ANNUAL REPORT PURSUANT TO SEC. 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2000

Commission File No. 1-3429

Maine Public Service Company

(Exact name of registrant as specified in its charter)

Maine

(State or other jurisdiction of incorporation or organization)

01-0113635

(I.R.S. Employer Identification No.)

209 State Street, Presque Isle, Maine

(Address of principal executive offices)

04769

(Zip Code)

Registrant's telephone number, including area code:   207-768-5811

Securities registered pursuant to Section 12(b) of the Act:

Title of each class:   Common Stock, $7.00 par value

Name of each exchange on which registered:   American Stock Exchange

Securities registered pursuant to Section 12(g) of the Act:

None

Title of Class

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 if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K not contained herein, and will not be
contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this
Form 10-K or any amendment to this Form 10-K.  [ ]

Aggregate market value of the voting stock held by non-affiliates at March 9, 2001: $38,933,235.

The number of shares outstanding of each of the issuer's classes of common stock as of March 9, 2001.

Common Stock, $7.00 par value - 1,573,060 shares



1. 	The Company's 2000 Annual Report to Stockholders is incorporated by reference into Parts I, II and IV.

2. 	The Company's definitive proxy statement, to be filed pursuant to Regulation 14A no later than 120 days after December 31,
2000, which is the end of the fiscal year covered by this report, is incorporated by reference into Part III.



MAINE PUBLIC SERVICE COMPANY

FORM 10-K

For the Fiscal Year Ended December 31, 2000

TABLE OF CONTENTS

Pages

PART I

Item 1.  Business

General											  3

Financial Information about Foreign and Domestic Operations				  4

Regulation and Rates									 	  5

Franchises and Competition									  5

Employees											  5

Subsidiaries and Affiliated Companies							  5

Item 2.  Properties												  6

Item 3.  Legal Proceedings											  6

Item 4.  Submission of Matters to a Vote of Security Holders						  7

PART II

Item 5.  Market for Registrant's Common Equity and Related Shareholder Matters			  7

Item 6.  Selected Financial Data										  8

Item 7.  Management's Discussion and Analysis of Financial Condition and

Results of Operations										  8

Item 7a. Quantitative and Qualitative Disclosures About Market Risk					  9

Item 8.  Financial Statements and Supplementary Data							  9

Item 9.  Changes In and Disagreements with Accountants							  9



PART III

Item 10. Directors and Executive Officers of the Registrant							  9

Item 11. Executive Compensation										11

Item 12. Security Ownership of Certain Beneficial Owners and Management				11

Item 13. Certain Relationships and Related Transactions							11

PART IV

Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K				11

2



Item 1.	Business

General

The Company was originally incorporated as the Gould Electric Company in April, 1917 by a special act of the Maine
legislature.  Its name was changed to Maine Public Service Company in August, 1929.  Until 1947, when its capital stock was sold
to the public, it was a subsidiary of Consolidated Electric & Gas Company.  Maine and New Brunswick Electrical Power Company,
Limited, the Company's wholly-owned Canadian subsidiary (the "Canadian Subsidiary") was incorporated in 1903 under the laws
of the Province of New Brunswick, Canada.  Energy Atlantic, LLC (EA), the Company's unregulated marketing subsidiary,
formally began operations in January, 1999.

The Company, until the generating assets were sold on June 8, 1999, produced electric energy, and currently engages in the
transmission and distribution of electric energy to retail and, until March 1, 2000, wholesale customers in all of Aroostook County
and a small portion of Penobscot County in northern Maine.  Geographically, the service territory is approximately 120 miles long
and 30 miles wide, with a population of approximately 77,000.  The service area of the Company includes one of the most
important potato growing and processing sections in the United States.  In addition, the area produces wood products, principally
lumber, as well as pulp wood and wood chips for paper manufacturing.  From January 1, 2000 to February 29, 2000, the Company
and EA (wholesale only) required 140,346 MWH's to service all customers.  On March 1, 2000, customers in the Company's
service territory began purchasing energy from suppliers other than the Company, either from competitive electricity providers or,
if they are unable or did not wish to choose a competitive supplier, the Standard Offer Service (SOS), marking the beginning of
retail competition in Maine.

The Canadian Subsidiary was primarily a hydro-electric generating company.  It owned and operated the Tinker hydro plant
in New Brunswick, Canada until June 8, 1999, when these assets were sold to WPS-PDI.  Prior to the generating asset sale, the
Canadian Subsidiary sold to the Company the energy not needed to supply its wholesale New Brunswick customer.  During 1999,
sales to the Company amounted to 65,333 MWH out of the 78,109 MWH generated for sale at Tinker.

See Item 1, "Regulation and Rates", below for further discussion of Maine's electric utility deregulation law and the sale of
the Company's generating assets.

EA participated in the wholesale power market during 1999 and until March 1, 2000, when it began selling energy in the
competitive retail electricity market in Maine.  EA serves approximately 525,000 residential and small commercial, as well as
several large industrial customers in Central Maine Power's (CMP) territory.  In the Company's service territory, EA provided 20%
of the medium non-residential SOS from March 1, 2000 until February 28, 2001 and continues to serve customers in that and other
classes on a competitive basis.  EA sells power throughout Maine via an exclusive wholesale supply contract, which supplied a total
of 3,552,892 MWH's from March 1, 2000 to December 31, 2001, including 2,750,719 MWH's for SOS, which are not reported as
purchased power because SOS activity is recorded on a net basis.

As of June 4, 1984, the Company entered into a Power Purchase Agreement (PPA) with Sherman Power Company, which
assigned its interest in the Agreement to Wheelabrator-Sherman Energy Company (W-S), formerly Signal-Sherman Energy
Company, (a cogenerator), for 17.6 MW of capacity which began July, 1986.  The original contract was scheduled to expire in
2001.  The Company and W-S agreed to amend the PPA.  Under the terms of this amendment, W-S agreed to reductions in the
price of purchased power of approximately $10 million over the PPA's current term.  The Company and W-S have agreed to renew
the PPA for an additional six years at agreed-upon prices.  The Company made an up-front payment to W-S of $8.7 million on May
29, 1998, with the financing provided by the Finance Authority of Maine (FAME).  This payment has been reflected as a regulatory
asset and, based on an MPUC order, will be included in stranded costs and recovered in the rates of the transmission and
distribution utility, beginning January 1, 2001.  The amended PPA helped relieve the financial pressure caused by the closure of
Maine Yankee in 1997 as well as the need for substantial increases in its retail rates, and is therefore in the best interests of the
Company, its customers and shareholders.  Beginning on March 1, 2000, WPS Energy Services began taking delivery of W-S
output and reimbursing the Company for the market rate.  The Company records the above-market cost of the W-S contract as
stranded costs.

3

Form 10-K

PART I

Item 1.	Business - Continued





|                                      | 2000    | 1999    | 1998   
|------------------------------------- | ------- | ------- | -------
|Revenues from Unaffiliated Customers:
|Parent-United States                  | 37,443  | 58,677  | 55,958 
|Subsidiary-United States              | 38,021  | 8,429   | -      
|Subsidiary - U.S. - SOS Margin        | 2,774   | -       | -      
|Total Domestic                        | 78,238  | 67,106  | 55,958 
|Subsidiary-Canada                     | -       | 350     | 669    
|Intercompany Revenues:               
|Parent-United States                  | -       | 323     | 644    
|Subsidiary-United States              | 70      | 311     | -      
|Total Domestic                        | 70      | 634     | 644    
|Subsidiary-Canada                     | -       | 1,027   | 1,748  
|Operating Income (Loss):             
|Parent-United States                  | 1,711   | 7,143   | 5,785  
|Subsidiary-United States              | 5,514   | (76)    | -      
|Total Domestic                        | 7,225   | 6,973   | 5,785  
|Subsidiary-Canada                     | 86      | 104     | 380    
|Net Income (Loss)                    
|Parent-United States                  | 3,354   | 3,811   | 1,886  
|Subsidiary-United States              | 1,688   | (354)   | -      
|Total Domestic                        | 5,042   | 3,457   | 1,886  
|Subsidiary-Canada                     | 259     | 549     | 367    
|Identifiable Assets:                 
|Parent-United States                  | 143,828 | 160,782 | 157,476
|Subsidiary-United States              | 6,385   | 1,445   | -      
|Total Domestic                        | 150,213 | 162,227 | 157,476
|Subsidiary-Canada                     | 756     | 9,321   | 6,820  

The identifiable assets, by company, are those assets used in each company's operations, excluding intercompany receivables and
investments.

4

Form 10-K

PART I

Item 1.	Business - Continued

Regulation and Rates



The information with respect to regulation and rates is presented in Exhibit 13, 2000 Annual Report to Stockholders, Note
11 to the Consolidated Financial Statements, "Commitments, Contingencies and Regulatory Matters", which information is
incorporated herein by reference.

Franchises and Competition

Except for consumers served at retail by the Company's wholesale customers, the Company has practically an exclusive
franchise to deliver electric energy in the Company's service area.  For additional information on changes to the structure of the
electric utility industry in Maine and the generating asset sale, see Exhibit 13, 2000 Annual Report to Stockholders, Note 11 to the
Consolidated Financial Statements, "Commitments, Contingencies and Regulatory Matters", incorporated herein by reference.

Employees

The information with respect to employees is presented in Exhibit 13, 2000 Annual Report to Stockholders, page 13,
"Employees", which information is incorporated herein by reference.

Subsidiaries and Affiliated Companies

The Company owns 100% of the Common Stock of Maine and New Brunswick Electrical Power Company, Limited (the
Canadian Subsidiary).  The Canadian Subsidiary owned and operated the Tinker Station located in the Province of New Brunswick,
Canada prior to its sale on June 8, 1999.

On August 24, 1998, the MPUC approved the formation of the Company's unregulated subsidiary, Energy Atlantic, LLC
(EA).  EA began formal operations on January 1, 1999, performing various non-core activities, such as wholesale marketing of
electric power and the sales of energy-related products and services.  EA began retail sales activity on March 1, 2000, the start of
retail competition in Maine.  As a start-up unregulated subsidiary, the Board of Directors and the MPUC limited the capital
contributions to a maximum of $2 million.

The Company owns 5% of the Common Stock of Maine Yankee, which operated an 860 MW nuclear power plant (the
"Plant") in Wiscasset, Maine.  On August 6, 1997, the Board of Directors of Maine Yankee voted to permanently cease power
operations and to begin decommissioning the Plant.  The Plant experienced a number of operational and regulatory problems and
did not operate after December 6, 1996.  The decision to close the Plant permanently was based on an economic analysis of the
costs, risks and uncertainties associated with operating the Plant compared to those associated with closing and decommissioning it.
The Plant's operating license from the Nuclear Regulatory Commission (NRC) was due to expire on October 21, 2008.  For further
information regarding Maine Yankee and its deregulation progress, see Exhibit 13, 2000 Annual Report to Stockholders, Note 11
to the Consolidated Financial Statements, "Commitments, Contingencies and Regulatory Matters", incorporated herein by
reference.

The Company also owns 7.49% of the Common Stock of Maine Electric Power Company, Inc. (MEPCO).  MEPCO owns
and operates a 345-KV (kilovolt) transmission line about 180 miles long which connects the New Brunswick Power (NB Power)
system with the New England Power Pool.

5Form 10-K

PART I

Item 2.	Properties

The Company owned and operated electric generating facilities consisting of:  oil-fired steam units with a total capability of
23,000 kilowatts, diesel generation totaling 12,300 kilowatts, and hydro-electric facilities of 2,300 kilowatts.  The Canadian
Subsidiary owned and operated a hydro-electric plant of 33,500 kilowatts and a small diesel unit with 1,000 kilowatt capacity.  As
discussed in Exhibit 13, 2000 Annual Report to Stockholders, Note 11 to the Consolidated Financial Statements, "Commitments,
Contingencies and Regulatory Matters", incorporated herein by reference, the Company sold its generating assets on June 8, 1999
in accordance with the State's electric deregulation law.

As of December 31, 2000, the Company and Subsidiary had approximately 392 pole miles of transmission lines and the
Company owned approximately 1,737 miles of distribution lines.

The Company was a part-owner of a 600,000 kilowatt oil-fired steam unit built by Central Maine Power Company at its
Wyman Station in Yarmouth, Maine.  The Company's share of that unit was 3.3455%, or approximately 20,000 kilowatts, and was
included in the generating asset sale on June 8, 1999, as more fully described in Exhibit 13, 2000 Annual Report to Stockholders,
Note 11 to the Consolidated Financial Statements, "Commitments, Contingencies and Regulatory Matters", incorporated herein by
reference.

Substantially all of the properties owned by the Company are subject to the liens of the First and Second Mortgage
Indentures and Deeds of Trust.

Item 3.  Legal Proceedings



(a)	WPS Energy Services, Inc., Complaint against Maine Public Service Company, and Petition to Alter or Amend the
MPUC's Order Authorizing the Formation of Energy Atlantic, LLC, MPUC Docket Nos. 98-138 and 00-894

On October 30, 2000, WPS Energy Services (WPS), a Competitive Electricity Provider (CEP) offering retail sales
of electricity in the Company's service territory, filed a Complaint (Docket No. 00-894) against the Company as well
as a Petition to Alter or Amend the MPUC's September 2, 1998 Order in Docket No. 98-138.

The Complaint alleges that the Company has violated various provisions of Chapter 304 of the MPUC's Regulations
governing relations between the Company and all CEPs, including the Company's own marketing subsidiary, Energy
Atlantic, LLC (EA).  According to the Complaint, various of the Company's employees have engaged in conduct
that either awards EA a competitive advantage over other CEPs or has burdened WPS with an unfair disadvantage
relative to EA.  These allegations include such practices as denying WPS information made available to EA, or
providing EA with information about WPS's customers that is not available publicly.  The Company does not
believe it has in any way violated any provisions of Chapter 304 and has so argued to the MPUC.

In its September 2, 1998 Order in Docket No. 98-138 authorizing the formation of EA, the Commission allowed the
Company and EA to share the services of certain employees under certain conditions on the ground that such
sharing was in the public interest and would not have any anti-competitive effect on the retail market for electricity.
WPS claims that the sharing does not conform to the conditions set forth in the Order and that, in any event, the
Commission should now find such sharing not in the public interest, thereby amending its original September 2,
1998 Order.

The Complaint and Petition to Amend the September 2, 1998 Order, in addition to requesting a prohibition on the
sharing of certain employees, also seeks a formal investigation of the Complaint, penalties for any violations of the
Commission's rules and certain specific relief for violations of Chapter 304.

6

Form 10-K

PART I

Item 3.  Legal Proceedings - Continued

The Company believes the Complaint and Petition are completely without merit and are motivated by EA's recent
competitive successes against WPS in the local retail electricity market.  The Company intends to vigorously contest
the matter at the MPUC, but cannot predict the outcome of this proceeding.

(b)	Maine Public Utilities Commission, Inquiry Into Bulk Power System Administration and Settlement System in
Northern Maine, MPUC Docket No. 98-929.

On December 1, 1998, the MPUC issued its Notice of Inquiry into the structure and operation of a bulk power
system administrator and retail settlement system for northern Maine.  This Inquiry was assigned MPUC Docket No.
98-529.  The MPUC based the need for this proceeding on the fact that northern Maine is not electrically connected
to the New England grid and therefore systems in place in the rest of New England that are necessary to support a
marketable competitive environment do not yet exist in northern Maine.

The MPUC Notice acknowledges that the four northern Maine utilities - the Company, the Houlton Water
Company, the Eastern Maine Electric Cooperative, Inc. and the Van Buren Light and Power District - have

formed a working group for the express purpose of developing these systems.  The northern Maine utilities
developed and filed a proposal for these systems on April 30, 1999.  The proposal consisted of a Northern Maine
Independent System Administrator (NMISA) for northern Maine, which must be approved by the FERC.  The
NMISA has been organized as a non-profit corporation under Maine law.  On August 25, 1999, the NMISA filed its
tariff with the FERC (Docket No. ER99-4225-000).  The FERC approved this tariff on November 15, 1999.



Item 4.	Submission of Matters To a Vote of Security Holders



At the Company's Annual Meeting of Stockholders, held on May 9, 2000 the only matter voted upon was the uncontested
election of the following directors to serve until the 2002 Annual Meeting of Stockholders, each of whom received the
votes shown:



|Nominee            | For       | Against | Non-votes and Abstentions
|------------------ | --------- | ------- | -------------------------
|Robert E. Anderson | 1,471,324 | 9,818   | 126,108                  
|Nathan L. Grass    | 1,471,690 | 9,452   | 126,108                  
|J. Paul Levesque   | 1,470,974 | 10,168  | 126,108                  

PART II

Item 5.	Market for Registrant's Common Equity and Related Stockholder Matters

The Company's Common Stock is listed and traded on the American Stock Exchange.  As of December 31, 2000, there
were 1,075 holders of record of the Company's Common Stock.

7

Form 10-K

PART II

Item 5.	Market for Registrant's Common Equity and Related Stockholder Matters - Continued

Dividend data and market price related to the Common Stock are tabulated as follows for the two most recent calendar years:

|                | Market Price | Dividends Paid | Dividends Declared
|--------------- | ------------ | -------------- | ------------------
|                | High         | Low            | Per Share         
|2000            |              |                |                   
|First Quarter   | $18          | $16            | $.30              
|Second Quarter  | $20.75       | $17.38         | .30               
|Third Quarter   | $25.60       | $20.25         | .30               
|Fourth Quarter  | $27.13       | $23.75         | .32               
|Total Dividends |              |                | $1.22             
|1999            |              |                |                   
|First Quarter   | $16-1/8      | $13-1/8        | $.25              
|Second Quarter  | $17-7/8      | $12-7/8        | .25               
|Third Quarter   | $19-1/8      | $17-7/16       | .25               
|Fourth Quarter  | $19          | $16-1/2        | .30               
|Total Dividends |              |                | $1.05             

Dividends declared within the quarter are paid on the first day of the succeeding quarter.



See Exhibit 13, 2000 Annual Report to Stockholders, Note 7 to the Consolidated Financial Statements, "Common
Shareholders' Equity", incorporated herein by reference, concerning restrictions on payment of dividends on Common
Stock.

Item 6.	Selected Financial Data

A five-year summary of selected financial data (1996-2000) is included on page 16 of Exhibit 13, 2000 Annual Report to
Stockholders, which summary is incorporated herein by reference.

Item 7.	Management's Discussion and Analysis of Financial Condition and Results of Operations

The information required to be furnished in response to this Item is submitted as pages 5 to 15, Exhibit 13, 2000 Annual
Report to Shareholders, which pages are hereby incorporated herein by reference.  Information regarding "Construction" is
also furnished in Note 11 to the Consolidated Financial Statements, "Commitments, Contingencies and Regulatory
Matters", of the Notes to the Consolidated Financial Statements, pages 31 to 36 of Exhibit 13, 2000 Annual Report to
Stockholders, which pages are hereby incorporated herein by reference.

