northeast Energy, LP (NE LP) (all five entities collectively, the registrants) are hereby filing cautionary statements identifying important factors that could cause the registrants' actual results to differ materially from those projected in forward-looking statements (as such term is defined in the Reform Act) made by or on behalf of the registrants in this combined Form 10-Q, in presentations, in response to questions or otherwise. Any statements that express, or involve discussions as to expectations, beliefs, plans, objectives, assumptions or future events or performance (often, but not always, through the use of words or phrases such as "will likely result," "are expected to," "will continue," "is anticipated," "believe," "could," "estimated," "may," "plan," "potential," "projection," "target," "outlook") are not statements of historical facts and may be forward-looking. Forward-looking statements involve estimates, assumptions and uncertainties. Accordingly, any such statements are qualified in their entirety by reference to, and are accompanied by, the following important factors (in addition to any assumptions and other factors referred to specifically in connection with such forward-looking statements) that could cause the registrants' actual results to differ materially from those contained in forward-looking statements made by or on behalf of the registrants.
Any forward-looking statement speaks only as of the date on which such statement is made, and the registrants undertake no obligation to update any forward-looking statement to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events. New factors emerge from time to time, and it is not possible for management to predict all of such factors, nor can it assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statement.
The following are some important factors that could have a significant impact on the registrants' operations and financial results, and could cause the registrants' actual results or outcomes to differ materially from those discussed in the forward-looking statements:
·	The registrants are subject to changes in laws or regulations, including the Public Utility Regulatory Policies Act of 1978, as amended (PURPA), changing governmental policies and regulatory actions, including those of the Federal Energy Regulatory Commission (FERC), with respect to, but not limited to, acquisition and disposal of assets and facilities, and present or prospective competition.
·	The registrants are subject to extensive federal, state and local environmental statutes, rules and regulations relating to air quality, water quality, waste management, natural resources and health and safety that could, among other things, restrict or limit the output of certain facilities or the use of certain fuels required for the production of electricity and/or increase costs. There are significant capital, operating and other costs associated with compliance with these environmental statutes, rules and regulations, and those costs could be even more significant in the future.
·	The registrants operate in a changing market environment influenced by various legislative and regulatory initiatives regarding deregulation, regulation or restructuring of the energy industry, including deregulation of the production and sale of electricity. The registrants will need to adapt to these changes and may face increasing competitive pressure.
·	The Partnerships were developed and are operated as qualifying facilities (QFs) under PURPA and the regulations promulgated thereunder by the FERC. FERC regulations require that at least 5% of a QF's total energy output be useful thermal energy. To meet this requirement, the Partnerships sell steam under long-term sales agreements to two unrelated third parties for use in gas and chemical processing facilities to maintain their QF status. The Partnerships are dependent upon the on-going operations of these facilities. Loss of QF status would entitle one power purchaser to renegotiate the price provisions of its power purchase agreement and one power purchaser to terminate its power purchase agreement.
·	A substantial portion of the output from the Partnerships' power generation facilities is sold under long-term power purchase agreements to four regulated utilities, two of which are under common control. The limited number of power purchasers creates a concentration of counterparty risk. The remaining output from the power generation facilities is sold, from time to time, in the merchant markets. In addition, it is expected that upon expiration of the power purchase agreements, the residual portion of the electrical output will be sold in the merchant market. Merchant plants sell power based on market conditions at the time of sale. The amount and timing of revenues to be received from the merchant markets in the future is uncertain.
·	The operation of power generation facilities involves many risks, including start up risks, breakdown or failure of equipment, transmission lines or pipelines, use of new technology, the dependence on a specific fuel source or the impact of unusual or adverse weather conditions (including natural disasters), as well as the risk of performance below expected levels of output or efficiency. This could result in lost revenues and/or increased expenses. Insurance, warranties or performance guarantees may not cover any or all of the lost revenues or increased expenses, including the cost of replacement power. Breakdown or failure of an operating facility may prevent the facility from performing under applicable power sales agreements which, in certain situations, could result in termination of the agreement or payment of liquidated damages.
·	The registrants use derivative instruments, such as swaps and options, to manage their commodity and financial market risks. The registrants could recognize financial losses as a result of volatility in the market values of these contracts, or if a counterparty fails to perform. In the absence of actively quoted market prices and pricing information from external sources, the valuation of these derivative instruments involves management's judgment or use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the value of the reported fair value of these contracts.
·	In addition to risks discussed elsewhere, risk factors specifically affecting the registrants' success include the ability to efficiently operate generating assets, the successful and timely completion of project restructuring activities, the price and supply of fuel, transmission constraints, competition from new sources of generation, excess generation capacity and demand for power. There can be significant volatility in market prices for fuel, and there are other financial, counterparty and market risks that are beyond the control of the registrants. The registrants' inability or failure to effectively hedge their assets or positions against changes in commodity prices, interest rates, counterparty credit risk or other risk measures could significantly impair their future financial results.
·	The registrants' results of operations can be affected by changes in the weather. Severe weather can be destructive, causing outages and/or property damage, which could require additional costs to be incurred.
·	The registrants are subject to costs and other effects of legal and administrative proceedings, settlements, investigations and claims; as well as the effect of new, or changes in, tax rates or policies, rates of inflation, accounting standards, securities laws or corporate governance requirements.
·	The registrants are subject to direct and indirect effects of terrorist threats and activities. Generation and transmission facilities, in general, have been identified as potential targets. The effects of terrorist threats and activities include, among other things, terrorist actions or responses to such actions or threats, the inability to generate, purchase or transmit power, the risk of a significant slowdown in growth or a decline in the U.S. economy, delay in economic recovery in the U.S., and the increased cost and adequacy of security and insurance.
·	The registrants' ability to obtain insurance, and the cost of and coverage provided by such insurance, could be affected by national events as well as registrant-specific events.
·	The registrants are substantially leveraged. The ability of the registrants to make interest and principal payments and fund capital expenditures is dependent on the future performance of the Partnerships. Future performance is subject to general economic, financial, competitive, legislative, regulatory and other factors that are beyond the control of the registrants. The registrants are also subject to restrictive covenants under their debt agreements that will limit the ability to borrow additional funds.
·	All obligations of the Partnerships are non-recourse to the direct and indirect owners of the registrants. Following any default by the Partnerships, security is limited to the owners' economic interests in the Partnerships. The owners have no meaningful revenues other than the distributions they receive from the Partnerships. In the event of default, the ability of the owners to satisfy any obligations will be limited to amounts payable by the Partnerships as distributions.
The issues and associated risks and uncertainties described above are not the only ones the registrants may face. Additional issues may arise or become material as the energy industry evolves. The risks and uncertainties associated with these additional issues could impair the registrants' businesses in the future.