8

Form 10-K

PART II

Item 7a. Quantitative and Qualitative Disclosures about Market Risk

(a)	The Company has interest rate risk with three variable rate debt issues of the regulated business as of December 31,
2000 for purposes other than trading.  Two of these issues, $9 million of tax-exempt bonds, issued on the Company's behalf
by the Maine Public Utility Financing Bank (MPUFB) on October 19, 2000, Public Utility Revenue Bonds, 2000 Series
and $11,540,000 of Taxable Electric Rate Stabilization Revenue Notes issued on May 29, 1998 by the Finance Authority of
Maine on behalf of the Company, are discussed in detail in Exhibit 13, the Company's 2000 Annual Report, in Note 9 to the
Consolidated Financial Statements, "Long-Term Debt", and is hereby incorporated by reference.  The third variable rate
debt issue, Public Utility Refunding Revenue Bonds, 1996 Series, was issued by the MPUFB on behalf of the Company in
1996, with $13.6 million outstanding as of December 31, 2000.  As discussed in Note 9 incorporated above, the Company
purchased interest rate caps for each of these issues.

(b)	The Company's unregulated marketing subsidiary, Energy Atlantic, LLC (EA) is engaged in retail and wholesale
energy transactions for purposes other than trading.  This activity exposes EA to a number of risks such as market liquidity,
deliverability and credit risk.  EA seeks to assure that risks are identified, evaluated and actively managed.

Item 8.	Financial Statements and Supplementary Data

(a)	The following financial statements and supplementary data are included in Exhibit 13, the Company's 2000 Annual
Report to Stockholders on pages 17 through 37, and are incorporated herein by reference:

Report of Independent Accountants.



Statements of Consolidated Income for the years ended December 31, 2000, 1999 and 1999.

Statements of Consolidated Cash Flows for the years ended December 31, 2000, 1999 and 1998.

Consolidated Balance Sheets as of December 31, 2000 and 1999.

Statements of Consolidated Common Shareholders' Equity for the years ended December 31, 2000, 1999 and 1998.

Consolidated Statements of Capitalization as of December 31, 2000 and 1999.

Notes to Consolidated Financial Statements.

Item 9.	Changes In And Disagreements With Accountants On Accounting and Financial Disclosure

None.



Item 10. Directors and Executive Officers of the Registrant

Information with regard to the Directors of the registrant is set forth in the proxy statement of the registrant relating to its
2001 Annual Meeting of Stockholders, which information is incorporated herein by reference.  Certain information
regarding executive officers is set forth below and also in the proxy statement of the registrant relating to the 2000

9

Form 10-K



Item 10. Directors and Executive Officers of the Registrant - Continued

Annual Meeting of Stockholders, under "Compliance with Section 16(a) of the Securities and Exchange Act of 1934",
which information is incorporated by reference.

Executive Officers

The executive officers of the registrant are as follows:

|Name                 |                                       | Age | Office Continuously Held Since
|-------------------- | ------------------------------------- | --- | ------------------------------
|Paul R. Cariani      | President and Chief Executive Officer | 60  | 6/1/94                        
|Larry E. LaPlante    | Vice President, Treasurer and Chief   | 49  | 6/1/99                        
|                     | Financial Officer                    
|Stephen A. Johnson   | Vice President and General Counsel    | 53  | 3/2/01                        
|William L. Cyr       | Vice President, Power Delivery        | 41  | 6/1/00                        
|Michael A. Thibodeau | Vice President, Human Resources       | 44  | 12/1/00                       



Paul R. Cariani has been an employee of the Company since November 1, 1977, starting as an Assistant to the Treasurer.
In May 1978, he was appointed Assistant Treasurer until his election as Treasurer, Secretary and Clerk, on March 1, 1983.  In May
1985, he was elected Vice President, Finance and Treasurer effective June 1, 1985.  On February 25, 1992, Mr. Cariani was elected
a Director of the Company to fill an existing vacancy on the Board.  On May 11, 1993, he was elected Executive Vice President,
Chief Financial Officer and Treasurer, effective June 1, 1993.  Effective June 1, 1994, he was elected President and CEO, replacing
the retiring G. Melvin Hovey.  Mr. Hovey remains Chairman of the Board of Directors.

Larry E. LaPlante was elected to the position of Vice President, Treasurer and Chief Financial Officer on June 1, 1999.  He
has been an employee of the Company since November 4, 1983, starting as Controller.  In May, 1984, he was also appointed
Assistant Secretary and Assistant Treasurer until his election as Vice President, Finance and Treasurer effective June 1, 1994.
Effective June 1, 1996, he was elected to Vice President, Finance, Administration and Treasurer.

Stephen A. Johnson was elected to the position of Vice President and General Counsel, effective March 2, 2001.  Mr.
Johnson also continues in his capacity as Secretary and Clerk of the Company, a position he has held since June 1, 1985.  Mr.
Johnson was appointed General Counsel of the Company on March 5, 1985.  On September 1, 1988, he was elected Vice President
of Administration and General Counsel, a position he held until his election as Vice President, Customer Service and General
Counsel.  Effective June 1, 1990, he was elected to Vice President, Customer Service and General Counsel.  On June 1, 1999, he
was elected Vice President, Energy Atlantic and General Counsel.  Prior to joining the Company, Mr. Johnson was the General
Counsel of the Maine Office of the Public Advocate from 1983 to 1985 and prior to that was a Staff Attorney of the Maine Public
Utilities Commission.

William L. Cyr was elected to the position of Vice President, Power Delivery effective June 1, 2000, replacing the retiring
Frederick C. Bustard.  He has been a full-time employee of the Company since July 1, 1982 in various engineering capacities until
his appointment to Assistant Vice President, Power Delivery, effective June 1, 1999.

10

Form 10-K

PART III

Item 10. Directors and Executive Officers of the Registrant - Continued

Michael A. Thibodeau was elected to the position of Vice President, Human Resources effective December 1, 2000.  He
has been an employee of the Company since August 3, 1981, serving in various accounting and finance capacities.  He served as
Assistant Treasurer from June 1, 1986 until his appointment to Assistant Vice President, Administration effective April 1, 1991.
Effective April 1, 1996, he was appointed Assistant Vice President, Human Resources.

Each executive office is a full-time position and has been the principal occupation of each officer since first elected.  All
officers were elected to serve until the next annual election of officers and until their successors shall have been duly chosen and
qualified.  The next annual election of officers will be on May 8, 2001.

There are no family relationships among the executive officers.

Item 11. Executive Compensation

Information for this item is set forth in the proxy statement of the registrant relating to its 2001 Annual Meeting of
Stockholders, which information (with the exception of the "Board Executive Compensation Committee Report") is
incorporated herein by reference.

Item 12. Security Ownership of Certain Beneficial Owners and Management

Information for this item is set forth in the proxy statement of the registrant relating to its 2001 Annual Meeting of
Stockholders, which information is incorporated herein by reference.

Item 13. Certain Relationships and Related Transactions

Not applicable.



Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K

(a)	(1)	Financial Statements



Report of Independent Accountants

Incorporated by reference into Part II of this report from pages 18 through 37 of the 2000 Annual Report to
Stockholders:

Statements of Consolidated Income for years ended December 31, 2000, 1999 and 1998

Statements of Consolidated Cash Flows for the years ended December 31, 2000, 1999 and 1998

Consolidated Balance Sheets as of December 31, 2000 and 1999

Statements of Consolidated Common Shareholders' Equity for the years ended December 31, 2000, 1999
and 1998

Consolidated Statements of Capitalization as of December 31, 2000 and 1999

Notes to Consolidated Financial Statements

11

Form 10-K

PART IV

Item 14. Exhibits, Financial Statement Schedules, and Reports on Form 8-K

(2)	Financial Statement Schedules

Included in Part IV of this report:

Page

Report of Independent Accountants 	   	    					14

Schedule II - Valuation of Qualifying Accounts and Reserves			15



Schedules other than those listed above are omitted for the reason that they are not required or are not
applicable, or the required information is shown in the financial statements or notes thereto.

(3)	Exhibits

Exhibits for Maine Public Service Company are listed in the Index to Exhibits	E-1 to E-6

(b)	A Form 8-K was filed on:  February 8, 2000, under item 5, Other Events.



Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused
this report to be signed on its behalf by the undersigned, hereunto duly authorized, on the 9th of March, 2001.

MAINE PUBLIC SERVICE COMPANY

By: /s/ Kurt A. Tornquist

Kurt A. Tornquist

Controller, Assistant Secretary and Assistant Treasurer

12

Form 10-K

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

|Signature              | Title                              | Date  
|---------------------- | ---------------------------------- | ------
|                      
|/s/ G. Melvin Hovey    | Chairman of the Board and Director | 3/2/01
|(G. Melvin Hovey)     
|                      
|/s/ Paul R. Cariani    | President and Director             | 3/5/01
|(Paul R. Cariani)     
|                      
|/s/ Robert E. Anderson | Director                           | 3/2/01
|(Robert E. Anderson)  
|                      
|/s/ Donald F. Collins  | Director                           | 3/2/01
|(Donald F. Collins)   
|                      
|/s/ D. James Daigle    | Director                           | 3/2/01
|(D. James Daigle)     
|                      
|/s/ Richard G. Daigle  | Director                           | 3/2/01
|(Richard G. Daigle)   
|                      
|s/ J. Gregory Freeman  | Director                           | 3/2/01
|(J. Gregory Freeman)  
|                      
|/s/ Deborah L. Gallant | Director                           | 3/2/01
|(Deborah L. Gallant)  
|                      
|/s/ Nathan L. Grass    | Director                           | 3/2/01
|(Nathan L. Grass)     
|                      
|/s/ J. Paul Levesque   | Director                           | 3/2/01
|(J. Paul Levesque)    

13

REPORT OF INDEPENDENT ACCOUNTANTS

To the Directors and Shareholders of

Maine Public Service Company

Our audits of the consolidated financial statements referred to in our report dated February 9, 2001 appearing on page 17 of the
2000 Annual Report to Shareholders of Maine Public Service Company (which report and consolidated financial statements are
incorporated by reference in this Annual Report on Form 10-K) also included an audit of the financial statement schedule in Item
14(a)(2) of this Form 10-K.  In our opinion, this financial statement schedule presents fairly, in all material respects, the
information set forth therein when read in conjunction with the related consolidated financial statements.

/s/ PricewaterhouseCoopers LLP

PricewaterhouseCoopers LLP

Portland, Maine

February 9, 2001, except for Note 3 for which the date is March 7, 2001

14

Maine Public Service Company & Subsidiary

Valuation of Qualifying Accounts & Reserves

For the Years Ended December 31, 2000, 1999 and 1998

|                                                 |           | Additions | Deductions  |              
|------------------------------------------------ | --------- | --------- | ----------- | -------------
|                                                 | Balance   |           | Recoveries  | Accounts     
|                                                 | at        | Costs     | of Accounts | Written Off  
|                                                 | Beginning | &         | Previously  | As           
|Description                                      | of Period | Expenses  | Written Off | Uncollectible
|                                                
|Reserve Deducted From Asset To Which It Applies:
|Allowance for Uncollectible Accounts            
|                                                
|2000                                             | 215,000   | 352,739   | 102,444     | 335,493      
|                                                
|1999                                             | 215,000   | 171,323   | 119,690     | 291,013      
|                                                
|1998                                             | 215,000   | 181,360   | 129,022     | 310,382      
|                                                



15

Form 10-K

INDEX TO EXHIBITS

Certain of the following exhibits are filed herewith.  Certain other of the following exhibits have heretofore been filed with
the Commission and are incorporated herein by reference.  (* indicates filed herewith)

3(a)		Restated Articles of Incorporation with all amendments through May 8, 1990.  (Exhibit 3(a) to 1990
form 10-K)

3(b)		By-laws of the Company, as amended through May 12, 1987.  (Exhibit 3(b) to 1987 Form 10-K)

4(a)		Indenture of Mortgage and Deed of Trust defining the rights of the holders of the Company's First
Mortgage Bonds.  (Exhibit 4(a) to 1980 Form 10-K)

4(b)		First Supplemental Indenture.  (Exhibit 4(b) to 1980 Form 10-K)

4(c)		Second Supplemental Indenture.  (Exhibit 4(c) to 1980 Form 10-K)

4(d)		Third Supplemental Indenture.  (Exhibit 4(d) to 1980 Form 10-K)

4(e)		Fourth Supplemental Indenture.  (Exhibit 4(e) to 1980 Form 10-K)

4(f)		Fifth Supplemental Indenture.  (Exhibit A to Form 8-K dated May 10, 1968)

4(g)		Sixth Supplemental Indenture.  (Exhibit A to Form 8-K dated April 10, 1973)



4(h)		Seventh Supplemental Indenture.  (Exhibit A to Form 8-K dated November 7, 1975)

4(i)		Eighth Supplemental Indenture.  (Exhibit 4(i) to 1980 Form 10-K)

4(j)		Ninth Supplemental Indenture.  (Exhibit B to Form 10-Q for the second quarter of 1978)

4(k)		Tenth Supplemental Indenture.  (Exhibit 4(k) to 1980 Form 10-K)

4(l)		Eleventh Supplemental Indenture.  (Exhibit 4(l) to 1982 Form 10-K)

4(m)		Indenture defining the rights of the holders of the Company's 9 7/8% debentures.  (Exhibit A to Form
8-K, dated June 10, 1970)

4(n)		Indenture defining the rights of the holders of the Company's 14% debentures.  (Exhibit 4(n) to 1982
Form 10-K)

4(o)		Twelfth Supplemental Indenture.  (Exhibit 4(o) to Form 10-Q for the quarter ended September 30,
1984)

4(p)		Thirteenth Supplemental Indenture.  (Exhibit 4(p) to Form 10-Q for the quarter ended September 30,
1984)

4(q)		Fourteenth Supplemental Indenture, Dated July 1, 1985.  (Exhibit 4(q) to 1985 Form 10-K)

4(r)		Fifteenth Supplemental Indenture, Dated March 1, 1986.  (Exhibit 4(r) to 1985 Form 10-K)

4(s)		Sixteenth Supplemental Indenture, Dated September 1, 1991.  (Exhibit 4(s) to the Company's 1991
Form 10-K)

E-1

4(t)		Seventeenth Supplemental Indenture, Dated April 1, 1997.  (Exhibit 4(t) to the Company's 1998
Form 10-K)

4(u)		Eighteenth Supplemental Indenture, Dated April 1, 1998.  (Exhibit 4(u) to the Company's 1998 Form
10-K)

4(v)		Nineteenth Supplemental Indenture, Dated May 1, 1998.  (Exhibit 4(v) to the Company's 1998 Form
10-K)

*4(w)		Twentieth Supplemental Indenture, Dated October 1, 2000.



9		Not applicable.

10(a)(1)	Joint Ownership Agreement with Public Service of New Hampshire in respect to construction of two
nuclear generating units designated as Seabrook Units 1 and 2, together with related amendments to
date.  (Exhibit 10 to the Company's 1980 Form 10-K)

10(a)(2)	Twentieth Amendment to Joint Ownership Agreement. (Exhibit 10(a)(6) to the Company's 1986
Form 10-K)

10(a)(3)	Twenty-Second Amendment to Joint Ownership Agreement.  (Exhibit 10(a)(3) to the 1988 Form 10-K)

10(b)(1)	Capital Funds Agreement, dated as of May 20, 1968 between Maine Yankee Atomic Power
Company and the Company.  (Exhibit 10(b)(1) to Form 10-Q for the quarter ended March 31, 1983)

10(b)(2)	Power Contract, dated as of May 20, 1968 between Maine Yankee Atomic Power Company and the
Company.  (Exhibit 10(b)(2) to Form 10-Q for the quarter ended March 31, 1983)

10(c)(1)	Participation Agreement, as of June 20, 1969, with Maine Electric Power Company, Inc.  (Exhibit
10(c)(1) to Form 10-Q for the quarter ended March 31, 1983)

10(c)(2)	Agreement, as of June 20, 1969, among the Company and the other Maine Participants.  (Exhibit
10(c)(2) to Form 10-Q for quarter ended March 31, 1983)

10(c)(3)	Power Purchase and Transmission Agreement Supplement to Participation Agreement, dated as of
August 1, 1969, with Maine Electric Power Company, Inc.  (Exhibit 10(c)(3) to Form 10-Q for
quarter ended March 31, 1983)

10(c)(4)	Supplement Amending Participation Agreement, as of June 24, 1970, with Maine Electric Power
Company, Inc.  (Exhibit 10(c)(4) to Form 10-Q for quarter ended March 31, 1983)

10(c)(5)	Second Supplement to Participation Agreement, dated as of December 1, 1971, including as Exhibit
A the Unit Participation Agreement dated November 15, 1971, as amended, between Maine Electric
Power Company, Inc. and the New Brunswick Electric Power Commission.  (Exhibit 10(c)(5) to
Form 10-Q for quarter ended March 31, 1983)

10(c)(6)	Agreement and Assignment, as of August 1, 1977, by Connecticut Light & Power Company,
Hartford Electric Company, Holyoke Water Power Company, Holyoke Power Company, Western
Massachusetts Electric Company and the Company.  (Exhibit 10(c)(6) to Form 10-Q for the quarter
ended March 31, 1983)

E-2

10(c)(7)	Amendment dated November 30, 1980 to Agreement and Assignment as of August 1, 1977, between
Connecticut Light & Power Company, Hartford Electric Company, Holyoke Water Power Company,
Holyoke Power Company, Western Massachusetts Electric Company and the Company.  (Exhibit
10(c)(7) to Form 10-Q for the quarter ended March 31, 1983)

10(c)(8)	Assignment Agreement as of January 1, 1981, between Central Maine Power Company and the
Company.  (Exhibit 10(c)(8) to Form 10-Q for the quarter ended March 31, 1983)

10(d)		Wyman Unit #4 Agreement for Joint Ownership as of November 1, 1974, with Amendments 1, 2,
and 3, dated as of June 30, 1975, August 16, 1976, December 31, 1978, respectively.  (Exhibit 10(d)
to Form 10-Q for the quarter ended March 31, 1983)

10(e)		Agreement between Sherman Power Company and Maine Public Service Company, dated June 4,
1984, with amendments dated July 12, 1984 and February 14, 1985.  (Exhibit 10(f) to 1984 Form 10-K)

10(f)		Credit Agreement, dated as of October 8, 1987 among the Registrant and The Bank of New York,
Bank of New England, N.A., The Merrill Trust Company and The Bank of New York, as agent for
the Participating Banks.  (Exhibit 10(g) to Form 8-K dated October 13, 1987)

10(g)		Amendment No. 1, dated as of October 8, 1989, to the Revolving Credit Agreement, dated as of
October 8, 1987, among the Registrant and The Bank of New York, Bank of New England, N.A.,
Fleet Bank (formerly the Merrill Trust Company) and The Bank of New York as agent for the
participating banks.  (Exhibit 10(l) to Form 8-K dated September 22, 1989)

10(h)		Amendment No. 2, dated as of June 5, 1992, to the Revolving Credit Agreement, among the
Registrant and The Bank of New York, Bank of New England, N.A., Shawmut Bank and the Bank of
New York, as agent for the participating banks.  (Exhibit 10(h) to the Company's 1992 Form 10-K)

10(i)		Indenture of Second Mortgage and Deed of Trust, dated as of October 1, 1985, made by the
Registrant to J. Henry Schroder Bank and Trust Company, as Trustee.  (Exhibit 10(i) to Form 8-K
dated November 1, 1985)

10(j)		First Supplemental Indenture Dated March 1, 1991.  (Exhibit 10(i) to the Company's 1991 Form 10-K)

10(k)		Second Supplemental Indenture Dated September 1, 1991.  Exhibit 10(j) to the Company's 1991
Form 10-K)

10(l)		Agency Agreement dated as of October 1, 1985, between J. Henry Schroder Bank and Trust
Company, as Trustee under the Indenture of Second Mortgage and Deed of Trust dated as of October
1, 1985, made by the Registrant to J. Henry Schroder Bank and Trust Company, as Trustee, and
Continental Illinois National Bank and Trust Company, as Trustee, under an Indenture of Mortgage
and Deed of Trust, dated as of October 1, 1945, as amended and supplemented, made by the
Registrant to Continental Illinois National Bank and Trust Company, as Trustee.  (Exhibit 10(j) to
Form 8-K dated November 1, 1985)

Executive Compensation Plans and Arrangements

10(m)		Employment Contract between Frederick C. Bustard and Maine Public Service Company dated
August 22, 1989.  (Exhibit 10(h) to 1989 Form 10-K)

E-3

10(n)		Employment Contract between Paul R. Cariani and Maine Public Service Company dated November
5, 1999.  (Exhibit 10(n) to 1999 Form 10-K)

10(o)		Employment Contract between Stephen A. Johnson and Maine Public Service Company dated
November 5, 1999.  (Exhibit 10(o) to 1999 Form 10-K)

10(p)		Employment Contract between Larry E. LaPlante and Maine Public Service Company, dated
November 5, 1999.  (Exhibit 10(p) to 1999 Form 10-K)

10(q)		Employment Contract between William L. Cyr and Maine Public Service Company, dated November
5, 1999.  (Exhibit 10(q) to 1999 Form 10-K)

*10(r)		Employment Contract between Michael A. Thibodeau and Maine Public Service Company, dated
December 11, 2000.