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements

NORTHEAST ENERGY, LP (A PARTNERSHIP) AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS

(Thousands of Dollars)
(Unaudited)

						September 30, 2003			December 31, 2002

ASSETS
Current assets:
	Cash and cash equivalents					$	89,719		$	45,878
	Accounts receivable						47,445			42,632
	Due from related party						2,764			1,623
	Spare parts inventories						12,029			9,735
	Fuel inventories						11,557			7,832
	Prepaid expenses and other current assets						2,912			7,900

				Total current assets			166,426			115,600


Non-current assets:
		Deferred debt issuance costs (net of accumulated amortization of $3,516 and $3,067, respectively)					3,443			3,893
		Land					4,712			4,712
		Cogeneration facilities and carbon dioxide facility (net of accumulated depreciation of $123,479 and $108,583, respectively)					395,664			410,509
		Power purchase agreements (net of accumulated amortization of $304,050 and $260,595, respectively)					584,706			628,161
		Other assets					5			7

					Total non-current assets		988,530			1,047,282


TOTAL ASSETS						$	1,154,956		$	1,162,882


LIABILITIES AND PARTNERS' EQUITY
Current liabilities:
	Current portion of notes payable - the Funding Corp.					$	26,191		$	23,818
	Current portion of note payable - the Acquisition Corp.						8,800			8,800
	Accounts payable						12,731			16,689
	Accrued interest payable - the Funding Corp. and the Acquisition Corp.						12,808			-
	Due to related parties						14,649			7,425
	Other accrued expenses						11,108			8,495

			Total current liabilities				86,287			65,227


Non-current liabilities:
		Deferred credit - fuel contract					111,047			161,039
		Notes payable - the Funding Corp.					337,932			352,214
		Note payable - the Acquisition Corp.					198,000			202,400
		Energy bank and other liabilities					112,035			146,868
		Lease payable					827			878

					Total non-current liabilities		759,841			863,399


COMMITMENTS AND CONTINGENCIES

Partners' equity:
	General partners						6,043			4,482
	Limited partners						303,023			226,571
	Accumulated other comprehensive income (loss)						(238	)		3,203

			Total partners' equity				308,828			234,256


TOTAL LIABILITIES AND PARTNERS' EQUITY						$	1,154,956		$	1,162,882

This report should be read in conjunction with the Notes to Condensed Consolidated Financial Statements herein and the Notes to Consolidated and Combined Financial Statements appearing in the combined Annual Report on Form 10-K for the fiscal year ended December 31, 2002 (2002 Form 10-K) for NE LP and Subsidiaries.

NORTHEAST ENERGY, LP (A PARTNERSHIP) AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Thousands of Dollars)
(Unaudited)

					Three Months Ended September 30,					Nine Months Ended September 30,

					2003			2002			2003			2002

REVENUES				$	101,824		$	104,715		$	309,342		$	297,659


COSTS AND EXPENSES (INCOME):
	Fuel				48,159			44,312			147,993			133,819
	Operations and maintenance				3,334			3,157			10,439			10,505
	Depreciation and amortization				19,659			19,501			58,351			57,330
	General and administrative				2,402			2,141			7,150			6,113
	Gain on energy bank settlement				-			-			(11,112	)		-

			Total costs and expenses		73,554			69,111			212,821			207,767


OPERATING INCOME					28,270			35,604			96,521			89,892


OTHER EXPENSE (INCOME):
		Gain on restructuring of contracts			(15,198	)		-			(15,198	)		-
		Amortization of debt issuance costs			151			155			449			468
		Interest expense			15,871			16,910			48,695			51,767
		Interest income			(50	)		(144	)		(428	)		(545	)
		Other income			(97	)		-			(294	)		-
		Change in fair value of derivatives			352			(14	)		3,780			(3,492	)

			Total other expense - net		1,029			16,907			37,004			48,198


NET INCOME				$	27,241		$	18,697		$	59,517		$	41,694

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Thousands of Dollars)
(Unaudited)

			Nine Months Ended September 30,

				2003			2002

NET CASH PROVIDED BY OPERATING ACTIVITIES			$	65,702		$	63,834


CASH FLOWS FROM INVESTING ACTIVITIES:
	Capital expenditures			(48	)		(1,841	)

		Net cash used in investing activities		(48	)		(1,841	)


CASH FLOWS FROM FINANCING ACTIVITIES:
	Principal payment on the Funding Corp. notes			(11,909	)		(11,340	)
	Principal payment on the Acquisition Corp. note			(4,400	)		(4,400	)
	Distributions to partners			(5,504	)		(30,878	)

		Net cash used in financing activities		(21,813	)		(46,618	)


Net increase in cash and cash equivalents				43,841			15,375
Cash and cash equivalents at beginning of period				45,878			45,003

Cash and cash equivalents at end of period			$	89,719		$	60,378


SUPPLEMENTAL SCHEDULE OF NONCASH FINANCING ACTIVITIES
	Assumption of liability by partners		$	24,000		$	-

These reports should be read in conjunction with the Notes to Condensed Consolidated Financial Statements herein and the Notes to Consolidated and Combined Financial Statements appearing in the 2002 Form 10-K for NE LP and Subsidiaries.

NORTHEAST ENERGY ASSOCIATES, A LIMITED PARTNERSHIP AND
NORTH JERSEY ENERGY ASSOCIATES, A LIMITED PARTNERSHIP
CONDENSED COMBINED BALANCE SHEETS

(Thousands of Dollars)
(Unaudited)

						September 30, 2003			December 31, 2002

ASSETS
Current assets:
	Cash and cash equivalents					$	88,777		$	44,943
	Accounts receivable						47,445			42,632
	Due from related party						2,764			1,616
	Spare parts inventories						12,029			9,735
	Fuel inventories						11,557			7,832
	Prepaid expenses and other current assets						2,906			7,892

				Total current assets			165,478			114,650


Non-current assets:
		Land					4,712			4,712
		Cogeneration facilities and carbon dioxide facility (net of accumulated depreciation of $123,479 and $108,583, respectively)					395,664			410,509
		Power purchase agreements (net of accumulated amortization of $304,050 and $260,595, respectively)					584,706			628,161
		Other assets					5			7

					Total non-current assets		985,087			1,043,389


TOTAL ASSETS						$	1,150,565		$	1,158,039


LIABILITIES AND PARTNERS' EQUITY
Current liabilities:
	Current portion of notes payable - the Funding Corp.					$	26,191		$	23,818
	Accounts payable						12,731			16,689
	Accrued interest payable - the Funding Corp.						8,677			-
	Due to related parties						14,303			7,430
	Other accrued expenses						11,108			8,495

			Total current liabilities				73,010			56,432


Non-current liabilities:
		Deferred credit - fuel contract					111,047			161,039
		Notes payable - the Funding Corp.					337,932			352,214
		Energy bank and other liabilities					111,883			146,716
		Lease payable					827			878

					Total non-current liabilities		561,689			660,847


COMMITMENTS AND CONTINGENCIES

Partners' equity:
	General partners						5,161			4,376
	Limited partners						510,943			433,181
	Accumulated other comprehensive income (loss)						(238	)		3,203

			Total partners' equity				515,866			440,760


TOTAL LIABILITIES AND PARTNERS' EQUITY						$	1,150,565		$	1,158,039

This report should be read in conjunction with the Notes to Condensed Combined Financial Statements herein and the Notes to Consolidated and Combined Financial Statements appearing in the 2002 Form 10-K for NEA and NJEA.

NORTHEAST ENERGY ASSOCIATES, A LIMITED PARTNERSHIP AND
NORTH JERSEY ENERGY ASSOCIATES, A LIMITED PARTNERSHIP

CONDENSED COMBINED STATEMENTS OF OPERATIONS

(Thousands of Dollars)
(Unaudited)

				Three Months Ended September 30,						Nine Months Ended September 30,

				2003			2002			2003			2002

REVENUES				$	101,930		$	104,715		$	309,687		$	297,659


COSTS AND EXPENSES (INCOME):
	Fuel				48,159			44,312			147,993			133,819
	Operations and maintenance				3,334			3,157			10,439			10,505
	Depreciation and amortization				19,659			19,501			58,351			57,330
	General and administrative				2,402			2,141			7,150			6,113
	Gain on energy bank settlement				-			-			(11,112	)		-

			Total costs and expenses		73,554			69,111			212,821			207,767


OPERATING INCOME					28,376			35,604			96,866			89,892


OTHER EXPENSE (INCOME):
		Gain on restructuring of contracts			(15,198	)		-			(15,198	)		-
		Interest expense			11,737			12,603			36,045			38,671
		Interest income			(49	)		(141	)		(406	)		(498	)
		Other income			(97	)		-			(306	)		-
		Change in fair value of derivatives			352			(14	)		3,780			(3,492	)

			Total other (income) expense - net		(3,255	)		12,448			23,915			34,681


NET INCOME				$	31,631		$	23,156		$	72,951		$	55,211

CONDENSED COMBINED STATEMENTS OF CASH FLOWS

(Thousands of Dollars)
(Unaudited)

			Nine Months Ended September 30,

			2003			2002

NET CASH PROVIDED BY OPERATING ACTIVITIES			$	85,307		$	72,562


CASH FLOWS FROM INVESTING ACTIVITIES:
	Capital expenditures			(48	)		(1,841	)

		Net cash used in investing activities		(48	)		(1,841	)


CASH FLOWS FROM FINANCING ACTIVITIES:
	Principal payment on the Funding Corp. notes			(11,909	)		(11,340	)
	Distributions to partners			(29,516	)		(44,067	)

		Net cash used in financing activities		(41,425	)		(55,407	)


Net increase in cash and cash equivalents				43,834			15,314
Cash and cash equivalents at beginning of period				44,943			43,969

Cash and cash equivalents at end of period			$	88,777		$	59,283


SUPPLEMENTAL SCHEDULE OF NONCASH FINANCING ACTIVITIES
	Assumption of liabilities by parent company		$	35,112		$	-

These reports should be read in conjunction with the Notes to Condensed Combined Financial Statements herein and the Notes to Consolidated and Combined Financial Statements appearing in the 2002 Form 10-K for NEA and NJEA.

ESI TRACTEBEL FUNDING CORP.

CONDENSED BALANCE SHEETS

(Thousands of Dollars)
(Unaudited)

			September 30, 2003		December 31, 2002

ASSETS
Current assets:
	Cash		$	1	$	1
	Interest receivable from the Partnerships			8,677		-
	Current portion of notes receivable from the Partnerships			26,191		23,818

		Total current assets		34,869		23,819

Notes receivable from the Partnerships				337,932		352,214


TOTAL ASSETS			$	372,801	$	376,033


LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
	Current portion of debt securities payable		$	26,191	$	23,818
	Accrued interest payable			8,677		-

		Total current liabilities		34,868		23,818

Debt securities payable				337,932		352,214

COMMITMENTS AND CONTINGENCIES

Stockholders' equity:
	Common stock, no par value, 10,000 shares authorized, issued and outstanding			1		1


TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY			$	372,801	$	376,033

CONDENSED STATEMENTS OF OPERATIONS

(Thousands of Dollars)
(Unaudited)

	Three Months Ended September 30,						Nine Months Ended September 30,

	2003			2002			2003			2002

Interest income	$	8,677		$	9,219		$	26,586		$	28,176
Interest expense		(8,677	)		(9,219	)		(26,586	)		(28,176	)


NET INCOME	$	-		$	-		$	-		$	-

These reports should be read in conjunction with the Notes to Condensed Financial Statements herein and the Notes to Financial Statements appearing in the 2002 Form 10-K for the Funding Corp.

ESI TRACTEBEL FUNDING CORP.
CONDENSED STATEMENTS OF CASH FLOWS

(Thousands of Dollars)
(Unaudited)

			Nine Months Ended September 30,

			2003			2002

NET CASH PROVIDED BY OPERATING ACTIVITIES			$	-		$	-


CASH FLOWS FROM INVESTING ACTIVITIES:
	Principal payment received from the Partnerships			11,909			11,340

		Net cash provided by investing activities		11,909			11,340


CASH FLOWS FROM FINANCING ACTIVITIES:
	Principal payment on debt			(11,909	)		(11,340	)

		Net cash used in financing activities		(11,909	)		(11,340	)


Net increase in cash				-			-
Cash at beginning of period				1			1

Cash at end of period			$	1		$	1

This report should be read in conjunction with the Notes to Condensed Financial Statements herein and the Notes to Financial Statements appearing in the 2002 Form 10-K for the Funding Corp.

ESI TRACTEBEL ACQUISITION CORP.