10(s)		Maine Public Service Company, Prior Service Executive Retirement Plan, dated May 12, 1992.
(Exhibit 10(s) to 1992 Form 10-K)

10(t)		Maine Public Service Company Pension Plan.  (Exhibit 10(t) to 1992 Form 10-K)

10(u)		Maine Public Service Company Retirement Savings Plan.  (Exhibit 10(u) to 1992 Form 10-K)

10(v)		Third Supplemental Indenture Dated as of June 1, 1996.  (Exhibit 10(t) to 1996 Form 10-K)

10(w)		Amendment No. 3, dated as of October 8, 1995, to the Revolving Credit Agreement, dated as of
October 7, 1987, among the Registrant and The Bank of New York, Shawmut Bank of Boston, Fleet
Bank of Maine, and The Bank of New York, an agent for the participating Banks.  (Exhibit 10(u) to
1996 Form 10-K)

10(x)		Fourth Supplemental Indenture dated May 1, 1998.  (Exhibit 10(v) to the Company's 1998 Form 10-K)



*10(y)		Fifth Supplemental Indenture dated October 1, 2000.

10(z)		Agreement between WPS Power Development, Inc. and Maine Public Service Company, dated July
7, 1998.  (Exhibit 10(w) to the Company's 1998 Form 10-K)

10(aa)		Agreement between Wheelabrator-Sherman Energy Company and Maine Public Service Company,
dated October 15, 1997, with amendments dated January 30, 1998 and April 28, 1998.  (Exhibit
10(x) to the Company's 1998 Form 10-K)

10(ab)		Agreement between Loring Development Authority of Maine and Maine Public Service Company,
dated July 9, 1998.  (Exhibit 10(y) to the Company's 1998 Form 10-K)

*10(ac)	Wholesale Power Sales Agreement between Energy Atlantic, LLC and Engage Energy US, L.P.,
dated December 9, 1999, with amendments dated March 10, 2000 and August 1, 2000 and
addendums dated December 14, 1999 and December 1, 2000

11		Not applicable.



12		Not applicable.

*13		2000 Annual Report to Stockholders

16		March 8, 1996 Letter regarding change in certifying accountant from Deloitte & Touche LLP.
(Exhibit 16 to the Company's 1996 Form 10-K)

18		Not applicable.E-4

19		Not applicable.

21		Maine and New Brunswick Electrical Power Company, Limited, a Canadian corporation.

22		Not applicable.

23		Not applicable.

99(a)		Agreement of Purchase and Sale between Maine Public Service and Eastern Utilities Associates,
dated April 7, 1986.  (Exhibit 28(a) to Form 10-Q for the quarter ended June 30, 1986)

99(b)		Addendum to Agreement of Purchase and Sale, dated June 26, 1986.  (Exhibit 28(b) to Form 10-Q
for the Quarter ended June 30, 1986)

99(c)		Stipulation between Maine Public Service Company, the Staff of the Commission and the Maine
Public Utilities Commission and the Maine Public Advocate, dated July 14, 1986. (Exhibit 28(c) to
Form 10-Q for the quarter ended June 30, 1986)

99(d)		Amendment to July 14, 1986 Stipulation, dated July 18, 1986.  (Exhibit 28(d) to Form 10-Q for the
quarter ended June 30, 1986)

99(e)		Order of the Maine Public Utilities Commission dated July 21, 1986, Docket Nos 84-80, 84-113 and
86-3.  (Exhibit 28(g) to 1986 Form 10-K)



99(f)		Order of the Maine Public Utilities Commission, dated May 9, 1986, Docket Nos. 84-113 and 86-3
(with attached Stipulations).  (Exhibit 28(r) to 1986 Form 10-K)

99(g)		Order of the Maine Public Utilities Commission, dated July 31, 1987, Docket Nos. 84-80, 84-113,
87-96 and 87-167 (with attached Stipulation).  (Exhibit 28(i) to 1988 Form 10-K)

99(h)		Agreement between Maine Public Service Company and various current Seabrook Nuclear Project
Joint Owners, dated January 13, 1989.  (Exhibit 28(o) to 1988 Form 10-K)

99(i)		Order of the Maine Public Utilities Commission dated November 30, 1995 (with attached
Stipulation) in Docket No. 95-052.  (Exhibit 28(p) to 1995 Form 10-K)

99(j)		Order of the Federal Energy Regulatory Commission dated May 31, 1995 in Docket No. ER 95-836-000.  (Exhibit 28(r) to 1995 Form 10-K)

99(k)		Order of Maine Public Utilities Commission dated June 26, 1996 in Docket 95-052 (Rate Design).
(Exhibit 99(n) to 1996 Form 10-K)

99(l)		Independent Auditors Report of Deloitte & Touche L.L.P. dated February 14, 1996 regarding year
ended December 31, 1995.  (Exhibit 99(l) to 1997 Form 10-K)

99(m)		Amendment No. 1, dated as of March 28, 1997, to the Letter of Credit and Reimbursement
Agreement, dated as of June 1, 1996, among the Registrant, The Bank of New York, Fleet Bank of
Maine, and The Bank of New York, as Agent and Issuing Bank.  (Exhibit 99(m) to 1997 Form 10-K)

99(n)		Amendment No. 4, dated as of March 28, 1997, to the Revolving Credit Agreement, dated as of
October 8, 1987, by and among the Registrant, the signatory Banks thereto and The Bank of New
York, as Agent.  (Exhibit 99(n) to 1997 Form 10-K)

E-5

99(o)		Order of Maine Public Utilities Commission dated January 30, 1998 in Docket No. 97-830 (Annual
Increase under Rate Stabilization Plan).  (Exhibit 99(o) to 1997 Form 10-K)

99(p)		Order by the Maine Public Utilities Commission dated January 15, 1998 in Docket No. 97-727.
(Exhibit 99(q) to 1997 Form 10-K)

99(q)		Order of Maine Public Utilities Commission dated February 20, 1998 in Docket 97-670 (Divestiture
of Generation Assets).  (Exhibit 99(q) to the Company's 1998 Form 10-K)

99(r)		Order of Maine Public Utilities Commission dated September 21, 1998 in Docket 98-138 (Formation
of marketing affiliate).  (Exhibit 99(r) to the Company's 1998 Form 10-K)

99(s)		Order of Maine Public Utilities Commission dated December 15, 1998 in Docket 98-865 (Annual
Increase Under Rate Stabilization Plan).  (Exhibit 99(s) to the Company's 1998 Form 10-K)

99(t)		Report of Synapse Energy Economics regarding competition and market power in the northern
Maine market for the Maine Public Utilities Commission for Docket 97-586.  (Exhibit 99(t) to the
Company's 1998 Form 10-K)

99(u)		Final Report of the MPUC and the Maine Attorney General regarding market power issues raised by
the prospect of retail competition in the electric indus- try in Docket 97-877.  (Exhibit 99(u) to the
Company's 1998 Form 10-K)

99(v)		Order of the Federal Energy Regulatory Commission dated December 22, 1998 in Docket No. ER95-836-000.  (Exhibit 99(v) to the Company's 1998 Form 10-K)

99(w)		Order of Maine Public Utilities Commission dated April 5, 1999 in Docket 98-584(Generating Asset
Sale Approval).  (Exhibit 99(w) to 1999 Form 10-K)

99(x)		Order of the Federal Energy Regulatory Commission dated April 14, 1999 in Docket EC 99-29-000
(Generating Asset Sale Approval).  (Exhibit 99(x) to 1999 Form 10-K)

99(y)		Order of the Federal Energy Regulatory Commission dated November 15, 1999 in Docket ER 99-4225-000 (Independent System Administrator).  (Exhibit 99(y) to 1999 Form 10-K)

99(z)		Order of Maine Public Utilities Commission dated December 1, 1999 in Docket 98-577 (Stipulation
Approval).  (Exhibit 99(z) to 1999 Form 10-K)

99(aa)		Order of Maine Public Utilities Commission dated December 3, 1999 in Docket 99-111 (Energy
Atlantic as Central Maine Power Standard Offer Provider).  (Exhibit 99(aa) to 1999 Form 10-K)

99(ab)		Order of Maine Public Utilities Commission dated February 17, 2000 in Docket 98-577 (Order
Approving Phase II Stipulation).  (Exhibit 99(ab) to 1999 Form 10-K)

*99(ac)	Order of the Federal Energy Regulatory Commission dated August 14, 2000 in Dockets ER00-1053-000 and ER00-1053-002

*99(ad)	Order of the Maine Public Utilities Commission dated November 17, 1999 in Docket 99-610
(Reduction in Capital).

*99(ae)	Order of the Maine Public Utilities Commission dated August 11, 2000 in Docket 99-185
(Stipulation Approval).

*99(af)	Agreement between the Maine Public Utilities Commission, the Company, Central Maine Power
Company and Bangor Hydro-Electric Company dated January 10, 2001 regarding Maine Yankee
Power Costs.

E-6

Exhibit 4(w)

THIS INSTRUMENT GRANTS A SECURITY INTEREST

BY A TRANSMITTING UTILITY

THIS INSTRUMENT CONTAINS AFTER-ACQUIRED PROPERTY PROVISIONS

MAINE PUBLIC SERVICE COMPANY

TO

U.S. BANK TRUST

NATIONAL ASSOCIATION

Trustee

TWENTIETH SUPPLEMENTAL INDENTURE

Dated as of October 1, 2000

Supplementing and Modifying Indenture of Mortgage and

Deed of Trust dated as of October 1, 1945

and

Relating to an Issue of Mortgage and

Collateral Trust Bonds, Series due 2025

This is a Security Agreement granting a Security Interest

in Personal Property, Including Personal Property affixed to

Realty as well as a Mortgage

upon Real Estate and other Property.

******THIS TWENTIETH SUPPLEMENTAL INDENTURE** (hereinafter called the "Twentieth Supplemental Indenture"),
dated as of October 1, 2000, made by MAINE PUBLIC SERVICE COMPANY, a Maine corporation (hereinafter called the
"Company"), party of the first part, and U.S. BANK TRUST NATIONAL ASSOCIATION (formerly known as First Trust
National Association, as successor to Continental Bank, National Association (formerly, Continental Illinois National Bank and
Trust Company of Chicago)), a national banking association duly organized and existing under the laws of the United States of
America, and having its principal place of business in the City of Chicago, State of Illinois (hereinafter called the "Trustee"), party
of the second part.

WHEREAS, the Company has heretofore executed and delivered to the Trustee an Indenture of Mortgage and Deed of
Trust, dated as of October 1, 1945 (hereinafter called the "Original Indenture"), to secure the payment of principal and interest on,
as provided therein, its bonds (in the Original Indenture and herein called the "Bonds") to be designated generally as its "First
Mortgage and Collateral Trust Bonds", and to be issued in one or more series as provided in the Original Indenture, pursuant to
which the Company provided for the creation of an initial series of Bonds designated as "First Mortgage and Collateral Trust
Bonds, 2 7/8% Series due 1975" (herein sometimes called "Bonds of the 1975 Series"); and

WHEREAS, the Company has heretofore executed and delivered to the Trustee a First Supplemental Indenture, dated as
of September 1, 1950, pursuant to which the Company provided for the creation of a second series of Bonds designated as "First
Mortgage and Collateral Trust Bonds, 3% Series due 1980" (herein sometimes called "Bonds of the 1980 Series"), a Second
Supplemental Indenture, dated as of February 1, 1955, pursuant to which the Company provided for the creation of a third series of
Bonds designated as "First Mortgage and Collateral Trust Bonds, 3.35% Series due 1985" (herein sometimes called "Bonds of the
1985 Series"), a Third Supplemental Indenture, dated as of September 1, 1960, pursuant to which the Company provided for the
creation of a fourth series of Bonds designated as "First Mortgage and Collateral Trust Bonds, 5 1/2% Series due 1990" (herein
sometimes called "Bonds of the 1990 Series"), a Fourth Supplemental Indenture, dated as of January 1, 1965, pursuant to which the
Company provided for the creation of a fifth series of Bonds designated as "First Mortgage and Collateral Trust Bonds, 4 3/4%
Series due 1995" (herein sometimes called "Bonds of the 1995 Series"), a Fifth Supplemental Indenture, dated as of May 1, 1968,
pursuant to which the Company provided for the creation of a sixth series of Bonds designated as "First Mortgage and Collateral
Trust Bonds, 7 1/8% Series due 1998" (herein sometimes called "Bonds of the 1998 Series"), a Sixth Supplemental Indenture,
dated as of March 1, 1973, pursuant to which the Company supplemented and modified the Original Indenture and provided for the
creation of a seventh series of Bonds designated as "First Mortgage and Collateral Trust Bonds, 7.95% Series due 2003" (herein
sometimes called "Bonds of the 2003 Series"), a Seventh Supplemental Indenture, dated as of September 1, 1975, pursuant to
which the Company supplemented and modified the Original Indenture and provided for the creation of an eighth series of Bonds
designated as "First Mortgage and Collateral Trust Bonds, 10 5/8% Series due 1995" (herein sometimes called "Bonds of the
Second 1995 Series"), an Eighth Supplemental Indenture, dated as of January 1, 1977, pursuant to which the Company
supplemented the Original Indenture, a Ninth Supplemental Indenture, dated as of March 1, 1978, pursuant to which the Company
supplemented and modified the Original Indenture, a Tenth Supplemental Indenture, dated as of October 1, 1979, pursuant to
which the Company supplemented the Original Indenture and

provided for the creation of a ninth series of Bonds designated as "First Mortgage and Collateral Trust Bonds, 10 1/4% Series due
2004" (herein sometimes called "Bonds of the 2004 Series"), an Eleventh Supplemental Indenture, dated as of January 15, 1983,
pursuant to which the Company supplemented the Original Indenture and provided for the creation of a tenth series of Bonds
designated as "First Mortgage and Collateral Trust Bonds, 13 7/8% Series due 1992" (herein sometimes called "Bonds of the 1992
Series"), a Twelfth Supplemental Indenture, dated as of July 1, 1984, pursuant to which the Company supplemented the Original
Indenture and provided for the creation of an eleventh series of Bonds designated as "First Mortgage and Collateral Trust Bonds,
16.30% Series due 1989" (herein sometimes called "Bonds of the 1989 Series"), a Thirteenth Supplemental Indenture, dated as of
July 1, 1984, pursuant to which the Company supplemented the Original Indenture and provided for the creation of a twelfth series
of Bonds designated as "First Mortgage and Collateral Trust Bonds, Floating Rate Series A due 1985" (herein sometimes called
"Bonds of the Series A due 1985"), a Fourteenth Supplemental Indenture, dated as of July 1, 1985, pursuant to which the Company
supplemented the Original Indenture and provided for the creation of a thirteenth series of Bonds designated as "First Mortgage and
Collateral Trust Bonds, Floating Rate Series B due 1986" (herein sometimes called "Bonds of the Series B due 1986"), a Fifteenth
Supplemental Indenture, dated as of March 1, 1986, pursuant to which the Company supplemented the Original Indenture and
provided for the creation of a fourteenth series of Bonds designated as "First Mortgage and Collateral Trust Bonds, 11% Series due
1996" (herein sometimes called "Bonds of the 1996 Series"), a Sixteenth Supplemental Indenture, dated as of September 1, 1991,
pursuant to which the Company supplemented the Original Indenture and provided for the creation of a fifteenth series of Bonds
designated as "First Mortgage and Collateral Trust Bonds, 9.775% Series due 2011" (herein sometimes called "Bonds of the 2011
Series"),  a Seventeenth Supplemental Indenture, dated as of April 1, 1997, pursuant to which the Company supplemented the
Original Indenture and provided for the creation of a sixteenth series of Bonds designated as "First Mortgage and Collateral Trust
Bonds, Series due 2005" (herein sometimes called "Bonds of the 2005 Series"), an Eighteenth Supplemental Indenture, dated as of
April 1, 1998, pursuant to which the Company supplemented the Original Indenture and provided for the creation of a seventeenth
series of Bonds designated as "First Mortgage and Collateral Trust Bonds, Series due 1999" (herein sometimes called "Bonds of
the 1999 Series"), a Nineteenth Supplemental Indenture, dated as of May 1, 1998, pursuant to which the Company supplemented
and modified the Original Indenture and provided for the creation of an eighteenth series of Bonds designated as "First Mortgage
and Collateral Trust Bonds, Series due 2008" (herein sometimes called "Bonds of the 2008 Series"); and

WHEREAS, pursuant to the Original Indenture, as so supplemented and modified, there have been executed, authenticated
and delivered and there are now outstanding First Mortgage and Collateral Trust Bonds of series and in principal amounts as
follows:

|                         | Issued       | Outstanding
|------------------------ | ------------ | -----------
|Bonds of the 2003 Series | $  2,500,000 | $1,850,000 
|Bonds of the 2005 Series | $11,000,000  | $6,000,000 
|Bonds of the 2008 Series | $  4,000,000 | $4,000,000 

which constitute the only Bonds outstanding under the Original Indenture, as so supplemented and modified; and