CONDENSED BALANCE SHEETS

(Thousands of Dollars)
(Unaudited)

				September 30, 2003		December 31, 2002

ASSETS
Current assets:
	Interest receivable from NE LP			$	4,131	$	-
	Current portion of note receivable from NE LP				8,800		8,800

			Total current assets		12,931		8,800


Non-current assets:
	Due from NE LP				152		152
	Note receivable from NE LP				198,000		202,400

			Total non-current assets		198,152		202,552


TOTAL ASSETS				$	211,083	$	211,352


LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
	Income taxes payable			$	26	$	23
	Current portion of debt securities payable				8,800		8,800
	Accrued interest payable				4,131		-

		Total current liabilities			12,957		8,823


Non-current liabilities:
	Debt securities payable				198,000		202,400
	Other				75		85

			Total non-current liabilities		198,075		202,485


COMMITMENTS AND CONTINGENCIES

Stockholders' equity:
	Common stock, $.10 par value, 100 shares authorized, 20 shares issued and outstanding				-		-
	Retained earnings				51		44


TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY				$	211,083	$	211,352

CONDENSED STATEMENTS OF OPERATIONS

(Thousands of Dollars)
(Unaudited)

	Three Months Ended September 30,						Nine Months Ended September 30,

	2003			2002			2003			2002

Interest income	$	4,131		$	4,307		$	12,568		$	13,096
Interest expense		(4,127	)		(4,303	)		(12,558	)		(13,085	)

Income before income taxes		4			4			10			11
Income tax expense		(1	)		(1	)		(3	)		(4	)


NET INCOME	$	3		$	3		$	7		$	7

These reports should be read in conjunction with the Notes to Condensed Financial Statements herein and the Notes to Financial Statements appearing in the 2002 Form 10-K for the Acquisition Corp.

ESI TRACTEBEL ACQUISITION CORP.
CONDENSED STATEMENTS OF CASH FLOWS

(Thousands of Dollars)
(Unaudited)

			Nine Months Ended September 30,

			2003			2002

NET CASH PROVIDED BY OPERATING ACTIVITIES			$	-		$	-


CASH FLOWS FROM INVESTING ACTIVITIES:
	Principal payment received from NE LP			4,400			4,400

		Net cash provided by investing activities		4,400			4,400


CASH FLOWS FROM FINANCING ACTIVITIES:
	Principal payment on debt			(4,400	)		(4,400	)

		Net cash used in financing activities		(4,400	)		(4,400	)


Net increase in cash				-			-
Cash at beginning of period				-			-

Cash at end of period			$	-		$	-

This report should be read in conjunction with the Notes to Condensed Financial Statements herein and the Notes to Financial Statements appearing in the 2002 Form 10-K for the Acquisition Corp.

NORTHEAST ENERGY, LP (A PARTNERSHIP) AND SUBSIDIARIES
NORTHEAST ENERGY ASSOCIATES, A LIMITED PARTNERSHIP AND
NORTH JERSEY ENERGY ASSOCIATES, A LIMITED PARTNERSHIP
ESI TRACTEBEL FUNDING CORP.
ESI TRACTEBEL ACQUISITION CORP.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
NOTES TO CONDENSED COMBINED FINANCIAL STATEMENTS
NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

The accompanying condensed consolidated financial statements, condensed combined financial statements and condensed financial statements should be read in conjunction with the 2002 Form 10-K for the registrants. In the opinion of the registrants' management, all adjustments (consisting of normal recurring accruals) considered necessary for fair financial statement presentation have been made. Certain amounts included in prior year's consolidated and combined financial statements have been reclassified to conform to the current year's presentation. The results of operations for an interim period may not give a true indication of results for the year.

1. Combined Statement of Partners' Equity

NEA's and NJEA's general partner (GP) and limited partner (LP) equity balances are comprised of the following:

	NEA						NJEA						Combined

	GP		LP		Total		GP		LP		Total		GP		LP		Total

	(Thousands of Dollars)

Balances, December 31, 2002	$	1,158	$	114,666	$	115,824	$	3,218	$	318,515	$	321,733	$	4,376	$	433,181	$	437,557	^(a)
Balances, September 30, 2003	$	1,847	$	182,924	$	184,771	$	3,314	$	328,019	$	331,333	$	5,161	$	510,943	$	516,104	^(b)


(a)	Exclusive of accumulated other comprehensive income of $3,203.
(b)	Exclusive of accumulated other comprehensive loss of $238.

2. Accounting for Derivative Instruments and Hedging Activities

Accumulated other comprehensive income (loss) is separately displayed in NE LP's and the Partnerships' balance sheets. Included in NE LP's and the Partnerships' accumulated other comprehensive income (loss) at September 30, 2003 is approximately $0.2 million of net unrealized losses associated with cash flow hedges of forecasted fuel purchases through December 2004, of which $0.1 million is expected to be reclassified into earnings within the next twelve months. NE LP and the Partnerships reclassified a net gain of approximately $3.6 million and $15.7 million into earnings from accumulated other comprehensive income (loss) for the three and nine months ended September 30, 2003, respectively. The effective portion of the net gain (loss) on cash flow hedges included within other comprehensive income (loss) was a net loss of approximately $8.0 million and a net gain of approximately $1.1 million for the three months ended September 30, 2003 and 2002, respectively. The effective portion of the net gain on cash flow hedges included within other comprehensive income (loss) was approximately $12.2 million and $7.8 million for the nine months ended September 30, 2003 and 2002, respectively.

Effective July 1, 2003, NE LP and the Partnerships adopted Statement of Financial Accounting Standards No. (FAS) 149, "Amendment of Statement 133 on Derivative Instruments and Hedging Activities" (FAS 149). The statement amends and clarifies financial accounting and reporting for derivative instruments, including derivative instruments embedded in other contracts, and for hedging activities. There was no financial statement impact upon adoption of FAS 149.

In August 2003, the Emerging Issues Task Force (EITF) released Issue No. 03-11 (EITF 03-11), which provides guidance on whether to report realized gains or losses on physically settled derivative contracts not held for trading purposes on a gross or net basis and requires realized gains or losses on derivative contracts that net settle to be reported on a net basis. Currently, NE LP and the Partnerships generally report contracts requiring physical delivery of a commodity on a gross basis. The new guidance is effective October 1, 2003. NE LP and the Partnerships are evaluating the effect the new guidance will have on their financial statements in the future.

Recently, the staff of the Securities and Exchange Commission (SEC) indicated that the realized and unrealized effects of derivative instruments not accounted for as hedges should be reported within the same caption on the statements of operations. Currently, NE LP and the Partnerships reflect unrealized gains and losses for their derivative instruments not accounted for as hedges in a different caption in the statements of operations than realized gains and losses for these instruments. NE LP and the Partnerships expect to adopt the new guidance as soon as practicable. NE LP and the Partnerships are evaluating the effect the new guidance will have on their financial statements in the future.