WHEREAS, the Company now desires to create a new series of Bonds to be designated First Mortgage and Collateral Trust
Bonds, Series due 2025 (herein sometimes called the "Bonds of the 2025 Series"), and the Original Indenture provides that each series
of Bonds (except the Bonds of the 1975 Series) shall be created by an indenture supplemental to the Original Indenture; and

WHEREAS, the Original Indenture further provides that all property of the character specifically described in the Original
Indenture, and all improvements, extensions, betterments or additions to the property specifically described in the Original
Indenture, constructed or acquired after the date of the execution and delivery of the Original Indenture, shall be and become
subject to the lien of the Original Indenture, and that the Company shall from time to time execute, acknowledge and deliver any
and all such further assurances, conveyances, mortgages or assignments of such property as may be required by the terms and
provisions of the Original Indenture, or as the Trustee under the Original Indenture may require, and the Company now desires to
subject to the lien of the Original Indenture certain additional properties which it has constructed or acquired since the date of
execution and delivery of the Nineteenth Supplemental Indenture; and

WHEREAS, all acts and proceedings required by law and by the charter and by-laws of the Company necessary to make
the Bonds of the 2025 Series to be initially issued when executed by the Company, authenticated and delivered by the Trustee and
duly issued, the valid, binding and legal obligations of the Company, and to constitute the Original Indenture, as heretofore
supplemented and modified and as supplemented and modified by this Twentieth Supplemental Indenture, a valid and binding
mortgage and deed of trust for the security of the Bonds, in accordance with the terms of the Original Indenture, as so supplemented
and modified, and the terms of the Bonds, have been done and taken; and the execution and delivery of this Twentieth
Supplemental Indenture and the issue of the Bonds of the 2025 Series to be initially issued have been in all respects duly
authorized;

NOW, THEREFORE, for the purposes aforesaid and in pursuance of the terms and provisions of the Original Indenture,
the Company has executed and delivered this Twentieth Supplemental Indenture (the Original Indenture, as supplemented by the
First, Second, Third, Fourth, Fifth, Eighth, Tenth, Eleventh, Twelfth, Thirteenth, Fourteenth, Fifteenth and Sixteenth Supplemental
Indentures, as supplemented and modified by the Sixth, Seventh, Ninth,  Seventeenth, Eighteenth and Nineteenth Supplemental
Indentures and as supplemented and modified by this Twentieth Supplemental Indenture and any and all supplemental indentures
hereafter entered into between the Company and the Trustee in accordance with the provisions of the Original Indenture, as
supplemented and modified, being herein sometimes called the "Indenture"), and in consideration of the sum of One Dollar ($1.00)
to the Company duly paid by the Trustee at or before the ensealing and delivery hereof, and for other good and valuable
considerations, the receipt whereof is hereby acknowledged, the Company hereby covenants to and with the Trustee and its
successors in the trust under the Original Indenture, as supplemented and modified, as follows:

**ARTICLE 1**

**Schedule of Mortgaged Property.**

**Section 1.01.**  In order to further secure the payment of the principal of, premium, if any, and interest on, all Bonds at any
time issued and outstanding under the Indenture, according to their tenor, purport and effect, and further to secure the performance
and observance of all the covenants and conditions in said Bonds and in the Original Indenture, as supplemented and modified, and
in this Twentieth Supplemental Indenture contained, for the considerations above expressed, and for and in consideration of the
mutual covenants herein contained and of the purchase and acceptance of the Bonds by holders thereof, the Company has executed
and delivered this Twentieth Supplemental Indenture and by these presents does grant, bargain, sell, alien, remise, release, convey,
assign, transfer, mortgage, pledge, set over and confirm unto U.S. Bank Trust National Association, as Trustee under the Indenture,
and to its assigns forever, all property, real, personal or mixed, acquired since the execution and delivery of the Nineteenth
Supplemental Indenture which by the terms of the Original Indenture, as supplemented and modified, is subject or is intended to be
subject to the lien of the Indenture, including, without limiting the generality of the foregoing, the following described property:

**CLAUSE I**

**PART I**

**AROOSTOOK  COUNTY, MAINE**

HOULTON TO ISLAND FALLS LINE

PARCEL I:  A certain parcel of land, being part of Lot Forty-Two (42) in the Town of Oakfield, County of Aroostook and State of
Maine, being more particularly described as follows:

Commencing at the northwest corner of the lot conveyed to Maine Public Service Company by Guy B. Chambers and Eda H.
Chambers and described in Book 551, Page 213 of the Southern Aroostook Registry of Deeds, said point being on the south line of
the property conveyed to Gregory B. Nevers by Lynn M. Nevers by Deed dated January 9 1998 and recorded in Vol. 3097, Page
307 of said Registry; thence westerly on a course bearing North Sixty-Eight Degrees Six Minutes Eight Seconds West (N68
degrees 06' 08" W) along the south line of Nevers for a distance of ninety-seven and ninety-eight hundredths (97.98) feet to a 5/8"
rebar driven into the ground at the southwest corner of said Gregory B. Nevers parcel described in Vol. 3097, Page 307 of said
Registry; thence northerly on the west line of Nevers on a course bearing North Twenty-One Degrees Fifty-Seven Minutes Thirty-Six Seconds East (N 21 degrees 57' 36" E) for a distance of twenty and no-hundredths (20.00) feet to a point; thence westerly on a

course bearing North Sixty-Eight Degrees Six Minutes Eight Seconds West (N 68 degrees 06' 08" W) for a distance of forty-three
and fifty-five hundredths (43.55) feet to a 5/8" rebar driven into the ground on the west line of Parcel I described in a Deed to
Robert A. Stiles dated June 10, 1991 and Recorded in Vol. 2368, Page 117 of said Registry; thence southerly on said west line on a
course bearing South Twenty-Four Degrees Zero Minutes Fifty-One Seconds West (S 24 degrees 00' 51" W) for a distance of one
hundred sixteen and eight-six hundredths (116.86) feet to a 5/8" rebar driven into the ground; thence easterly on a course bearing
North Eighty-Two Degrees Fifty-Four Minutes Forth- Five Seconds East (N 82 degrees 54' 45" E) for a distance of thirty-four and
sixty-three hundredths (34.63) feet to a 5/8" rebar driven into the ground at the west line of the property conveyed  to Marion R.
Dickinson and Joseph H. Dickinson by Deed Dated November 16, 1996 and recorded in Vol. 2999, Page 208 of said Registry;
thence northerly on said north line on a course bearing North Twenty-One Degrees Fifty-Three Minutes Fifty-Two Seconds East (N
21 degrees 53' 52" E) for a distance of thirty and no-hundredths (30.00) feet to a 5/8" rebar driven into the ground at the northwest
corner of the Dickinson property; thence easterly on the north line of said Dickinson on a course bearing South Sixty-Eight Degrees
Six Minutes Eight Seconds East (S 68 degrees 06' 08" E) for a distance of one hundred fifteen and no-hundredths (115.00) feet to
the southwest corner of the lot conveyed to Maine Public Service Company and described in Vol. 551, Page 213 of said Registry;
thence northerly on the west line of Maine Public Service Company on a course bearing North Twenty-Two Degrees Thirty
Minutes Twenty-Four Seconds East (N 22 degrees 30' 24" E) for a distance of fifty and no-hundredth (50.00) feet to the point of
beginning.  The herein described parcel contains twenty-one hundredths .21) acres.

The herein Parcel I being part, and part only, of Parcel I of the same premises conveyed by Jerolyn J. Boutilier, f/k/a Jerolyn J.
Stiles, to Robert A. Stiles by Deed recorded in Vol. 2368, Page 117 of the Southern Aroostook Registry of Deeds.

PARCEL II:  A certain parcel of land, being part of Lot Forty-Two (42) in the Town of Oakfield, County of Aroostook and State of
Maine, being more particularly described as follows:

Commencing at a 5/8" rebar found on the southerly right of way line of the Webb Road at the northeast corner of the parcel
conveyed to Katahdin Development Corporation by John R. Philbert and Sally S Philbert and described in Vol. 2216, Page 256 of
the Southern Aroostook Registry of Deeds; thence westerly on the southerly right of way line of the Webb Road on a course
bearing North Seventy Degrees Fifty Minutes Thirty-Seven Seconds West (N 70 degrees 50' 37" W) for a distance of eighty and
no-hundredths (80.00) feet to a 5/8" rebar driven into the ground; thence southerly on a course bearing South Twenty-Four Degrees
Two Minutes Forty-Six Seconds West (S 24 degrees 02' 46" W) for a distance of four hundred thirty-eight and sixty-seven
hundredths (438.67) feet to a 5/8" rebar driven into the ground; thence easterly on a course bearing South Sixty-Seven Degrees
Fifty- Two Minutes Fifty-Two Seconds East (S 67 degrees 52' 52" E) for a distance of eighty and no-hundredths (80.00) feet to a
5/8" rebar found at the northwest corner of the parcel conveyed by Robert A. Stiles to Daigle Oil Company by Deed dated
September 21, 1999 and recorded in Vol. 3323, Page 125 of said Registry; thence northerly on a course bearing North Twenty-Four
Degrees Zero Minutes Fifty- One Seconds East (N 24 degrees 00' 51" E) for a distance of four hundred twenty-two and eighty-hundredths (422.80) feet to a 5/8" rebar on the southerly right of way line of the Webb Road at the point of beginning.  The herein
described parcel contains eighty-one hundredths (.81) acres.

The herein Parcel II being the same premises conveyed by Katahdin Development Corporation to Robert A. Stiles by Warranty
Deed dated December 26, 1999 and recorded in Vol. 3356, Page 194 of said Registry.

Recorded in the Southern District of Aroostook Registry of Deeds in Volume 3375, pages 020-023 on March 24, 2000.

PARCEL III:  A certain parcel of land, being part of Lot Forty-Two (42) in the Town of Oakfield, County of Aroostook and State
of Maine, being more  particularly described as follows:

Commencing at a 5/8" rebar driven into the ground on the westerly right of way line of the River Road, so-called, at the northeast
corner of the lot conveyed to Maine Public Service Company by Guy B. Chambers and Edna H Chambers and described in Book
551, Page 213 of the Southern Aroostook Registry of deeds; said point also being the southeast corner of the property conveyed to
Gregory B. Nevers by Lynn M. Nevers by deed dated January 9, 1998 and recorded in Book 3097, Page 307 of the Southern
Aroostook Registry of Deeds; thence westerly on a course bearing North Sixty-Eight Degrees Six Minutes Eight Seconds West (N
68 degrees 06' 08" W) along the south line of Nevers for a distance of one hundred forty-seven and ninety-eight hundredths
(147.98) feet to a 5/8" rebar driven into the ground at the southwest corner of said Gregory B. Nevers parcel described in Book
3097, Page 307; thence northerly on the west line of Nevers on a course bearing North Twenty- One Degrees Fifty-Seven Minutes
Thirty-Six Seconds East (N 21 degrees 57' 36" E) for a distance of twenty and zero-hundredths (20.00) feet to a point; thence
easterly on a course bearing South Sixty-Eight Degrees Six Minutes Eight Seconds East (S 68 degrees 06' 08" E) for a distance of
one hundred forth-seven and ninety-six hundredths (147.96) feet to a 5/8" rebar driven into the ground on the westerly right of way
line of the River Road, so-called; thence southerly on the westerly right of way line of the River Road on a course bearing South
Twenty-One Degrees Fifty-Three Minutes Fifty-Two Seconds West ( S21 degrees 53' 52" W) for a distance of twenty and zero-hundredths (20.00) feet to a 5/8" rebar driven into the ground as  the point of beginning.

The herein described parcel contains .07 acres.

Recorded in the Southern Aroostook Registry of Deeds in Volume 3412,   Page 278 on July 7, 2000.

PARCEL IV:  A certain parcel of land, being part of Lot Forty-Two (42) in the Town of Oakfield, County of Aroostook and State
of Maine, being more  particularly described as follows:

Commencing at an axle found driven into the ground on the westerly right of way line of the River Road, so-called, at the southeast
corner of the lot conveyed to Maine Public Company by Guy B. Chambers and Eda H. Chambers and described in Book 551, Page
213 of the Southern Aroostook Registry of Deeds; said point also being the northeast corner of the property conveyed to Marion R.
and Joseph H. Dickinson by deed dated November 12, 1996 and recorded in Book 2999, Page 208 of the Southern Aroostook
Registry of Deeds; thence westerly on the north line of said Dickinson on a course bearing North Sixty-Eight Degrees Six Minutes
Eight Seconds West (N 68 degrees 06' 08" W) for a distance of one hundred sixty-five and zero-hundredths (165.00) feet to a 5/8"
rebar driven into the ground at the northwest corner of Dickinson; thence southerly on the west line of Dickinson on a course
bearing South Twenty-One Degrees Fifty-Three Minutes Fifty-Two Seconds West (S 21 degrees  53' 52" W) for a distance of thirty
and zero-hundredths (30.00) feet to a 5/8" rebar driven into the ground; thence easterly on a course bearing South Sixty-Eight
Degrees Six Minutes Eight Seconds East (S 68 degrees 06' 08" E) for a distance of one hundred sixty-five and zero-hundredths
(165.00) feet to a 5/8" rebar driven into the ground on the westerly right of way line of the River Road, so-called; thence northerly
on the westerly right of way line of the River Road on a course bearing North Twenty-One Degrees Fifty-Three Minutes and Two
Seconds East (N 21 degrees 53' 52" E) for a distance of thirty and zero-hundredths (30.00) feet to the point of beginning.

The herein described parcel contains .11 acres.

Recorded in the Southern Aroostook Registry of Deeds Volume 3407, Page 193 on June 26, 2000.

WESTFIELD SUBSTATION LAND

A certain piece or parcel of land located on the south side of the Mars Hill Road, so-called, in the  Town of Westfield, County of
Aroostook, State of Maine,  approximately three thousand  (3,000) feet Easterly of the intersection of Easton Viner Road, so called,
and said Mars Hill Road, being a part of original Lot Six (6), Range One (1) and more particularly described as follows:

Beginning at a 5/8" rebar set at the intersection of the Southerly sideline of the Mars Hill Road and the westerly limit of the Maine
Public Service Company pole line right of way as conveyed to said company by Francis A. Tweedie and recorded in the Southern
District of the Aroostook Registry of Deeds in Book 927, Page 92.

Said point of beginning also being three thousand seventy-three (3,073) feet Easterly from the centerline of traveled way of the
Easton Viner Road, as measured along said Southerly sideline;

thence southerly along said easterly limit of Maine Public Service Company right of way, South Seventeen Degrees Thirty-One
Minutes Twelve Seconds West (S 17 degrees 31' 12" W) a distance of three hundred and no-hundredths (300.00) feet to a rebar set;
thence Westerly and parallel to the Southerly limit of the Mars Hill Road, North Seventy-Two Degrees Four Minutes Twenty-Six
Seconds West (N 72 degrees 04' 26" W) a distance of five hundred and no-hundredths (500.00) feet to a rebar set; thence

Northerly and parallel to said Westerly limit of Maine Public Service Company right of way, North Seventeen Degrees Thirty-One
Minutes Twelve Seconds East (N 17 degrees 31' 12" E) a distance of three hundred and no-hundredths (300.00) feet to a rebar set
on the said Southerly sideline of Mars Hill Road; thence Easterly along said Southerly sideline of Mars Hill Road, South Seventy-Two Degrees  Four Minutes Twenty-Six Seconds East (S 72 degrees 04' 26" E) a distance of five hundred and no- hundredths
(500.00) feet to the point of beginning.  The above-described piece or parcel of land contains three and forty-four hundredths (3.44)
acres of land more or less.

Recorded in Southern District of Aroostook Registry of Deeds in Volume 3398, pages 141-142  on June 2, 2000.

**PART II**

**TRANSMISSION LINES**

**ADDITIONAL RIGHT-OF-WAY, THE HOULTON TO ISLAND FALLS LINE, SO CALLED**

A 44,000 volt transmission line in Aroostook County, Maine owned and operated by Maine Public Service Company from
Houlton to Island Falls, a distance of approximately 27.85 miles, said Maine Public Service Company line being constructed for the
most part on rights-of-way conveyed to Maine Public Service Company by the following deeds:

|                                                                   | Recorded |     
|------------------------------------------------------------------ | -------- | ----
|Grantor                                                            | Date     | Vol.
|Harold & Theodore Sherman                                          | 8/08/97  | 3021
|Edith A. Dwyer                                                     | 8/08/97  | 3021
|Norman Grant III                                                   | 9/15/97  | 3060
|Dale Hosford                                                       | 10/28/97 | 3075
|Edith A. Dwyer                                                     | 12/18/97 | 3090
|International Paper                                                | 03/06/98 | 3108
|Dale Hosford                                                       | 07/09/98 | 3160
|Craig O. & Debra J. McLaughlin                                     | 07/30/98 | 3156
|Walter Sanders III &                                              
|Rebecca Ann Sanders                                                | 07/30/98 | 3156
|Leah and Albert Hersey                                             | 07/30/98 | 3156
|Judy M. Cameron                                                    | 07/30/98 | 3167
|Glenn C. & Betty McGraw                                            | 08/03/98 | 3168
|Emery & Norma Nightingale                                          | 10/05/98 | 3192
|Inhabitants of Dyer Brook                                         
|Dyer Brook Selectmen                                               | 10/05/98 | 3192
|Charles E. Burpee                                                  | 05/07/99 | 3266
|Joseph A. Farrar & Son, Inc.                                       | 12/09/98 | 3216
|Merle S. & Evelyn F. Burpee                                        | 04/22/99 | 3262
|Merle S. & Evelyn F. Burpee                                        | 04/22/99 | 3262
|Carlene Burpee                                                     | 04/30/99 | 3264
|David W. & Leretta G. McLaughlin                                   | 04/26/99 | 3262
|Elery R. Grant                                                     | 04/29/99 | 3264
|Alfred R. & Cleo B. Skolfield                                      | 03/27/00 | 3375
|E. Lawson & Janice E. Helsor                                       | 12/14/99 | 3351
|William S. Woods & Herbert E. Rhoda                                | 12/16/99 | 3351
|Lysten M. & Judith A. Ivey                                         | 11/30/99 | 3347
|Ralph A. & Joan M. Ivey                                            | 12/03/99 | 3348
|Thomas J. & Pamela J. Anderson                                     | 01/11/00 | 3359
|Thomas J. Anderson, Trustee for                                    | 01/11/00 | 3359
|Thomas J. Anderson, D.M.D., P.A., Employee Retirement Benefit Plan
|Walter M. & Amy Metherell                                          | 01/03/00 | 3357
|Rena B. Barton                                                     | 01/03/00 | 3357
|Roderick G. & Elizabeth M. Lindsay                                 | 01/06/00 | 3358
|Bernard & Iona Nadeau                                              | 01/05/00 | 3358
|Robert W. Nadeau                                                   | 01/14/00 | 3360
|Jack Q. & Donna N. Margison                                        | 01/10/00 | 3358
|Virginia Ford                                                      | 01/06/00 | 3358
|Ernest Buchalla                                                    | 01/10/00 | 3359
|Joey & Trudy Tarr                                                  | 01/07/00 | 3358
|Joey & Trudy Tarr                                                  | 01/07/00 | 3358
|Gerard J. Berthelette                                              | 01/07/00 | 3358
|Paul M. Jr. & Melanie Shields                                      | 01/25/00 | 3362
|Merwin H. & Shirley Crandall                                       | 01/24/00 | 3362
|Robert Kane                                                        | 01/27/00 | 3363
|Lawrence & Mary Winchell                                           | 01/20/00 | 3361
|Linwood B. & Jean A. Jones                                         | 01/19/00 | 3361
|David W. Barrows                                                   | 01/25/00 | 3362
|Joseph H. & Judith A. Anderson                                     | 01/31/00 | 3363
|Frank J. & Mary L. Stiles                                          | 02/07/00 | 3365
|Judith Small                                                       | 02/03/00 | 3364
|Donald P. & Helen I. Woods                                         | 02/10/00 | 3365
|David T. & Aimee J. Goff                                           | 02/23/00 | 3368
|George N. & Gina Clark                                             | 02/22/00 | 3367
|Forest E. & Bobbie Jo Cummings                                     | 02/17/00 | 3367
|Bruce & Marla Crandall                                             | 02/25/00 | 3368
|David & Vallie H. Condon                                           | 03/08/00 | 3371
|David & Vallie H. Condon                                           | 03/08/00 | 3371
|David & Vallie H. Condon                                           | 03/08/00 | 3371
|David & Vallie H. Condon                                           | 03/08/00 | 3371
|David & Vallie H. Condon                                           | 03/08/00 | 3371
|Vallie H. Condon                                                   | 03/08/00 | 3371
|Virginia Ford                                                      | 03/03/00 | 3370
|John R. & Stephanie B. Woods                                       | 03/07/00 | 3370
|John A. Graham                                                     | 04/07/00 | 3378
|Mary B. Stover                                                     | 04/14/00 | 3381
|Joan H. Williams                                                   | 05/02/00 | 3386
|Calvin III & Julie Doughty                                         | 05/01/00 | 3385
|Clement & Linda McGillicuddy                                       | 05/08/00 | 3387
|Paul M. Sr. & Betty I. Shields                                     | 05/18/00 | 3392
|Ray A., Annie E. & Brian R. Delong                                 | 05/16/00 | 3391
|Brent A. & Karen D. Watson                                         | 05/24/00 | 3395
|Shirley Spellman                                                   | 06/01/00 | 3398

The foregoing rights-of-way are conveyed subject to reservations, conditions, restrictions, limitations and exceptions referred to or
mentioned in the deeds above listed.

**CLAUSE II**

All and singular the lands, real estate, chattels real, interests in land, leaseholds, ways, rights-of-way, easements,
servitudes, permits and licenses, lands under water, riparian rights, franchises, privileges, rights and interests, electric generating
plants, power houses, dams, stations, electric transmission and distribution systems, substations, conduits, poles, wires, cables,
office buildings, warehouses, garages, machine shops, and other buildings and structures, implements, meters, tools, and other
apparatuses, appurtenances and facilities materials and supplies and all other property of any nature appertaining to any of the
plants, systems, business or operations of the Company, whether or not affixed to the realty, used in the operation of any of the
premises or plants or systems or otherwise, which are now owned, or which may hereafter be owned or acquired by the Company,
other than excepted property as hereinafter defined.

**CLAUSE III**

All corporate, Federal, State, municipal and other permits, consents, licenses, bridge licenses, bridge rights, river permits,
franchises, grants, privileges and immunities of every kind and description, now belonging to or which may hereafter be owned,
held, possessed or enjoyed by the Company (other than excepted property as hereinafter defined) and all renewals, extensions,
enlargements and modifications of any of them.

**CLAUSE IV**

Also all other property, real, personal or mixed, tangible or intangible (other than excepted property as hereinafter defined)
of every kind, character and description and wheresoever situated, whether or not useful in the generation, manufacture, production,
transportation, distribution, sale or supplying electricity now owned or which may hereafter be acquired by the Company, it being
the intention hereof that all property, rights and franchises acquired by the Company after the date of the execution and delivery
hereof (other than excepted property as hereinafter defined) shall be as fully embraced within and subjected to the lien of the
Indenture as if such property were now owned by the Company and were specifically described herein and conveyed hereby.

**CLAUSE V**

Together with (other than excepted property as hereinafter defined) all and singular the plants, buildings, improvements,
additions, tenements, hereditaments, easements, rights, privileges, licenses and franchises and all other appurtenances whatsoever
belonging or in any wise appertaining to any of the property hereby mortgaged or pledged, or intended so to be, or any part thereof,
and the reversion and reversions, remainder and remainders, and the rents, revenues, issues, earnings, income, products and profits
thereof, and every part and parcel thereof, and all the estate, rights, title, interest, property, claim and demand of every nature
whatsoever of the Company at law, in equity or otherwise howsoever, in, of and to such property and every part and parcel thereof.

**CLAUSE VI**

Also any and all property, real, personal or mixed, including excepted property, that may, from time to time hereafter, by
delivery or by writing of any kind, for the purposes of the Indenture be in any wise subjected to the lien of the Indenture or be
expressly conveyed, mortgaged, assigned, transferred, deposited and/or pledged by the Company, or by anyone in its behalf or with
its consent, to and with the Trustee, which is hereby authorized to receive the same at any and all times as and for additional
security and also, when and as provided in the Indenture, to the extent permitted by law.  Such conveyance, mortgage, assignment,
transfer, deposit and/or pledge or other creation of lien by the Company, or by anyone in its behalf, or with its consent, of or upon
any property as and for additional security may be made subject to any reservations, limitations, conditions and provisions which
shall be set forth in an instrument or agreement in writing executed by the Company or the person or corporation conveying,
assigning, mortgaging, transferring, depositing and/or pledging the same and/or by the Trustee, respecting the use, management and
disposition of the property so conveyed, assigned, mortgaged, transferred, deposited and/or pledged, or the proceeds thereof.

**CLAUSE VII**

There is however, expressly excepted and excluded from the lien and operation of the Indenture the following described
property of the Company, herein sometimes referred to as "excepted property":

(a)  Any and all property expressly excepted and excluded from the Original Indenture and from the lien and operation
thereof by Paragraph A of Clause VII of the Granting Clauses thereof and all property of the character expressly excepted
or intended to be excepted and excluded by Paragraphs B through I of said Clause VII; and

(b)  All property which prior to the execution and delivery of this Twentieth Supplemental Indenture has been released by
the Trustee or otherwise disposed of by the Company free from the lien of the Indenture, in accordance with the provisions
thereof.

The Company may, however, pursuant to the provisions of Granting Clause VI above, subject to the lien and operation of
the Indenture all or any part of the excepted property.

**TO HAVE AND TO HOLD** the trust estate and all and singular the lands, properties, estates, rights, franchises,
privileges and appurtenances hereby mortgaged, conveyed, pledged or assigned, or intended so to be, together with all the
appurtenances thereto appertaining and the rents, issues and profits thereof, unto the Trustee and its successors in trust and to its
assigns, forever:

**SUBJECT, HOWEVER,** to the exceptions, reservations, restrictions, conditions, limitations, covenants and matters
recited in Schedule A to the Original Indenture or otherwise recited in the Original Indenture, as modified and supplemented, and
contained in all deeds and other instruments whereunder the Company has acquired any of the property now owned by it, and to
permitted encumbrances as defined in Subsection B of Section 1.11 of the Original Indenture, as modified by the provisions of the
Sixth Supplemental Indenture, the Seventh Supplemental Indenture, the Ninth Supplemental Indenture, the Seventeenth
Supplemental Indenture, the Eighteenth Supplemental Indenture and the Nineteenth Supplemental Indenture and, with respect to
any property which the Company may hereafter acquire, to all terms, conditions, agreements, covenants, exceptions and
reservations expressed or provided in the deeds or other instruments, respectively, under any by virtue of which the Company shall
hereafter acquire the same and to any liens thereon existing, and to any liens for unpaid portions of the purchase money placed
thereon, at the time of acquisition;

**BUT IN TRUST, NEVERTHELESS,** for the equal and proportionate use, benefit, security and protection of those who
from time to time shall hold the Bonds authenticated and delivered under the Indenture and duly issued by the Company, without
any discrimination, preference or priority of any one Bond over any other by reason of priority in the time of issue, sale or
negotiation thereof or otherwise, except as provided in Section 12.28 of the Original Indenture, so that, subject to said Section
12.28, each and all of said Bonds shall have the same right, lien and privilege under the Indenture, and shall be equally secured
hereby (except in so far as any sinking fund, replacement fund or other fund established in accordance with the provisions of the
Indenture may afford additional security for the Bonds of any specific series) and shall have the same proportionate interest and
share in the trust estate, with the same effect as if all of the Bonds had been issued, sold and negotiated simultaneously on the date
of the delivery hereof;

**AND UPON THE TRUSTS, USES AND PURPOSES** and subject to the covenants, agreements and conditions in the
Indenture set forth and declared.

**ARTICLE 2**

**Bonds of the 2025 Series and Certain**

**Provisions Relating Thereto**

**Section 2.01.**  **Terms of the Bonds of the 2025 Series.**  There shall be a series of Bonds, known as and entitled "First
Mortgage and Collateral Trust Bonds, Series due 2025" (herein referred to as the "Bonds of the 2025 Series"), and the form thereof
shall be substantially as hereinafter set forth in Section 2.02.

The Bonds of the 2025 Series shall be issued to The Bank of New York, as Agent, to secure the obligations of the Company
under a Letter of Credit and Reimbursement Agreement, dated as of October 1, 2000, among the Company, The Bank of New York
("BNY") and Fleet National Bank ("Fleet") and The Bank of New York, as Agent (in such capacity, "BNY Agent"), and as Issuing
Bank (in such capacity, "BNY Issuing Bank") (the "Reimbursement Agreement"), pursuant to which BNY Issuing Bank has issued its
irrevocable, transferrable, direct-pay letter of credit (the "Letter of Credit") to support certain Maine Public Utility Financing Bank
Public Utility Refunding Revenue Bonds, Series 2025 (Maine Public Service Company Project) (the "Revenue Bonds").

The aggregate principal amount of the Bonds of the 2025 Series which may be authenticated and delivered and outstanding
under this Twentieth Supplemental Indenture shall be limited to $5,000,000 except for duplicate Bonds, authenticated and delivered
pursuant to Section 2.12 of the Original Indenture.  The definitive Bonds of the 2025 Series shall be issued only as registered Bonds
without coupons of the denomination of $1.00 and of any multiple thereof and shall be registered in the name of BNY Agent.

The date of authentication on the original issuance of the Bonds of the 2025 Series shall be the date of commencement of the
first interest period for such Bonds.  All Bonds of the 2025 Series shall mature October 1, 2025, and shall bear interest at the Default
Rate as set forth in, and in accordance with, the Reimbursement Agreement until the payment of the principal thereof.  Both principal of
and interest on the Bonds of the 2025 Series will be paid in any coin or currency of the United States of America which at the time of
payment is legal tender for the payment of public and private debts, at the principal office in the City of Chicago, Illinois, of the Trustee
or, at the office of its successor as Trustee, except that, in case of the redemption as a whole at any time of Bonds of the 2025 Series
then outstanding, the Company may designate in the redemption notice other offices or agencies at which, at the option of the registered
holders, Bonds of the 2025 Series may be surrendered for redemption and payment; and in the case of interest on Bonds of the 2025
Series, at the option of the registered holder, at the agency of the Company in the Borough of Manhattan, City and State of New York,
in each case to the holder of record on the record date as hereinbelow defined.  Interest on the Bonds of the 2025 Series shall, unless
otherwise directed by the respective registered holders thereof, be paid by checks payable to the order of the respective holders entitled
thereto, and mailed by the Trustee by first class mail, postage prepaid, to such holders at their respective registered addresses as shown
on the Bond register for the Bonds of the 2025 Series.

The definitive Bonds of the 2025 Series may be issued in the form of Bonds engraved, printed or lithographed on steel
engraved borders and the signature of the President, or a Vice President and of the Secretary or an Assistant Secretary of the Company
may be facsimile.  Bonds of the 2025 Series may also be issued as temporary printed, lithographed or typewritten Bonds, and, so long
as the registered holder of such Bonds does not request their exchange for Bonds in definitive form, the Company shall not be deemed
to have unreasonably delayed the preparation, execution and delivery of definitive Bonds as called for by Section 2.08 of the Original
Indenture.

Notwithstanding any provision in the Original Indenture to the contrary, the person in whose name any Bond of the 2025
Series is registered at the close of business on any record date (as hereinbelow defined) with respect to any interest payment date shall
be entitled to receive the interest payable on such interest payment date notwithstanding the cancellation of such Bond of the 2025
Series upon any transfer or exchange thereof (including any exchange effected as an incident to a partial redemption thereof)
subsequent to the record date and prior to such interest payment date, except that, if and to the extent that the Company shall default in
the payment of the interest due on such interest payment date, then the registered holders of Bonds of the 2025 Series on such record
date shall have no further right to or claim in respect of such defaulted interest as such registered holders on such record date, and the
persons entitled to receive payment of any defaulted interest thereafter payable or paid on any Bonds of the 2025 Series shall be the
registered holders of such Bonds of the 2025 Series on the record date for payment of such defaulted interest.  The term "record date"
as used in this Section 2.01, and in the form of the Bonds of the 2025 Series, with respect to any interest payment date applicable to the
Bonds of the 2025 Series, shall mean the May 15 next preceding a June 1 interest payment date or the November 15 next preceding a
December 1 interest payment date, as the case may be, or a special record date established for defaulted interest as hereinafter provided.

In the case of failure by the Company to pay any interest when due, the claim for such interest shall be deemed to have been
transferred by transfer of any Bond of the 2025 Series registered on the Bond register, and the Company by not less than 10 days
written notice to bondholders may fix a subsequent record date, not more than 15 days prior to the date fixed for the payment of such
interest, for determination of holders entitled to payment of such interest.  Such provision for establishment of a subsequent record date,
however, shall in no way affect the rights of bondholders or of the Trustee consequent on any default.

Except as provided in this Section 2.01, every Bond of the 2025 Series shall be dated as provided in Section 2.05 of the
Original Indenture except that upon original issuance of the Bonds of the 2025 Series, the Bonds of the 2025 Series shall be dated the
date of authentication.  Notwithstanding any provision in the Original Indenture to the contrary, so long as there is no existing default in
the payment of interest on the Bonds of the 2025 Series, all Bonds of the 2025 Series authenticated by the Trustee between the record
date for any interest payment date and such interest payment date shall be dated such interest payment date and shall bear interest from
such interest payment date.

As permitted by the provisions of Section 2.10 of the Original Indenture and upon payment at the option of the Company of a
sum sufficient to reimburse it for any stamp tax or other governmental charge as provided in Section 2.11 of the Original Indenture,
Bonds of the 2025 Series may be exchanged for other Bonds of the 2025 Series of different authorized denominations of like aggregate
principal amount.  Notwithstanding the provisions of Section 2.11 or the last sentence of the first paragraph of Section 2.12 of the
Original Indenture, no further sum, other than the sum sufficient to reimburse the Company for any stamp taxes or other governmental
charges, shall be required to be paid upon any exchange or replacement of Bonds of the 2025 Series or upon any transfer thereof.

The Bonds of the 2025 Series shall be nontransferable prior to maturity except upon the prior written consent of the Company
or to effect transfer to any successor or assignee of BNY Agent if and to the extent that BNY Agent shall have assigned its rights under
the Reimbursement Agreement, any such transfer to be made at the principal corporate trust office of the Trustee in the City of Chicago,
Illinois, upon surrender and cancellation of such Bonds of the 2025 Series, accompanied by a written instrument of transfer in a form
approved by the Company, duly executed by the registered owner of such Bonds of the 2025 Series or by his duly authorized attorney,
and thereupon a new Bond of the 2025 Series, for a like principal amount, will be issued to the successor of BNY Agent, in exchange
therefor.

The Trustee hereunder shall, by virtue of its office as such Trustee, be the registrar and transfer agent of the Company for the purpose
of registering and transferring Bonds of the 2025 Series.  Notwithstanding any provision in the Original Indenture to the contrary,
neither the Company nor the Trustee shall be required to make transfers or exchanges of Bonds of the 2025 Series for a period of ten
days next preceding any designation of the Bonds of the 2025 Series to be redeemed and neither the Company nor the Trustee shall be
required to make transfers or exchanges of any bonds designated in whole for redemption or that part of any bond designated in part for
redemption.

******Section 2.02.  Form of Bonds of the 2025 Series.**  The text of the Bonds of the 2025 Series and the Trustee's authentication
certificate to be executed on the Bonds of said series, shall be in substantially the following forms, respectively.

[FORM OF FACE OF BOND OF THE 2025 SERIES]

No. [     ]	$______________

MAINE PUBLIC SERVICE COMPANY

First Mortgage and Collateral Trust Bond,

Series due 2025

Due October 1, 2025

MAINE PUBLIC SERVICE COMPANY, a Maine corporation (hereinafter sometimes called the "Company"), for value received,
hereby promises to pay to ______________ or registered assigns,  on October 1, 2025, the sum of _____________ Dollars (the "Stated
Principal Amount") or, if less, the Effective Principal Amount (as hereinafter defined) on such date, and to pay to the registered owner hereof
interest on the Stated Principal Amount or, if less, on the Effective Principal Amount from the date hereof at the applicable rate of interest
as set forth in, and in accordance with, the Reimbursement Agreement (as hereinafter defined) until the payment of the principal thereof.

The Bonds of the 2025 Series, including this bond, are issued to secure the obligations of the Company under a Letter of Credit
and Reimbursement Agreement, dated as of October 1, 2000 (the "Reimbursement Agreement") among the Company, The Bank of New
York ("BNY") and Fleet National Bank ("Fleet") and The Bank of New York, as Agent (in such capacity, "BNY Agent") and as Issuing
Bank (in such capacity, "BNY Issuing Bank"), pursuant to which BNY Issuing Bank has issued its irrevocable, transferrable, direct-pay
letter of credit (the "Letter of Credit") to support certain Maine Public Utility Financing Bank Public Utility Refunding Revenue Bonds,
Series 2025 (Maine Public Service Company Project) (the "Revenue Bonds"). The obligations and liabilities (including, but not limited
to, obligations with respect to any fees, disbursements or other expenses and indemnification) of the Company due and to become due under
or otherwise in respect of the Reimbursement Agreement, whether direct or indirect, joint or several, absolute or contingent, liquidated or
unliquidated, now or hereafter existing, extended or renewed, deferred, refunded, refinanced or restructured, and including all indebtedness
of the Company under any instrument now or hereafter evidencing any of the foregoing, are all hereinafter called the "Reimbursement
Agreement Obligations".  The "Effective Principal Amount" of this bond as of the time  of any determination is an amount equal to the
Reimbursement Agreement Obligations outstanding and unpaid at such time multiplied by a fraction, the numerator of which is 5 and the
denominator of which is 9.525, such product in turn to be multiplied by a fraction, the numerator of which is the Stated Principal Amount
and the denominator of which is $5,000,000.