3. Comprehensive Income

Comprehensive income below includes net income and net unrealized gains (losses) on cash flow hedges of forecasted fuel purchases for both NE LP and the Partnerships of approximately $(11.6) million and $(0.4) million for the three months ended September 30, 2003 and 2002, respectively, and approximately $(3.4) million and $4.1 million for the nine months ended September 30, 2003 and 2002, respectively.

	Three Months Ended September 30,				Nine Months Ended September 30,

	2003		2002		2003		2002

	(Thousands of Dollars)

NE LP (Consolidated)	$	15,699	$	18,346	$	56,085	$	45,837
The Partnerships (Combined)	$	20,080	$	22,805	$	69,510	$	59,354

4. Commitments and Contingencies

The long-term contractual obligations of NE LP and the Partnerships at September 30, 2003 by fiscal year due are as follows:

NE LP AND THE PARTNERSHIPS
September 30, 2003

(Thousands of Dollars)

		2003		2004 - 05		2006 - 07		Thereafter		Total

CONTRACTUAL OBLIGATIONS

Long-term debt		$	16,309	$	91,513	$	141,861	$	321,240	$	570,923
Operating leases			63		534		582		1,395		2,574
Other long-term obligations:
Energy bank liability			-		-		-		108,246		108,246
Administrative agreement^(a)			150		1,200		1,200		6,000		8,550
O&M agreement^(a)			375		3,000		3,000		12,000		18,375
Fuel management agreement^(a)			225		1,800		1,800		13,500		17,325