The obligation of the Company to make any payment of interest on the Bonds of the 2025 Series, when such interest shall be due
and payable (including, but not limited to, October 1, 2025), shall be deemed to be, and shall be, satisfied and discharged if the Company
shall have paid all interest under the Reimbursement Agreement then due and payable.  The obligation of the Company to make payments
with respect to the principal of the Bonds of the 2025 Series at any time shall be deemed to be, and shall be, satisfied and discharged if, at
any time that such payment of principal shall be due (including, but not limited to, October 1, 2025), the Company shall have paid all
amounts then due pursuant to Sections 2.03 and 2.04 of the Reimbursement Agreement or otherwise due with respect to Reimbursement
Agreement Obligations.

The principal of and interest on this bond will be paid in any coin or currency of the United States of America which at the time
of payment is legal tender for the payment of public and private debts at the principal office in the City of Chicago, Illinois, of the Trustee
under the Indenture mentioned on the reverse hereof except that in case of the redemption as a whole at any time of the bonds of this series
then outstanding, the Company may designate in the redemption notice other offices or agencies at which, at the option of the registered
holder, this bond may be surrendered for redemption and payment.  Interest on this bond will be payable at the Corporate Trust Division
office in the City of Chicago, Illinois, of the Trustee, or, at the option of the holder hereof, at the agency of the Company in the Borough
of Manhattan, City and State of New York; provided, however, that interest on this bond shall, unless otherwise directed by the registered
holder hereof, be paid by check payable to the order of the registered holder entitled thereto and mailed by the Trustee by first class mail,
postage prepaid, to such holder at his address as shown on the bond register for the bonds in this series.

This bond shall not become or be valid or obligatory for any purpose until the authentication certificate hereon shall have been
signed by the Trustee.

The provisions of this bond are continued on the reverse hereof and such continued provisions shall for all purposes have the same
effect as though fully set forth at this place.

IN WITNESS WHEREOF, MAINE PUBLIC SERVICE COMPANY has caused these presents to be executed in its name and
behalf by its President or one of its Vice Presidents and its corporate seal or a facsimile thereof to be affixed hereto and attested by its
Secretary or one of its Assistant Secretaries, all as of __________, 20__.

MAINE PUBLIC SERVICE COMPANY

By:

Vice President

Attest:



Secretary

[FORM OF REVERSE OF BOND OF THE 2025 SERIES]

This bond constitutes the entire series designated as Bonds of the 2025 Series, of an authorized issue of bonds of the Company,
known as First Mortgage and Collateral Trust Bonds, issued under and equally secured (except in so far as any sinking fund, replacement
fund or other fund established in accordance with the provisions of the Indenture hereinafter mentioned may afford additional security for
the bonds of any specific series) by an Indenture of Mortgage and Deed of Trust dated as of October 1, 1945, duly executed and delivered
by the Company to U.S. Bank Trust National Association, (formerly known as First Trust National Association, as successor to Continental
Bank, National Association (formerly, Continental Illinois National Bank and Trust Company of Chicago)), as Trustee, to which Indenture
of Mortgage and Deed of Trust as supplemented and modified by indentures supplemental thereto, including a Twentieth Supplemental
Indenture dated as of October 1, 2000, duly executed by the Company to said Trustee and all further indentures supplemental thereto (herein
sometimes collectively called the "Indenture").  Reference is hereby made for a description of the property mortgaged and pledged as
security for said bonds, the nature and extent of the security, and the rights, duties and immunities thereunder of the Trustee, the rights of
the holders of said bonds and of the Trustee and of the Company in respect of such security, and the terms upon which said bonds may be
issued thereunder.

This bond shall be subject to redemption as a whole or in part, at any time, at the option of the Company prior to maturity upon
payment of the principal amount hereof on the date fixed for redemption in the manner provided for in the Indenture.  In the event that the
Revenue Bonds outstanding under the Indenture of Trust, dated as of October 1, 2000, between the Maine Public Utility Financing Bank
and State Street Bank and Trust Company (the "Revenue Bond Indenture") shall become immediately due and payable pursuant to Section
9.01(e) or 9.01(f) of the Revenue Bond Indenture, this bond shall be redeemed by the Company, on the date such Revenue Bonds shall have
become immediately due and payable.  In such event, this bond shall be redeemed by the Company at the Stated Principal Amount hereof
or, if less, the Effective Principal Amount hereof on the date fixed for redemption, plus unpaid interest accrued to the date of redemption.

If this bond (or any portion thereof (One Dollar or a multiple thereof)) is duly called for redemption and payment duly provided
for as specified in the Indenture, this bond shall cease to be entitled to the lien of the Indenture from and after the date payment is so
provided for and shall cease to bear interest from and after the redemption date.

Except as may be otherwise provided in any agreement entered into pursuant to the provisions of said Twentieth Supplemental
Indenture, in the event of the selection for redemption of a portion only of the principal of this bond, payment of the redemption price will
be made only (a) upon presentation of this bond for notation hereon of such payment of the portion of the principal of this bond so called
for redemption, or (b) upon surrender of this bond in exchange for a bond or bonds of authorized denominations of the same series, for the
unredeemed balance of the principal amount of this bond.

The Indenture contains provisions permitting the Company and the Trustee, with the consent of the holders of the not less than
seventy-five percent in principal amount of the bonds (exclusive of bonds disqualified by reason of the Company's interest therein) at the
time outstanding, including, if more than one series of bonds shall be at the time outstanding, not less than sixty percent in principal amount
of each series affected, to effect, by an indenture supplemental to the Indenture, modifications or alterations of the Indenture and of the rights
and obligations of the Company and of the holders of the bonds; provided, however, that no such modification or alteration shall be made
without the written approval or consent of the registered holder hereof which will (a) extend the maturity of this bond or reduce the rate or
extend the time of payment of interest hereon or reduce the amount of the principal hereof or (b) permit the creation of any lien, not
otherwise permitted, prior to or on a parity with the lien of the Indenture, or (c) reduce the aforesaid percentage of the principal amount of
the bonds, the holders of which are required to approve or consent to such modification or alteration.

The Company and the Trustee and any paying agent may deem and treat the person in whose name this bond shall be registered
upon the bond register for the bonds of this series as the absolute owner of such bond for the purpose of receiving payment of or on account
of the principal of and interest on this bond and for all other purposes, whether or not this bond be overdue; and all such payments so made
to such registered holder or upon his order shall be valid and effectual to satisfy and discharge the liability upon this bond to the extent of
the sum or sums so paid and neither the Company nor the Trustee nor any paying agent shall be affected by any notice to the contrary.

This bond is nontransferable prior to its maturity except upon the prior written consent of the Company or to effect transfer to any
successor or assignee of BNY Agent if and to the extent that BNY Agent shall have assigned its rights under the Reimbursement Agreement,
any such transfer to be made at the principal corporate trust office of the Trustee in the City of Chicago, Illinois, or, at the option of such
registered holder hereof, at the agency of the Company in the Borough of Manhattan, City and State of New York, upon surrender of this
bond for cancellation and upon payment, if the Company shall so require, of the stamp taxes and other governmental charges provided for
in said Twentieth Supplemental Indenture, accompanied by a written instrument of transfer in a form approved by the Company, duly
executed by the registered owner of this bond or by his duly authorized attorney, and thereupon a new bond of this series, for a like principal
amount, will be issued to the successor or assignee of BNY Agent in exchange therefor, as provided in the Indenture.

The registered holder of this bond at his option may surrender the same for cancellation at said office of the Trustee and receive
in exchange therefor the same aggregate principal amount of registered bonds of the same series but of other authorized denominations upon
payment, if the Company shall so require, of the stamp taxes and other governmental charges provided for in said Twentieth Supplemental
Indenture and subject to the terms and conditions therein set forth.

Neither the Company nor the Trustee shall be required to make transfers or exchanges of bonds of this series for a period of ten
days next preceding any designation of bonds of said series to be redeemed, and neither the Company nor the Trustee shall be required to
make transfers or exchanges of any bonds designated in whole for redemption or that part of any bond designated in part for redemption.
Subject to the provisions of said Twentieth Supplemental Indenture, if this bond is surrendered for any transfer or exchange between the
record date for any interest payment date and such interest payment date, the new bond will be dated such interest payment date.

The Indenture provides that in the event of any default in payment of the interest due on any interest payment date, such interest
shall not be payable to the holder of the bond on the original record date but shall be paid to the registered holder of such bond on the
subsequent record date established for payment of such defaulted interest.

If a default as defined in the Indenture shall occur, the principal of this bond may become or be declared due and payable before
maturity in the manner and with the effect provided in the Indenture.  The holders, however, of certain specified percentages of the bonds
at the time outstanding, including in certain cases specific percentages of bonds of particular series, may in these cases, to the extent and
under the conditions provided in the Indenture, waive past defaults thereunder and the consequences of such defaults.

No recourse shall be had for the payment of the principal of or the interest on this bond, or for any claim based hereon, or otherwise
in respect hereof or of the Indenture, against any incorporator, stockholder, director or officer, past, present or future, as such, of the
Company or of any predecessor or successor corporation, either directly or through the Company or such predecessor or successor
corporation, under any constitution or statute or rule of law, or by the enforcement of any assessment or penalty, or otherwise, all such
liability of incorporators, stockholders, directors and officers, as such, being waived and released by the holder and owner hereof by the
acceptance of this bond and as provided in the Indenture.

This bond shall not become or be valid or obligatory for any purpose until the authentication certificate hereon shall have been
manually signed by the Trustee.

[FORM OF TRUSTEE'S AUTHENTICATION CERTIFICATE FOR

BONDS OF THE 2025 SERIES]

This is one of the bonds, of the series designated therein, described in the within mentioned Indenture.

U.S. BANK TRUST NATIONAL

ASSOCIATION,

As Trustee,

By:

Authorized Officer

**Section 2.03.  Discharge of Company's Obligation for Payment.**  The obligation of the Company to make any payment of interest
on Bonds of the 2025 Series, when such interest shall be due and payable (including, but not limited to, October 1, 2025), shall be deemed
to be, and shall be, satisfied and discharged if the Company shall have paid all interest under the Reimbursement Agreement then due and
payable.  The obligation of the Company to make payments with respect to the principal of Bonds of the 2025 Series at any time shall be
deemed to be, and shall be, satisfied and discharged if, at any time that any such payment of principal shall be due (including, but not limited
to, October 1, 2025), the Company shall have paid BNY Agent all amounts then due pursuant to Sections 2.03 and 2.04 of the
Reimbursement Agreement or otherwise due with respect to the Reimbursement Agreement Obligations.  The Trustee may conclusively
presume that at any particular time, the obligations of the Company to make payments with respect to the principal of and interest on the
Bonds of the 2025 Series shall have been satisfied and discharged up until such time unless and until the Trustee shall have received a notice
as described in Section 12.01(l) of the Indenture.  Whenever all of the Reimbursement Agreement Obligations shall have been satisfied and
the Letter of Credit shall have been terminated, the aggregate principal amount of all of the Bonds of the 2025 Series shall be surrendered
by BNY Agent to the Trustee for cancellation, and upon such surrender shall be deemed fully paid.

**Section 2.04.  Redemption Provisions for the Bonds of the 2025 Series.** The Bonds of the 2025 Series shall be subject to
redemption as a whole or in part, at any time, at the option of the Company prior to maturity upon payment of an amount equal to the Stated
Principal Amount thereof or, if less, the Effective Principal Amount thereof including interest accrued thereon to the redemption date.

In the event that the Revenue Bonds outstanding under the Indenture of Trust, dated as of October 1, 2000, between the Maine
Public Utility Financing Bank and State Street Bank and Trust Company (the "Revenue Bond Indenture") shall become immediately due
and payable pursuant to Section 9.01(e) or 9.01(f) of the Revenue Bond Indenture, all Bonds of the 2025 Series then outstanding shall be
redeemed by the Company, on the date such Revenue Bonds shall have become immediately due and payable.  In such event, the Bonds
of the 2025 Series shall be redeemed by the Company at the Stated Principal Amount thereof or, if less, the Effective Principal Amount
thereof on the date fixed for redemption, plus unpaid interest accrued to the date of redemption.

The Trustee may conclusively presume that no redemption of Bonds of the 2025 Series is required pursuant to this Section 2.04
unless and until the Trustee shall have received a written notice from BNY Agent stating that an "Event of Default" under the
Reimbursement Agreement has occurred and is continuing.  Said notice shall also contain a waiver of notice of such redemption by BNY
Agent as holder of all of the Bonds of the 2025 Series then outstanding.

No notice of redemption pursuant to Section 10.02 of the Indenture need be given if the holders of all Bonds of the 2025 Series
called for redemption waive notice thereof in writing and such waiver is filed with the Trustee.

**Section 2.05.  Bondholders' List.**  Notwithstanding the provisions of Section 11.02(B) of the Original Indenture, any one of the
holders of the Bonds of the 2025 Series shall be entitled to make application to the Trustee for a Bondholders' list as provided for in Section
11.02.

**Section 2.06.  Mutilated, Lost or Destroyed Bonds.**  Notwithstanding the provisions of Section 2.12 of the Original Indenture,
for so long as any holder of Bonds of the 2025 Series shall be an institutional holder, an unsecured indemnity provided by such holder shall
be deemed acceptable for purposes of requesting a replacement bond for a mutilated, lost or destroyed Bond of the 2025 Series.

**Section 2.07.  Duration of Effectiveness of Article Two.**  This Article shall be of force and effect only so long as any Bonds of
the 2025 Series are outstanding.

**ARTICLE 3**

**Modification of the Indenture**

**Section 3.01.**Section 12.01 of the Indenture is hereby amended by adding new clause (l) thereto which reads as follows:

"(l)  so long as any of the Bonds of the 2025 Series are outstanding, upon receipt by the Trustees of a notice from the
holder of the Bonds of the 2025 Series that an event of default under the Reimbursement Agreement has occurred and
is continuing;"

**Section 3.02.  Duration of Effectiveness of Article Three.**  This Article shall be of force and effect only so long as any Bonds of
the 2025 Series are outstanding.

**ARTICLE 4**

**Authentication and Delivery of Bonds of the 2025 Series**

**Section 4.01.**Upon the execution and delivery of this Twentieth Supplemental Indenture, Bonds of the 2025 Series in the
aggregate amount of Five Million Dollars ($5,000,000) may forthwith, or from time to time thereafter, and upon compliance by the
Company with the provisions of Article Five of the Indenture, be executed by the Company and delivered to the Trustee and shall thereupon
be authenticated and delivered by the Trustee to or upon the written order of the Company.  Additional Bonds of the 2025 Series may be
executed, authenticated and delivered from time to time as permitted by the provisions of Article Five of the Original Indenture.

**ARTICLE 5**

**Section 5.01.**The Company may enter into an agreement with the holder of any registered Bond without coupons of any series
providing for the payment to such holder of the principal of and the premium, if any, and interest on such Bond or any part thereof at a place
other than the offices or agencies therein specified, and for the making of notation, if any, as to the principal payments on such Bond by
such holder or by an agent of the Company or of the Trustee.  The Trustee is authorized to approve any such agreement, and shall not be
liable for any act or omission to act on the part of the Company, any such holder or any agent of the Company in connection with any such
agreement.

**Section 5.02.**  This Twentieth Supplemental Indenture is executed and shall be construed as an indenture supplemental to the
Original Indenture, as amended and supplemented, and shall form a part thereof, and, except as hereby supplemented, the Original Indenture,
as amended and supplemented, is hereby ratified, approved and confirmed.

**Section 5.03.**  The recitals contained in this Twentieth Supplemental Indenture are made by the Company and not by the Trustee
and all of the provisions contained in the Original Indenture, as amended and supplemented, in respect of the rights, privileges, immunities,
powers and duties of the Trustee shall, except as hereinabove modified, be applicable in respect hereof as fully and with like effect as if set
forth herein in full.

**Section 5.04.**Nothing in this Twentieth Supplemental Indenture contained shall be deemed to abrogate, modify or contravene
any provisions of the Original Indenture, as amended and supplemented, required to be included therein by any of the provisions of Section
310 to 318, inclusive, of the Trust Indenture Act of 1939, it being the intention hereof that said provisions of the Original Indenture, as
amended and supplemented, shall continue in full force and effect.  Unless otherwise indicated, the terms used in this Nineteenth
Supplemental Indenture are intended to have the meanings given to such terms in the Original Indenture, as amended and supplemented.

**Section 5.05.**  Nothing in this Twentieth Supplemental Indenture expressed or implied is intended or shall be construed to give
to any person other than the Company, the Trustee, and the holders of the Bonds issued and to be issued under the Indenture, any legal or
equitable right, remedy or claim under or in respect of the Original Indenture, as amended and supplemented, or this Twentieth
Supplemental Indenture, or under any covenant, condition or provisions therein or herein or in the Bonds contained; and all such covenants,
conditions and provisions are and shall be held to be for the sole and exclusive benefit of the Company, the Trustee and the holders of the
Bonds issued and to be issued under the Indenture.

**Section 5.06.**The titles of Articles and any wording on the cover of this Twentieth Supplemental Indenture are inserted for
convenience only.

**Section 5.07.**  All the covenants, stipulations, promises and agreements in this Twentieth Supplemental Indenture contained made
by or on behalf of the Company or of the Trustee shall inure to and bind their respective successors and assigns.

**Section 5.08.**Although this Twentieth Supplemental Indenture is dated for convenience and for the purpose of reference as of
October 1, 2000, the actual date or dates of execution by the Company and by the Trustee are as indicated by their respective
acknowledgments hereto annexed.

**Section 5.09.**In order to facilitate the recording or filing of this Twentieth Supplemental Indenture, the same may be
simultaneously executed in several counterparts, each of which shall be deemed to be an original, and such counterparts shall together
constitute but one and the same instrument.

IN WITNESS WHEREOF, MAINE PUBLIC SERVICE COMPANY has caused this Twentieth Supplemental Indenture to be
signed in its corporate name and behalf by its President or one of its Vice Presidents and its corporate seal to be hereunto affixed and attested
by its Secretary, or one of its Assistant Secretaries; and U.S. BANK TRUST NATIONAL ASSOCIATION in token of its acceptance of
the trust hereby created has caused this Twentieth Supplemental Indenture to be signed in its corporate name and behalf by its President
or one of its Vice Presidents or one of its Second Vice Presidents and its corporate seal to be hereunto affixed and attested by its Assistant
Secretary, all as of the day and year first above written.