Total contractual obligations		$	17,122	$	98,047	$	148,443	$	462,381	$	725,993



(a)	Represents the minimum obligation under the terms of the agreement. The minimum obligation is subject to an annual inflation factor adjustment, which is excluded from the minimum obligation.
In February 2003, NJEA reached an agreement to modify the gas index used for calculating the energy price in an existing power purchase agreement with a New Jersey utility. The modification was necessary because the original index described in the power purchase agreement no longer existed at August 14, 2002. The new index rate, effective as of August 14, 2002 and adjusted annually on that date, resulted in an increase of $9.2 million in revenue to NJEA, which was paid in March 2003 of which $7.7 million pertains to 2002. In November 2003, this agreement was approved by the New Jersey Board of Public Utilities.
5. Energy Bank Balances
NEA and NJEA sell substantially all their output under power purchase agreements. Two of the power purchase agreements required the establishment of energy banks to record cumulative payments made by the utilities in excess of avoided cost rates scheduled or specified in such agreements. The energy bank balances bear interest at various rates specified in the agreements. Upon termination of the agreements, with the exception of the NEA power purchase agreement discussed below, some or all of the remaining amounts recorded in the energy banks will be required to be repaid. The energy bank balances are partially secured by letters of credit.
On December 31, 2000, NEA exercised its option to receive a reduced energy payment for the period remaining on one of the power purchase agreements (PPA) in lieu of paying the energy bank balance existing as of that date. The $24.9 million balance as of December 31, 2000 was being amortized into revenue on a straight-line basis over the remaining life of the agreement which expires on September 15, 2021. NEA's accounting treatment reflected the position that, as of December 31, 2000, the energy bank balance represented deferred revenue and was being reduced for the discounted amount of the energy payments on a straight-line basis over the remaining life of the PPA. The power purchaser (Power Purchaser) disputed this position. The Power Purchaser contended that the energy bank balance was being adjusted monthly and could require a significant payment by NEA upon termination. On October 31, 2002, the Power Purchaser filed a demand for arbitration with the American Arbitration Association in this matter.
On March 31, 2003, the PPA was restructured resulting in an $11.1 million gain for NEA. In connection with this restructuring, a settlement of the disputes in connection with the arbitration was reached between NE LP, acting on its behalf and on behalf of NEA, and another company (Agent), acting on its behalf and on behalf of the Power Purchaser. The registrants understand that, under a 1998 power purchase agreement between the Power Purchaser and the Agent (Agent PPA), the Agent acts as agent and representative of the Power Purchaser with respect to the PPA. Under the terms of the settlement, the arbitration was irrevocably dismissed and the related claims released, any energy bank obligations under the PPA were terminated, the energy bank balance of $22.2 million was eliminated, and NE LP paid approximately $11.1 million plus interest to the Agent in June 2003.
As a condition to this settlement, the Agent entered into an agreement (PMI Agreement) with FPL Energy, LLC's power marketing subsidiary, FPL Energy Power Marketing, Inc. (PMI). Under the terms of the PMI Agreement, until termination of the PPA, PMI is to purchase power from the Agent under the same terms as the Agent purchases power under the PPA, as the Power Purchaser's agent and representative pursuant to the Agent PPA. Also, under the PMI Agreement the parties agreed to seek approvals and satisfy conditions for NEA to terminate the PPA on or before December 31, 2003. Those approvals and conditions include approvals under the indentures relating to the Funding Corp. and Acquisition Corp. secured notes and bonds.
6. Fuel Supply Agreements
In March 2003, NEA bifurcated the fuel supply contract with one of its suppliers who provided approximately 65% of NEA's daily fuel requirements. In July 2003, NEA entered into two agreements with this supplier to terminate one of the agreements that provided for the purchase of 13,399 mmbtu/day (Termination Agreement) and to partially terminate the other agreement that provided for the purchase of 35,418 mmbtu/day (Partial Termination Agreement). These agreements were executed to hedge the Partnerships' exposure to natural gas prices in anticipation of other contract restructurings.
On August 31, 2003, the Termination Agreement was executed resulting in removal of a $39.2 million liability representing the unamortized deferred credit as of the termination date and a $15.2 million gain for NEA. In conjunction with this termination, NEA was to pay a termination fee of $24.0 million, of which $12.0 million was paid by the NE LP partners and recorded by NE LP as a capital contribution. Promissory notes were issued by the NE LP partners for the remaining $12.0 million. The notes bear interest at a rate of 6% per annum and are due no later than May 1, 2004.
NEA entered into two replacement long-term gas supply agreements with PMI and Tractebel Energy Marketing, Inc. (TEMI) which became effective September 1, 2003. These two contracts provide NEA with the same combined quantity of natural gas and with pricing that is expected to be more favorable over the term of the agreements. Affiliates of PMI and TEMI have guaranteed certain of their respective obligations under the long-term gas supply agreements.
Under the terms of the Partial Termination Agreement, the daily delivery of fuel may be reduced to 12,507 mmbtu/day. Implementation of this agreement is contingent upon certain conditions being met, including satisfaction of the relevant provisions of bond indentures.
7. Variable Interest Entities
In January 2003, the Financial Accounting Standards Board (FASB) issued FASB Interpretation No. (FIN) 46, "Consolidation of Variable Interest Entities." As a result, entities that are deemed to be variable interest entities (VIEs) in which any of the registrants is considered to be the "primary beneficiary" are to be consolidated. Variable interests are considered to be contractual, ownership or other monetary interests in an entity that fluctuate with changes in the entity's net asset value. An entity is considered to be a VIE when it has equity investors who lack the characteristics of having a controlling financial interest, or its capital is insufficient to permit it to finance its activities without additional subordinated financial support. Consolidation of a VIE by an investor is required when it is determined that the investor will absorb a majority of the VIE's expected losses or residual returns. In October 2003, the FASB deferred the required implementation date of FIN 46 until the fourth quarter of 2003. Under their current structure, none of the registrants believes it will be required to consolidate any VIEs beginning in the fourth quarter of 2003.
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations
This discussion should be read in conjunction with the Notes to Condensed Consolidated Financial Statements, Notes to Condensed Combined Financial Statements and Notes to Condensed Financial Statements contained herein (the Notes) and Management's Discussion and Analysis of Financial Condition and Results of Operations appearing in the 2002 Form 10-K for the registrants. The results of operations for an interim period may not give a true indication of results for the year. In the following discussion, all comparisons are with the corresponding items in the corresponding periods of the prior year.
Results of Operations
NE LP and the Partnerships - Net income increased for the three months ended September 30, 2003 primarily due to the gain recognized on restructuring of contracts and lower interest expense, partially offset by increased expenses, including fuel costs, and lower revenues. Net income increased for the nine months ended September 30, 2003 primarily due to the gains recognized on the energy bank settlement and restructuring of contracts, higher revenues and lower interest expense, partially offset by increased expenses, including fuel costs, and net unrealized mark-to-market losses on derivatives.
Revenues for the three months ended September 30, 2003 decreased primarily as a result of decreased electricity sales prices and lower volume due to curtailments. NE LP revenues for the three months ended September 30, 2003 and 2002 were comprised of $101.0 million and $103.7 million of power sales to utilities and $0.8 million and $1.0 million of steam sales, respectively. Partnerships' revenues for the three months ended September 30, 2003 and 2002 were comprised of $101.1 million and $103.7 million of power sales to utilities and $0.8 million and $1.0 million of steam sales, respectively. Power sales to utilities for NE LP and the Partnerships for the three months ended September 30, 2003 and 2002 reflect a decrease in utility energy bank balances which increased reported revenues by $6.4 million and $6.5 million, respectively. The decrease in the energy bank balances is determined in accordance with scheduled or specified rates under certain power purchase agreements.
Fuel expense for the three months ended September 30, 2003 increased primarily due to increased prices of natural gas required to fuel the facilities and lower deferred credit amortization for fuel contracts, partially offset by lower volume due to curtailments. Deferred credit amortization for fuel contracts for the three months ended September 30, 2003 and 2002 was $3.4 million and $5.2 million, respectively.
For the three months ended September 30, 2003 and 2002, NE LP and the Partnerships recorded net unrealized mark-to-market gains (losses) of $(0.4) million and $14.0 thousand, respectively, representing the net change in fair value of derivative instruments.
Revenues for the nine months ended September 30, 2003 increased primarily due to higher electricity sales prices and higher volume under certain power purchase agreements offset by lower volume at the Sayreville facility due to curtailments. NE LP revenues for the nine months ended September 30, 2003 and 2002 were comprised of $306.9 million and $294.7 million of power sales to utilities and $2.4 million and $3.0 million of steam sales, respectively. Partnerships' revenues for the nine months ended September 30, 2003 and 2002 were comprised of $307.3 million and $294.7 million of power sales to utilities and $2.4 million and $3.0 million of steam sales, respectively. Power sales to utilities for NE LP and the Partnerships for the nine months ended September 30, 2003 and 2002 reflect a decrease in utility energy bank balances which increased reported revenues by $20.9 million and $20.2 million, respectively. The decrease in the energy bank balances is determined in accordance with scheduled or specified rates under certain power purchase agreements.
Fuel expense for the nine months ended September 30, 2003 increased primarily as a result of increased prices of natural gas required to fuel the facilities and lower deferred credit amortization for fuel contracts, partially offset by lower volume due to curtailments. Deferred credit amortization for fuel contracts for the nine months ended September 30, 2003 and 2002 was $10.8 million and $15.6 million, respectively.
For the nine months ended September 30, 2003 and 2002, NE LP and the Partnerships recorded net unrealized mark-to-market gains (losses) of $(3.8) million and $3.5 million, respectively, representing the net change in fair value of derivative instruments.
On December 31, 2000, NEA exercised its option to receive a reduced energy payment for the period remaining on one of the power purchase agreements (PPA) in lieu of paying the energy bank balance existing as of that date. The $24.9 million balance as of December 31, 2000 was being amortized into revenue on a straight-line basis over the remaining life of the agreement which expires on September 15, 2021. NEA's accounting treatment reflected the position that, as of December 31, 2000, the energy bank balance represented deferred revenue and was being reduced for the discounted amount of the energy payments on a straight-line basis over the remaining life of the PPA. The power purchaser (Power Purchaser) disputed this position. The Power Purchaser contended that the energy bank balance was being adjusted monthly and could require a significant payment by NEA upon termination. On October 31, 2002, the Power Purchaser filed a demand for arbitration with the American Arbitration Association in this matter.
On March 31, 2003, the PPA was restructured resulting in an $11.1 million gain for NEA. In connection with this restructuring, a settlement of the disputes in connection with the arbitration was reached between NE LP, acting on its behalf and on behalf of NEA, and another company (Agent), acting on its behalf and on behalf of the Power Purchaser. The registrants understand that, under a 1998 power purchase agreement between the Power Purchaser and the Agent (Agent PPA), the Agent acts as agent and representative of the Power Purchaser with respect to the PPA. Under the terms of the settlement, the arbitration was irrevocably dismissed and the related claims released, any energy bank obligations under the PPA were terminated, the energy bank balance of $22.2 million was eliminated, and NE LP paid approximately $11.1 million plus interest to the Agent in June 2003.
As a condition to this settlement, the Agent entered into an agreement (PMI Agreement) with FPL Energy, LLC's power marketing subsidiary, FPL Energy Power Marketing, Inc. (PMI). Under the terms of the PMI Agreement, until termination of the PPA, PMI is to purchase power from the Agent under the same terms as the Agent purchases power under the PPA, as the Power Purchaser's agent and representative pursuant to the Agent PPA. Also, under the PMI Agreement the parties agreed to seek approvals and satisfy conditions for NEA to terminate the PPA on or before December 31, 2003. Those approvals and conditions include approvals under the indentures relating to the Funding Corp. and Acquisition Corp. secured notes and bonds.
In February 2003, NJEA reached an agreement to modify the gas index used for calculating the energy price in an existing power purchase agreement with a New Jersey utility. The modification was necessary because the original index described in the power purchase agreement no longer existed at August 14, 2002. The new index rate, effective as of August 14, 2002 and adjusted annually on that date, resulted in an increase of $9.2 million in revenue to NJEA, which was paid in March 2003 of which $7.7 million pertains to 2002. In November 2003, this agreement was approved by the New Jersey Board of Public Utilities.
In May 2003, NJEA entered into an agreement with the New Jersey utility mentioned above to amend and restate the power purchase agreement. The agreement provides for, among other things, the delivery of electricity to the utility from sources other than NJEA's facility at a payment that is less than the payment required under the existing power purchase agreement. In November 2003, this agreement was approved by the New Jersey Board of Public Utilities subject to the agreement becoming effective by December 31, 2003. However, implementation of the agreement is contingent upon certain conditions being met, some of which are considered significant. If these conditions are not satisfied there is a possibility that the agreement may not become effective, and in that event the existing power purchase agreement would remain in effect.
In March 2003, NEA bifurcated the fuel supply contract with one of its suppliers who provided approximately 65% of NEA's daily fuel requirements. In July 2003, NEA entered into two agreements with this supplier to terminate one of the agreements that provided for the purchase of 13,399 mmbtu/day (Termination Agreement) and to partially terminate the other agreement that provided for the purchase of 35,418 mmbtu/day (Partial Termination Agreement). These agreements were executed to hedge the Partnerships' exposure to natural gas prices in anticipation of other contract restructurings.
On August 31, 2003, the Termination Agreement was executed resulting in removal of a $39.2 million liability representing the unamortized deferred credit as of the termination date and a $15.2 million gain for NEA. In conjunction with this termination, NEA was to pay a termination fee of $24.0 million, of which $12.0 million was paid by the NE LP partners and recorded by NE LP as a capital contribution. Promissory notes were issued by the NE LP partners for the remaining $12.0 million. The notes bear interest at a rate of 6% per annum and are due no later than May 1, 2004.
NEA entered into two replacement long-term gas supply agreements with PMI and Tractebel Energy Marketing, Inc. (TEMI) which became effective September 1, 2003. These two contracts provide NEA with the same combined quantity of natural gas and with pricing that is expected to be more favorable over the term of the agreements. Affiliates of PMI and TEMI have guaranteed certain of their respective obligations under the long-term gas supply agreements.
Under the terms of the Partial Termination Agreement, the daily delivery of fuel may be reduced to 12,507 mmbtu/day. Implementation of this agreement is contingent upon certain conditions being met, including satisfaction of the relevant provisions of bond indentures.
Interest expense for NE LP and the Partnerships decreased as a result of decreasing principal balances on their outstanding debt.
The Funding Corp. and the Acquisition Corp. - Both the Funding Corp. and the Acquisition Corp. use interest income and principal payments received from the notes receivable from the Partnerships and NE LP, respectively, to make scheduled interest and principal payments on their outstanding debt. Both entities are scheduled to make semi-annual principal and interest payments on June 30 and December 30. On June 30, 2003, the Funding Corp. and the Acquisition Corp. made the scheduled debt service payments. Interest expense for both the Funding Corp. and Acquisition Corp. decreased in 2003 as a result of decreasing principal balances on their outstanding debt.
Liquidity and Capital Resources
NE LP and the Partnerships - The changes in net cash provided by operating activities for NE LP and the Partnerships for the nine months ended September 30, 2003 compared to the nine months ended September 30, 2002 were primarily due to timing of cash receipts under certain agreements. Net cash provided by operating activities for NE LP also reflects the payment of $11.1 million plus interest to the Agent in accordance with the energy bank settlement previously discussed. Cash distributions to partners for the nine months ended September 30, 2003 and 2002 for NE LP were $5.5 million and $30.9 million, respectively. Cash distributions to partners for the nine months ended September 30, 2003 and 2002 for the Partnerships were $29.5 million and $44.1 million, respectively.
Each of NE LP and the Partnerships make scheduled interest and principal payments on their outstanding debt. Each are scheduled to make semi-annual principal and interest payments on June 30 and December 30. On June 30, 2003, NE LP and the Partnerships made the scheduled debt service payments.
NE LP and the Partnerships' long-term contractual obligations at September 30, 2003 are discussed in Note 4.
Market Risk Sensitivity
Commodity price risk - The prices received by the Partnerships for power sales under their long-term contracts do not move precisely in tandem with the prices paid by the Partnerships for natural gas. To mitigate the price risk associated with purchases of natural gas, the Partnerships may, from time to time, enter into certain transactions either through public exchanges or by means of over-the-counter transactions with specific counterparties. The Partnerships mitigate their risk associated with purchases of natural gas through the use of natural gas swap agreements and options. The swap agreements require the Partnerships to pay a fixed price (absolutely or within a specified range) in return for a variable price on specified notional quantities of natural gas. The options consist of purchased call options to establish a maximum price for natural gas, and written put options are executed to offset the cost of the purchased call options. In order to mitigate the fixed price exposure of natural gas prices in 2003, the Partnerships entered into a costless collar in the fall of 2002 and gas swap agreements in June and July 2003.
The Partnerships use a value-at-risk (VaR) model to measure market risk in their mark-to-market portfolio. The VaR is the estimated loss based on a one-day holding period at a 95% confidence level using historical simulation methodology. As of September 30, 2003 and December 31, 2002, the VaR figures for hedges in accumulated other comprehensive income (loss) (in thousands) are as follows:

December 31, 2002	$	1,196
September 30, 2003	$	1,472
Average for the period ended September 30, 2003	$	1,346

New Accounting Rules
Variable Interest Entities - In January 2003, FASB issued FIN 46, "Consolidation of Variable Interest Entities." See Note 7.
Derivative Instruments and Hedging Activities - Effective July 1, 2003, NE LP and the Partnerships adopted FAS 149, "Amendment of Statement 133 on Derivative Instruments and Hedging Activities." In August 2003, the EITF released EITF 03-11. In addition, the staff of the SEC recently indicated that the unrealized effects of derivative instruments not accounted for as hedges should be reported within the same caption on the statements of operations. See Note 2.
Item 3. Quantitative and Qualitative Disclosures About Market Risk
See Management's Discussion and Analysis of Financial Condition and Results of Operations - Market Risk Sensitivity.
Item 4. Controls and Procedures
(a)	Evaluation of Disclosure Controls and Procedures
	As of September 30, 2003, each of the registrants performed an evaluation, under the supervision and with the participation of its management, including the chief executive officer and chief financial officer, or their equivalent (Principal Officers), of the effectiveness of the design and operation of the registrant's disclosure controls and procedures (as defined in Exchange Act Rule 13a-15(e) or 15d-15(e)). Based upon that evaluation, the Principal Officers of each of the registrants concluded that the registrant's disclosure controls and procedures are effective in timely alerting them to material information relating to the registrant required to be included in the registrant's reports filed or submitted under the Exchange Act. Due to the inherent limitations of the effectiveness of any established disclosure controls and procedures, management of the registrants cannot provide absolute assurance that the objectives of their disclosure controls and procedures will be met.
(b)	Changes in Internal Controls
	There has been no change in any registrant's internal control over financial reporting that occurred during such registrant's most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, such registrant's internal control over financial reporting.

PART II - OTHER INFORMATION

Item 5. Other Information

Reference is made to Item 1. Business - Partnerships' Operations in the 2002 Form 10-K for the registrants.

For information regarding a proposed amended and restated power purchase agreement of NJEA, see Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations - Results of Operations. Implementation of this agreement is subject to satisfaction of certain conditions.

For information regarding NEA's long-term gas supply agreements, see Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations - Results of Operations.

For information regarding energy bank balances and power purchase agreements, see Note 5.

Item 6. Exhibits and Reports on Form 8-K

(a)

Exhibits

	Exhibit Number	Description

	10(a)	Base Contract for Sale and Purchase of Natural Gas, dated August 1, 2003, between FPL Energy Power Marketing, Inc. and NEA
	10(b)	Base Contract for Sale and Purchase of Natural Gas, dated August 1, 2003, between Tractebel Energy Marketing, Inc. and NEA
	10(c)	Guarantee, dated August 1, 2003, by FPL Group Capital Inc in favor of NEA
	10(d)	Guaranty, dated August 1, 2003, by Tractebel S.A. in favor of NEA
	10(e)	First Amendment to Guarantee, dated August 1, 2003, by FPL Group Capital Inc, with the consent and acknowledgement of Northeast Energy Associates
	10(f)	First Amendment to Guarantee, dated October 2, 2002, by FPL Group Capital Inc, with the consent and acknowledgement of North Jersey Energy Associates
	31(a)	Rule 13a-14(a)/15d-14(a) Certification of President (equivalent to the Chief Executive Officer) of ESI Tractebel Funding Corp.
	31(b)	Rule 13a-14(a)/15d-14(a) Certification of Treasurer (equivalent to the Chief Financial Officer) of ESI Tractebel Funding Corp.
	31(c)	Rule 13a-14(a)/15d-14(a) Certification of President (equivalent to the Chief Executive Officer) of ESI Tractebel Acquisition Corp.
	31(d)	Rule 13a-14(a)/15d-14(a) Certification of Treasurer (equivalent to the Chief Financial Officer) of ESI Tractebel Acquisition Corp.
	31(e)	Rule 13a-14(a)/15d-14(a) Certification of President (equivalent to the Chief Executive Officer) of ESI Northeast Energy GP, Inc. as Administrative General Partner of Northeast Energy Associates, a limited partnership
	31(f)	Rule 13a-14(a)/15d-14(a) Certification of Vice President and Treasurer (equivalent to the Chief Financial Officer) of ESI Northeast Energy GP, Inc. as Administrative General Partner of Northeast Energy Associates, a limited partnership
	31(g)	Rule 13a-14(a)/15d-14(a) Certification of President (equivalent to the Chief Executive Officer) of ESI Northeast Energy GP, Inc. as Administrative General Partner of North Jersey Energy Associates, a limited partnership
	31(h)	Rule 13a-14(a)/15d-14(a) Certification of Vice President and Treasurer (equivalent to the Chief Financial Officer) of ESI Northeast Energy GP, Inc. as Administrative General Partner of North Jersey Energy Associates, a limited partnership
	31(i)	Rule 13a-14(a)/15d-14(a) Certification of President (equivalent to the Chief Executive Officer) of ESI Northeast Energy GP, Inc. as Administrative General Partner of Northeast Energy, LP
	31(j)	Rule 13a-14(a)/15d-14(a) Certification of Vice President and Treasurer (equivalent to the Chief Financial Officer) of ESI Northeast Energy GP, Inc. as Administrative General Partner of Northeast Energy, LP
	32(a)	Section 1350 Certification of President (equivalent to the Chief Executive Officer) and Treasurer (equivalent to the Chief Financial Officer) of ESI Tractebel Funding Corp.
	32(b)	Section 1350 Certification of President (equivalent to the Chief Executive Officer) and Treasurer (equivalent to the Chief Financial Officer) of ESI Tractebel Acquisition Corp.
	32(c)	Section 1350 Certification of President (equivalent to the Chief Executive Officer) and Vice President and Treasurer (equivalent to the Chief Financial Officer) of ESI Northeast Energy GP, Inc. as Administrative General Partner of Northeast Energy Associates, a limited partnership
	32(d)	Section 1350 Certification of President (equivalent to the Chief Executive Officer) and Vice President and Treasurer (equivalent to the Chief Financial Officer) of ESI Northeast Energy GP, Inc. as Administrative General Partner of North Jersey Energy Associates, a limited partnership
	32(e)	Section 1350 Certification of President (equivalent to the Chief Executive Officer) and Vice President and Treasurer (equivalent to the Chief Financial Officer) of ESI Northeast Energy GP, Inc. as Administrative General Partner of Northeast Energy, LP
(b)	Reports on Form 8-K - None.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned, thereunto duly authorized.

	NORTHEAST ENERGY ASSOCIATES, A LIMITED PARTNERSHIP (ESI Northeast Energy GP, Inc. as Administrative General Partner) NORTH JERSEY ENERGY ASSOCIATES, A LIMITED PARTNERSHIP (ESI Northeast Energy GP, Inc. as Administrative General Partner) NORTHEAST ENERGY, LP (ESI Northeast Energy GP, Inc. as Administrative General Partner) ESI TRACTEBEL FUNDING CORP. ESI TRACTEBEL ACQUISITION CORP. (Registrants)

Date: November 11, 2003



	MARK R. SORENSEN

	Mark R. Sorensen Vice President and Treasurer of ESI Northeast Energy GP, Inc. Treasurer of ESI Tractebel Funding Corp. Treasurer of ESI Tractebel Acquisition Corp. (Principal Financial and Principal Accounting Officer of the Registrants)

NORTHEAST ENERGY ASSOCIATES 10-Q