MAINE PUBLIC SERVICE COMPANY

/s/ Larry E. LaPlante

Name:	Larry E. LaPlante

Title:	Vice President

CORPORATE SEAL

Attest:

/s/ Stephen A. Johnson

Name:	Stephen A. Johnson

Title:	Secretary

Signed, sealed and delivered

by MAINE PUBLIC SERVICE COMPANY

in the presence of:

/s/ Marilyn L. Bouchard

Marilyn L. Bouchard

/s/ Alice E. Shepard

Alice E. Shepard

U.S. BANK TRUST NATIONAL ASSOCIATION



/s/ Patrick J. Crowley

Name:	Patrick J. Crowley

Title:	Vice President

CORPORATE SEAL

Attest:

/s/ Cynthia W. Brown

Name:	Cynthia W. Brown

Title:	Assistant Vice President

Signed, sealed and delivered

by U.S. BANK TRUST NATIONAL

ASSOCIATION in the presence of:

/s/ Aldrin M.F. Bayne

Name:	Aldrin M.F. Bayne

Title:	Trust Officer

Exhibit 10(r)





This Agreement made as of this 11th day of December, 2000 by and between MAINE PUBLIC SERVICE COMPANY, a Maine
corporation with its principal place of business in Presque Isle, Maine (the "Company") and Michael A. Thibodeau of Presque Isle, Maine,
("Officer").

WHEREAS, the Officer has been employed by the Company in a management capacity for over 14 years, and is now its Vice
President, Human Resources; and

WHEREAS, the Officer's knowledge of the Company's affairs and his experience are critical to the protection and enhancement
of the best interests of the Company, its employees, ratepayers and stockholders; and

WHEREAS, in the current business climate acquisitions of smaller, independently-operated utility companies is common; and

WHEREAS, the Company desires to assure itself of the continued employment of the Officer and the benefit of his independent
judgment in the operation of the Company, particularly in the event that any such acquisition was being considered, in light of the disruption
resulting from such event;

WHEREAS, the Company and the Officer entered into an Employment Continuity Agreement, dated November 5, 1999; and

WHEREAS, Section 13 of the Agreement provides that the Agreement may be amended in writing by the parties; and

WHEREAS, the Officer has been promoted to Vice President, the parties desire to amend and restate the Agreement as set forth
herein;

NOW, THEREFORE, in consideration of the mutual promises and undertakings herein contained and for other good and valuable
consideration, the receipt and adequacy of which is acknowledged by each of the parties, the Officer and the Company agree as follows:

1.	Term of the Agreement and Renewal.  The term of this Agreement shall be for a period beginning September 13,  1999,
and ending December 31, 2001.  On January 1,  2002, and on January 1 of each period of three (3) years thereafter (in each case such date
to be a "Renewal Date") this Agreement automatically shall be renewed for an additional three (3) year term, unless at least one (1) year
prior to any such Renewal Date, either party shall have given written notice to the other that such renewal shall not take place.  Such notice
may be given by the Company only upon the affirmative vote of the Compensation Committee of the Board of Directors.

2.	Rights Upon Involuntary Termination of Employment. If, within twenty-four (24) months after the occurrence of a Change
in Control Event, the Company terminates the Officer's employment for any reason other than Good Cause as defined in Paragraph 4, or
if the Officer voluntarily terminates employment for Good Reason as defined in Paragraph 3, the Company shall provide the Officer with
the following:

(a)	Within thirty (30) days of such termination, a lump sum cash payment in an amount equal to the sum of:

(i)	two hundred percent (200%) of the Officer's annual base salary in effect upon the date of the Change
in Control Event, and****

****(ii)	two hundred percent (200%) of the award the Officer would have received for the year in which such
termination occurs, pursuant to the Maine Public Service Company Incentive Compensation Plan, assuming that his
employment had not terminated and that for such year all applicable performance goals will be met.

(b)	The continuation of the Officer's participation and the participation of his dependents (to the extent they were
participating prior to his termination of employment) in the Company's health, life, disability and other employee benefit plans,
programs and arrangements (excluding the Maine Public Service Company Pension Plan and the Maine Public Service Company
Non-Union Retirement Savings Plan) for a period of twenty-four (24) months after such termination as if he were still employed
during such period; provided, however, if such participation in any such plan, program or arrangement is specifically prohibited
by the terms thereof, the Company shall provide the Officer (and his dependents) with benefits substantially similar to those which
he was entitled to receive under such plan, program or arrangement immediately prior to his termination of employment.
Additionally, at the end of any period of such coverage, the Officer shall have the right to have assigned to him, for the cash
surrender value thereof, any assignable insurance owned by the Company on the life of the Officer. For purposes of this Paragraph
2(b), any employee benefit determined with reference to the Officer's compensation or earnings shall be based on his annual base
salary unless otherwise provided under the terms of the applicable employee benefit plan, program or arrangement.



(c)	The Company shall pay the Officer an amount equal to the award he would have been entitled to receive under
the Company's Incentive Compensation Plan, if his employment had not terminated, based on the base salary he had earned as of
his termination date, and assuming that for such year all applicable performance goals will be met.  Such payment shall be made
within ninety (90) days after his employment terminates.



3.	 Termination  for Good Reason.  For purposes of this Agreement, termination by the Officer of his employment for "Good
Reason," except upon the Officer's express written consent otherwise, shall mean:

(a)	the assignment of duties to the Officer which:

2

(i)	are materially different from his duties immediately prior to the Change in Control Event, or

(ii)	result in his having significantly less authority or responsibility than he had prior to the Change in
Control Event; or

(b)	the Officer's removal from, or any failure to re-elect him to, any position he held immediately prior to the
Change in Control Event with either the Company or any majority-owned subsidiary; or

(c)	a reduction of the Officer's annual base salary in effect on the date of the Change in Control Event or as the same
may be increased from time to time thereafter; or

(d)	the Company's transferring or assigning the Officer to a place of employment more than twenty-five (25) miles
from Presque Isle, Maine, except for required business travel to an extent substantially consistent with his business travel
obligations immediately prior to the Change in Control Event; or

(e)	the Company's failure to provide the Officer with substantially the same health, life and other employee benefit
plans, programs and arrangements (specifically including the Company's compensation and incentive plans, as the same may be
amended in the future), and substantially the same perquisites of employment, as provided to him immediately prior to the Change
in Control Event or as the same may be increased thereafter; or

(f)	the Company's failure to provide the Officer with substantially the same support staff as provided to him
immediately prior to the Change in Control Event; or

(g)	the Company's failure to increase the Officer's salary, employee benefits or perquisites of employment in a
manner or amount commensurate with increases provided to the Company's other executive officers; or

(h)	the Company's failure to obtain from any successor a satisfactory agreement to assume and perform the terms
of this Agreement.

4.	Termination by Reason of Death or for Good Cause.   Notwithstanding any provision of this Agreement to the contrary,
no benefits are payable hereunder upon the Officer's death prior to his involuntary termination of employment pursuant to Paragraph 2 or
voluntary termination of employment for Good Reason pursuant to Paragraph 3.  The Company retains the right to terminate the Officer
for "Good Cause," in which event he shall not be entitled to receive any payment or benefits pursuant to this Agreement.  "Good Cause"
shall mean:

3

(a)	the Officer's conviction, by a court of competent jurisdiction, of a crime adversely reflecting on his honesty,
trustworthiness or fitness to carry out the responsibilities of his position with the Company in other respects; or

(b)	a willful breach by him of any material duty or obligation imposed upon him under the terms of his employment,
as those terms existed immediately prior to any Change in Control Event, and his failure to cure such breach within thirty (30) days
after receiving notice thereof from the Company.

5.	 "Change in Control Event."  Each of the following events shall constitute a "Change in Control Event" for purposes of
this Agreement:

(a)	Any person acquires beneficial ownership of Company securities and is or thereby becomes a beneficial owner
of securities entitling such person to exercise twenty-five percent (25%) or more of the combined voting power of the Company's
then outstanding stock.

For purposes of this Agreement, "beneficial ownership" shall be determined in accordance with Regulation 13D under
the Securities Exchange Act of 1934, or any similar successor regulation or rule; and the term "person" shall include any natural
person, corporation, partnership, trust or association, or any group or combination thereof, whose ownership of Company securities
would be required to be reported under such Regulation 13D, or any similar successor regulation or rule.

(b)	The Company ceases to be a reporting company pursuant to Section 13(a) of the Securities Exchange Act of
1934 or any similar successor provision.

(c)	The number of the Company's Outside Directors, as defined herein, is decreased by more than fifty percent
(50%) in any twenty-five (25) month period or the number of the Company's directors is increased such that the Outside Directors
constitute less than a majority of the Board.



(d)	Within any twenty-five (25) month period, individuals who were Outside Directors at the beginning of such
period, together with any other Outside Directors first elected as directors of the Company pursuant to nominations approved or
ratified by at least two-thirds (2/3) of the Outside Directors in office immediately prior to such respective elections, cease to
constitute a majority of the board of directors of the Company.

(e) 	The Company is subject to a change in control which would require reporting in response to Item 1 of Form
8-K under Regulation 13a-11 promulgated under the Securities Exchange Act of 1934, as amended, or any similar successor statute
or rule, whether or not the Company is a reporting company under such Act.

4

(f) 	The Company's stockholders approve:

(i)	any consolidation or merger of the Company in which the Company is not the continuing or surviving
corporation or pursuant to which shares of Company common stock would be converted into cash, securities or other
property, other than a merger or consolidation of the Company in which the holders of the Company's common stock
immediately prior to the merger or consolidation have substantially the same proportionate ownership and voting control
of the surviving corporation immediately after the merger or consolidation; or

(ii)	any sale, lease, exchange, liquidation or other transfer (in one transaction or a series of transactions)
of all or substantially all of the assets of the Company.

Notwithstanding subparagraphs (i) and (ii) above, the term "Change in Control Event" shall not include a consolidation, merger,
or other reorganization if upon consummation of such transaction all of the outstanding voting stock of the Company is owned,
directly or indirectly, by a holding company, and the holders of the Company's common stock immediately prior to the transaction
have substantially the same proportionate ownership and voting control of the holding company.

6.	Outside Directors.  For purposes of this Agreement, an "Outside Director" as of a given date shall mean a member of
the Company's board of directors who has been a director of the Company throughout the six (6) months prior to such date and who has
not been an employee of the Company at any time during such six (6) month period.

7.	Notices.  Any and all notices required or permitted to be given hereunder shall be in writing and shall be deemed to have
been given when deposited in the United States mails, certified or registered mail, postage prepaid and addressed as follows:

To the Officer:	Michael A. Thibodeau

103 Fleetwood Street

Presque Isle, Maine 04769-3030

To the Company:	Maine Public Service Company

P. 0. Box 1209

Presque Isle, Maine 04769-1209



Either party may change by notice to the other the address to which notices to it are to be addressed.

8.	Applicable Law, Taxes, Binding Agreement, Severability, Construction.

(a) 	This Agreement shall be governed by and construed in accordance with the laws of the State of Maine, except
as to any matter which is preempted by federal law.

5

(b) 	Notwithstanding anything to the contrary herein contained, the Company may withhold from any amounts
payable under this Agreement all federal, state or other taxes or assessments which may be required by applicable statute or
regulation to be withheld.

(c) 	This Agreement shall be binding upon and inure to the benefit of the Officer, his heirs, assigns, executors and
legal representatives; and the Company, its successors and assigns.

(d) 	If any provision of this Agreement shall be held invalid or unenforceable by a court of competent jurisdiction,
the remainder of this Agreement shall not be affected thereby.

(e) 	The Outside Directors shall have the authority to construe and interpret this Agreement on behalf of the
Company, and any such determination by the Outside Directors shall be conclusive on the Company.

9.	Limitation on Amount to be Paid.  If payment of any amount under this Agreement would cause the Officer to be subject
to an excise tax pursuant to Section 4999 of the Internal Revenue Code (as amended from time to time) or the regulations thereunder, then
such amount shall not be paid to the extent necessary to avoid the imposition of such tax.  The preceding sentence shall apply only if the
aggregate amount payable to the Officer or for his benefit under the Agreement, after payment of such excise tax, would be less than the
aggregate amount payable in accordance with the preceding sentence.

10.	Funding.  This Agreement shall not be construed to create or require the Company to create a trust or to otherwise act
to fund the amounts payable hereunder.

11.	Assignment.  Except as required by law, the right to receive payments hereunder shall not be subject to alienation,
assignment, garnishment, attachment, execution or levy of any kind, and any attempt to cause such payments to be so subject shall not be
recognized by the Company.

12.	Execution of Further Documents.  In the event the Officer receives payments or benefits pursuant to the terms hereof and
the Company's independent counsel deems it necessary for the Company to receive a release or other acknowledgment, the Officer agrees
to execute any such document, as may be reasonably required as a condition of his receipt of such payment or benefits.

13.	Amendment and Waiver.  The Agreement may be amended only in writing, by the parties hereto, and no condition or
provision of the Agreement may be waived except in writing.  Waiver by either party at any time of the other party's breach of, or failure
to comply with, any condition or provision of this Agreement to be performed by such other party shall not be deemed a waiver of any other
provision or condition at the same time or of any provision or condition at any prior or subsequent time, unless specifically stated therein.

6

14.	Arbitration.  In recognition of the mutual benefits of arbitration, the parties hereby agree that arbitration as provided for herein
shall be the exclusive remedy for resolving any claim or dispute arising under this Agreement, and hereby mutually waive any and all other
remedies at law or in equity for determining any such claim or dispute.

(a)	Any arbitration under this Agreement, and any related judicial proceeding, shall be initiated and shall proceed pursuant
to the provisions of the Maine Uniform Arbitration Act (the "Act") and, to the extent consistent with the Act, the then prevailing rules
of the American Arbitration Association (the "Association") for labor and employment contracts.  To initiate arbitration hereunder,
demand shall be given in writing to the Association and the other party no later than one year after the claim arises.  Any claim for which
such demand is not made within one year after the claim arises shall be barred and discharged absolutely.

(b)	Any arbitration under this Agreement shall be before a single arbitrator, and an award in such arbitration may include
only damages which the arbitrator determines to be due under express provisions of this Agreement.  The arbitrator shall have no
authority to award any other damages, including without limitation, consequential and exemplary damages.  Any award in arbitration
shall be subject to enforcement and appeal pursuant to the Act.

(c)	The parties shall share equally all costs and fees charged by the Association or the arbitrator.

15.	No Additional Effect.  Except as expressly provided herein, nothing contained herein shall be construed to provide the Officer
with any specific period of employment, right to be retained in the service of the Company or other rights, nor shall this Agreement be
construed to otherwise limit the rights of the Company to discharge or take other action with respect to the Officer.

IN WITNESS WHEREOF, the parties have executed this Agreement as of the day and year first above written.

Witness:						MAINE PUBLIC SERVICE COMPANY

/s/ Paul R. Cariani					By /s/ Nathan L. Grass

Its Chairman, Executive Compensation

Committee

/s/ Alice E. Shepard					 /s/ Michael A. Thibodeau

Officer Michael A. Thibodeau

7

Exhibit 10(y)

THIS INSTRUMENT GRANTS A SECURITY INTEREST

BY A TRANSMITTING UTILITY

THIS INSTRUMENT CONTAINS AFTER-ACQUIRED PROPERTY PROVISIONS

MAINE PUBLIC SERVICE COMPANY

TO

THE BANK OF NEW YORK

Trustee

FIFTH SUPPLEMENTAL INDENTURE

Dated as of October 1, 2000

Supplementing and Modifying Indenture of Second Mortgage

and Deed of Trust dated as of October 1, 1985

and

Relating to an Issue of Second Mortgage and

Collateral Trust Bonds, Series Due 2025

This is a Security Agreement granting a Security Interest

in Personal Property, Including Personal Property affixed to

Realty as well as a Mortgage

upon Real Estate and other Property.

******THIS FIFTH SUPPLEMENTAL INDENTURE** (hereinafter called the "Fifth Supplemental Indenture"), dated as of October 1,
2000, made by MAINE PUBLIC SERVICE COMPANY, a Maine corporation (hereinafter called the "Company"), party of the first part,
and THE BANK OF NEW YORK (as successor to J. Henry Schroder Bank and Trust Company), a banking corporation duly organized
and existing under the laws of the State of New York, and having its principal place of business in the City of New York, State of New York
(hereinafter called the "Trustee"), party of the second part.

**WHEREAS,** the Company has heretofore executed and delivered to the Trustee an Indenture of Second Mortgage and Deed of
Trust, dated as of October 1, 1985 (hereinafter called the "Original Indenture"), to secure the payment of principal and interest on, as
provided therein, its bonds (in the Original Indenture and herein called the "Bonds") to be designated generally as its "Second Mortgage
and Collateral Trust Bonds", and to be issued in one or more series as provided in the Original Indenture, pursuant to which the Company
provided for the creation of the Bonds of the initial series, known as Second Mortgage and Collateral Trust Bonds, Floating Rate Series A
due 1987 (herein sometimes called "Bonds of the 1987 Series"), Second Mortgage and Collateral Trust Bonds, 14% Series due 1990 (herein
sometimes called "Bonds of the 1990 Series") and Second Mortgage and Collateral Trust Bonds, 9 7/8% Series due 1995 (herein sometimes
called "Bonds of the 1995 Series" and together with the Bonds of the 1987 Series and the Bonds of the 1990 Series, called collectively the
"Bonds of the Initial Series"); and

WHEREAS, the Company has heretofore executed and delivered to the Trustee a First Supplemental Indenture, dated as of
March 1, 1991, pursuant to which the Company supplemented and modified the Original Indenture and provided for the creation of a fourth
series of Bonds designated as "Second Mortgage and Collateral Trust Bonds, Series due 1996" (herein sometimes called "Bonds of the 1996
Series"); and

**WHEREAS,** the Company has heretofore executed and delivered to the Trustee a Second Supplemental Indenture, dated as of
September 1, 1991, pursuant to which the Company supplemented the Original Indenture, as supplemented and modified, and provided
for the creation of a fifth series of Bonds designated as "Second Mortgage and Collateral Trust Bonds, 9.60% Series due 2001" (herein
sometimes called "Bonds of the 2001 Series"); and

**WHEREAS**, the Company has heretofore executed and delivered to the Trustee a Third Supplemental Indenture, dated as of June
1, 1996, pursuant to which the Company supplemented and modified the Original Indenture, as supplemented and modified, and provided
for the creation of a sixth series of Bonds designated as "Second Mortgage and Collateral Trust Bonds, Series due 2002" (herein sometimes
called "Bonds of the 2002 Series"); and

**WHEREAS,** the Company has heretofore executed and delivered to the Trustee a Fourth Supplemental Indenture, dated as of May
1, 1998, pursuant to which the Company supplemented and modified the Original Indenture, as supplemented and modified, and provided
for the creation of a seventh series of Bonds designated as "Second Mortgage and Collateral Trust Bonds, Series due 2008" (herein
sometimes called "Bonds of the 2008 Series"); and

**WHEREAS,** pursuant to the Original Indenture, as so supplemented and modified, there have been executed, authenticated and
delivered and there are now outstanding Second Mortgage and Collateral Trust Bonds of series and in principal amounts as follows:

|********                 | Issued       | Outstanding 
|------------------------ | ------------ | ------------
|Bonds of the 2002 Series | $15,875,000  | $13,600,000 
|Bonds of the 2008 Series | $  7,540,000 | $  7,540,000

which constitute the only Bonds outstanding under the Original Indenture, as so supplemented and modified; and

**WHEREAS,** the Company now desires to create a new series of Bonds to be designated Second Mortgage and Collateral Trust
Bonds, Series due 2025 (herein sometimes called the "Bonds of the 2025 Series"), and the Original Indenture provides that each series of
Bonds (except the Bonds of the Initial Series) shall be created by an indenture supplemental to the Original Indenture; and

**WHEREAS,** the Original Indenture further provides that all property of the character specifically described in the Original
Indenture, and all improvements, extensions, betterments or additions to the property specifically described in the Original Indenture,
constructed or acquired after the date of the execution and delivery of the Original Indenture, shall be and become subject to the lien of the
Original Indenture, and that the Company shall from time to time execute, acknowledge and deliver any and all such further assurances,
conveyances, mortgages or assignments of such property as may be required by the terms and provisions of the Original Indenture, or as
the Trustee under the Original Indenture may require, and the Company now desires to subject to the lien of the Original Indenture certain
additional properties which it has constructed or acquired since the date of execution and delivery of the Fourth Supplemental Indenture;
and

**WHEREAS,** all acts and proceedings required by law and by the charter and by-laws of the Company necessary to make the Bonds
of the 2025 Series to be initially issued when executed by the Company, authenticated and delivered by the Trustee and duly issued, the
valid, binding and legal obligations of the Company, and to constitute the Original Indenture, as heretofore supplemented and modified and
as supplemented and modified by this Fifth Supplemental Indenture, a valid and binding mortgage and deed of trust, subject to permitted
encumbrances including the lien of the Indenture of First Mortgage (each as defined in the Original Indenture), for the security of the Bonds,
in accordance with the terms of the Original Indenture, as so supplemented and modified, and the terms of the Bonds, have been done and
taken; and the execution and delivery of this Fifth Supplemental Indenture and the issue of the Bonds of the 2025 Series to be initially issued
have been in all respects duly authorized;

**NOW, THEREFORE,** for the purposes aforesaid and in pursuance of the terms and provisions of the Original Indenture, the
Company has executed and delivered this Fifth Supplemental Indenture (the Original Indenture, as supplemented and modified by the First
Supplemental Indenture, the Third Supplemental Indenture and the Fourth Supplemental Indenture, and supplemented by the Second
Supplemental Indenture and as supplemented and modified by this Fifth Supplemental Indenture and any and all supplemental indentures
hereafter entered into between the Company and the Trustee in accordance with the provisions of the Original Indenture, as supplemented
and modified, being herein sometimes called the "Indenture"), and in consideration of the sum of One Dollar ($1.00) to the Company duly
paid by the Trustee at or before the ensealing and delivery hereof, and for other good and valuable considerations, the receipt whereof is
hereby acknowledged, the Company hereby covenants to and with the Trustee and its successors in the trusts under the Original Indenture,
as supplemented and modified, as follows:

**ARTICLE 1.**

**Schedule of Mortgaged Property.**

Section 1.01.  In order to further secure the payment of the principal of, premium, if any, and interest on, all Bonds at any time issued
and outstanding under the Indenture, according to their tenor, purport and effect, and further to secure the performance and observance
of all the covenants and conditions in said Bonds and in the Original Indenture, as supplemented and modified, and in this Fifth
Supplemental Indenture contained, for the considerations above expressed, and for and in consideration of the mutual covenants herein
contained and of the purchase and acceptance of the Bonds by holders thereof, the Company has executed and delivered this Fifth
Supplemental Indenture and by these presents does grant, bargain, sell, alien, remise, release, convey, assign, transfer, mortgage,
pledge, set over and confirm unto The Bank of New York, as Trustee under the Indenture, and to its assigns forever, all property, real,
personal or mixed, acquired since the execution and delivery of the Fourth Supplemental Indenture which by the terms of the Original
Indenture, as supplemented and modified, is subject or is intended to be subject to the lien of the Indenture, including, without limiting
the generality of the foregoing, the following described property:

**CLAUSE I**

PART I

AROOSTOOK  COUNTY, MAINE

HOULTON TO ISLAND FALLS LINE

PARCEL I:  A certain parcel of land, being part of Lot Forty-Two (42) in the Town of Oakfield, County of Aroostook and State of
Maine, being more particularly described as follows:

Commencing at the northwest corner of the lot conveyed to Maine Public Service Company by Guy B. Chambers and Eda H.
Chambers and described in Book 551, Page 213 of the Southern Aroostook Registry of Deeds, said point being on the south line of the
property conveyed to Gregory B. Nevers by Lynn M. Nevers by Deed dated January 9 1998 and recorded in Vol. 3097, Page 307 of
said Registry; thence westerly on a course bearing North Sixty-Eight Degrees Six Minutes Eight Seconds West (N68 degrees 06' 08"
W) along the south line of Nevers for a distance of ninety-seven and ninety-eight hundredths (97.98) feet to a 5/8" rebar driven into the
ground at the southwest corner of said Gregory B. Nevers parcel described in Vol. 3097, Page 307 of said Registry; thence northerly on
the west line of Nevers on a course bearing North Twenty-One Degrees Fifty-Seven Minutes Thirty-Six Seconds East (N 21 degrees 57'
36" E) for a distance of twenty and no-hundredths (20.00) feet to a point; thence westerly on a course bearing North Sixty-Eight
Degrees Six Minutes Eight Seconds West (N 68 degrees 06' 08" W) for a distance of forty-three and fifty-five hundredths (43.55) feet
to a 5/8" rebar driven into the ground on the west line of Parcel I described in a Deed to Robert A. Stiles dated June 10, 1991 and
Recorded in Vol. 2368, Page 117 of said Registry; thence southerly on said west line on a course bearing South Twenty-Four Degrees
Zero Minutes Fifty-One Seconds West (S 24 degrees 00' 51" W) for a distance of one hundred sixteen and eight-six hundredths
(116.86) feet to a 5/8" rebar driven into the ground; thence easterly on a course bearing North Eighty-Two Degrees Fifty-Four Minutes
Forth- Five Seconds East (N 82 degrees 54' 45" E) for a distance of thirty-four and sixty-three hundredths (34.63) feet to a 5/8" rebar
driven into the ground at the west line of the property conveyed  to Marion R. Dickinson and Joseph H. Dickinson by Deed Dated
November 16, 1996 and recorded in Vol. 2999, Page 208 of said Registry; thence northerly on said north line on a course bearing
North Twenty-One Degrees Fifty-Three Minutes Fifty-Two Seconds East (N 21 degrees 53' 52" E) for a distance of thirty and no-hundredths (30.00) feet to a 5/8" rebar driven into the ground at the northwest corner of the Dickinson property; thence easterly
on the
north line of said Dickinson on a course bearing South Sixty-Eight Degrees Six Minutes Eight Seconds East (S 68 degrees 06' 08" E)
for a distance of one hundred fifteen and no-hundredths (115.00) feet to the southwest corner of the lot conveyed to Maine Public
Service Company and described in Vol. 551, Page 213 of said Registry; thence northerly on the west line of Maine Public Service
Company on a course bearing North Twenty-Two Degrees Thirty Minutes Twenty-Four Seconds East (N 22 degrees 30' 24" E) for a
distance of fifty and no-hundredth (50.00) feet to the point of beginning.  The herein described parcel contains twenty-one hundredths
 .21) acres.

The herein Parcel I being part, and part only, of Parcel I of the same premises conveyed by Jerolyn J. Boutilier, f/k/a Jerolyn J. Stiles, to
Robert A. Stiles by Deed recorded in Vol. 2368, Page 117 of the Southern Aroostook Registry of Deeds.

PARCEL II:  A certain parcel of land, being part of Lot Forty-Two (42) in the Town of Oakfield, County of Aroostook and State of
Maine, being more particularly described as follows:

Commencing at a 5/8" rebar found on the southerly right of way line of the Webb Road at the northeast corner of the parcel conveyed
to Katahdin Development Corporation by John R. Philbert and Sally S Philbert and described in Vol. 2216, Page 256 of the Southern
Aroostook Registry of Deeds; thence westerly on the southerly right of way line of the Webb Road on a course bearing North Seventy
Degrees Fifty Minutes Thirty-Seven Seconds West (N 70 degrees 50' 37" W) for a distance of eighty and no-hundredths (80.00) feet to
a 5/8" rebar driven into the ground; thence southerly on a course bearing South Twenty-Four Degrees Two Minutes Forty-Six Seconds
West (S 24 degrees 02' 46" W) for a distance of four hundred thirty-eight and sixty-seven hundredths (438.67) feet to a 5/8" rebar
driven into the ground; thence easterly on a course bearing South Sixty-Seven Degrees Fifty- Two Minutes Fifty-Two Seconds East (S
67 degrees 52' 52" E) for a distance of eighty and no-hundredths (80.00) feet to a 5/8" rebar found at the northwest corner of the parcel
conveyed by Robert A. Stiles to Daigle Oil Company by Deed dated September 21, 1999 and recorded in Vol. 3323, Page 125 of said
Registry; thence northerly on a course bearing North Twenty-Four Degrees Zero Minutes Fifty- One Seconds East (N 24 degrees 00'
51" E) for a distance of four hundred twenty-two and eighty-hundredths (422.80) feet to a 5/8" rebar on the southerly right of way line
of the Webb Road at the point of beginning.  The herein described parcel contains eighty-one hundredths (.81) acres.

The herein Parcel II being the same premises conveyed by Katahdin Development Corporation to Robert A. Stiles by Warranty Deed
dated December 26, 1999 and recorded in Vol. 3356, Page 194 of said Registry.

Recorded in the Southern District of Aroostook Registry of Deeds in Volume 3375, pages 020-023 on March 24, 2000.

PARCEL III:  A certain parcel of land, being part of Lot Forty-Two (42) in the Town of Oakfield, County of Aroostook and State of
Maine, being more  particularly described as follows:

Commencing at a 5/8" rebar driven into the ground on the westerly right of way line of the River Road, so-called, at the northeast
corner of the lot conveyed to Maine Public Service Company by Guy B. Chambers and Edna H Chambers and described in Book 551,
Page 213 of the Southern Aroostook Registry of deeds; said point also being the southeast corner of the property conveyed to Gregory
B. Nevers by Lynn M. Nevers by deed dated January 9, 1998 and recorded in Book 3097, Page 307 of the Southern Aroostook
Registry of Deeds; thence westerly on a course bearing North Sixty-Eight Degrees Six Minutes Eight Seconds West (N 68 degrees 06'
08" W) along the south line of Nevers for a distance of one hundred forty-seven and ninety-eight hundredths (147.98) feet to a 5/8"
rebar driven into the ground at the southwest corner of said Gregory B. Nevers parcel described in Book 3097, Page 307; thence
northerly on the west line of Nevers on a course bearing North Twenty- One Degrees Fifty-Seven Minutes Thirty-Six Seconds East (N
21 degrees 57' 36" E) for a distance of twenty and zero-hundredths (20.00) feet to a point; thence easterly on a course bearing South
Sixty-Eight Degrees Six Minutes Eight Seconds East (S 68 degrees 06' 08" E) for a distance of one hundred forth-seven and ninety-six
hundredths (147.96) feet to a 5/8" rebar driven into the ground on the westerly right of way line of the River Road, so-called; thence
southerly on the westerly right of way line of the River Road on a course bearing South Twenty-One Degrees Fifty-Three Minutes
Fifty-Two Seconds West ( S21 degrees 53' 52" W) for a distance of twenty and zero-hundredths (20.00) feet to a 5/8" rebar driven into
the ground as  the point of beginning.

The herein described parcel contains .07 acres.

Recorded in the Southern Aroostook Registry of Deeds in Volume 3412,   Page 278 on July 7, 2000.

PARCEL IV:  A certain parcel of land, being part of Lot Forty-Two (42) in the Town of Oakfield, County of Aroostook and State of
Maine, being more  particularly described as follows:

Commencing at an axle found driven into the ground on the westerly right of way line of the River Road, so-called, at the southeast
corner of the lot conveyed to Maine Public Company by Guy B. Chambers and Eda H. Chambers and described in Book 551, Page 213
of the Southern Aroostook Registry of Deeds; said point also being the northeast corner of the property conveyed to Marion R. and
Joseph H. Dickinson by deed dated November 12, 1996 and recorded in Book 2999, Page 208 of the Southern Aroostook Registry of
Deeds; thence westerly on the north line of said Dickinson on a course bearing North Sixty-Eight Degrees Six Minutes Eight Seconds
West (N 68 degrees 06' 08" W) for a distance of one hundred sixty-five and zero-hundredths (165.00) feet to a 5/8" rebar driven into
the ground at the northwest corner of Dickinson; thence southerly on the west line of Dickinson on a course bearing South Twenty-One
Degrees Fifty-Three Minutes Fifty-Two Seconds West (S 21 degrees 53' 52" W) for a distance of thirty and zero-hundredths (30.00)
feet to a 5/8" rebar driven into the ground; thence easterly on a course bearing South Sixty-Eight Degrees Six Minutes Eight Seconds
East (S 68 degrees 06' 08" E) for a distance of one hundred sixty-five and zero-hundredths (165.00) feet to a 5/8" rebar driven into the
ground on the westerly right of way line of the River Road, so-called; thence northerly on the westerly right of way line of the River
Road on a course bearing North Twenty-One Degrees Fifty-Three Minutes and Two Seconds East (N 21 degrees 53' 52" E) for a
distance of thirty and zero-hundredths (30.00) feet to the point of beginning.

The herein described parcel contains .11 acres.

Recorded in the Southern Aroostook Registry of Deeds Volume 3407, Page 193 on June 26, 2000.

WESTFIELD SUBSTATION LAND

A certain piece or parcel of land located on the south side of the Mars Hill Road, so-called, in the  Town of Westfield, County of
Aroostook, State of Maine,  approximately three thousand  (3,000) feet Easterly of the intersection of Easton Viner Road, so called, and
said Mars Hill Road, being a part of original Lot Six (6), Range One (1) and more particularly described as follows:

Beginning at a 5/8" rebar set at the intersection of the Southerly sideline of the Mars Hill Road and the westerly limit of the Maine
Public Service Company pole line right of way as conveyed to said company by Francis A. Tweedie and recorded in the Southern
District of the Aroostook Registry of Deeds in Book 927, Page 92.

Said point of beginning also being three thousand seventy-three (3,073) feet Easterly from the centerline of traveled way of the Easton
Viner Road, as measured along said Southerly sideline; thence southerly along said easterly limit of Maine Public Service Company
right of way, South Seventeen Degrees Thirty-One Minutes Twelve Seconds West (S 17 degrees 31' 12" W) a distance of three
hundred and no-hundredths (300.00) feet to a rebar set; thence Westerly and parallel to the Southerly limit of the Mars Hill Road, North
Seventy-Two Degrees Four Minutes Twenty-Six Seconds West (N 72 degrees 04' 26" W) a distance of five hundred and no-hundredths
(500.00) feet to a rebar set; thence Northerly and parallel to said Westerly limit of Maine Public Service Company right of way, North
Seventeen Degrees Thirty-One Minutes Twelve Seconds East (N 17 degrees 31' 12" E) a distance of three hundred and no-hundredths
(300.00) feet to a rebar set on the said Southerly sideline of Mars Hill Road; thence Easterly along said Southerly sideline of Mars Hill
Road, South Seventy-Two Degrees  Four Minutes Twenty-Six Seconds East (S 72 degrees 04' 26" E) a distance of five hundred and
no- hundredths (500.00) feet to the point of beginning.  The above-described piece or parcel of land contains three and forty-four
hundredths (3.44) acres of land more or less.

Recorded in Southern District of Aroostook Registry of Deeds in Volume 3398, pages 141-142  on June 2, 2000.

**PART II**

**TRANSMISSION LINES**

**ADDITIONAL RIGHT-OF-WAY, THE HOULTON TO ISLAND FALLS LINE, SO CALLED**

A 44,000 volt transmission line in Aroostook County, Maine owned and operated by Maine Public Service Company from
Houlton to Island Falls, a distance of approximately 27.85 miles, said Maine Public Service Company line being constructed for the
most part on rights-of-way conveyed to Maine Public Service Company by the following deeds:

|                                                                   |          |      | Recorded |             
|------------------------------------------------------------------ | -------- | ---- | -------- | ------------
|Grantor                                                            | Date     | Vol. | Page     | Registry at:
|Harold & Theodore Sherman                                          | 8/08/97  | 3021 | 044      | Houlton     
|Edith A. Dwyer                                                     | 8/08/97  | 3021 | 040      | Houlton     
|Norman Grant III                                                   | 9/15/97  | 3060 | 152      | Houlton     
|Dale Hosford                                                       | 10/28/97 | 3075 | 330      | Houlton     
|Edith A. Dwyer                                                     | 12/18/97 | 3090 | 319      | Houlton     
|International Paper                                                | 03/06/98 | 3108 | 051      | Houlton     
|Dale Hosford                                                       | 07/09/98 | 3160 | 014      | Houlton     
|Craig O. & Debra J. McLaughlin                                     | 07/30/98 | 3156 | 095      | Houlton     
|Walter Sanders III &                                              
|Rebecca Ann Sanders                                                | 07/30/98 | 3156 | 124      | Houlton     
|Leah and Albert Hersey                                             | 07/30/98 | 3156 | 093      | Houlton     
|Judy M. Cameron                                                    | 07/30/98 | 3167 | 292      | Houlton     
|Glenn C. & Betty McGraw                                            | 08/03/98 | 3168 | 320      | Houlton     
|Emery & Norma Nightingale                                          | 10/05/98 | 3192 | 111      | Houlton     
|Inhabitants of Dyer Brook                                         
|Dyer Brook Selectmen                                               | 10/05/98 | 3192 | 109      | Houlton     
|Charles E. Burpee                                                  | 05/07/99 | 3266 | 321      | Houlton     
|Joseph A. Farrar & Son, Inc.                                       | 12/09/98 | 3216 | 138      | Houlton     
|Merle S. & Evelyn F. Burpee                                        | 04/22/99 | 3262 | 108      | Houlton     
|Merle S. & Evelyn F. Burpee                                        | 04/22/99 | 3262 | 114      | Houlton     
|Carlene Burpee                                                     | 04/30/99 | 3264 | 263      | Houlton     
|David W. & Leretta G. McLaughlin                                   | 04/26/99 | 3262 | 315      | Houlton     
|Elery R. Grant                                                     | 04/29/99 | 3264 | 217      | Houlton     
|Alfred R. & Cleo B. Skolfield                                      | 03/27/00 | 3375 | 026      | Houlton     
|E. Lawson & Janice E. Helsor                                       | 12/14/99 | 3351 | 179      | Houlton     
|William S. Woods & Herbert E. Rhoda                                | 12/16/99 | 3351 | 320      | Houlton     
|Lysten M. & Judith A. Ivey                                         | 11/30/99 | 3347 | 086      | Houlton     
|Ralph A. & Joan M. Ivey                                            | 12/03/99 | 3348 | 128      | Houlton     
|Thomas J. & Pamela J. Anderson                                     | 01/11/00 | 3359 | 168      | Houlton     
|Thomas J. Anderson, Trustee for                                    | 01/11/00 | 3359 | 170      | Houlton     
|Thomas J. Anderson, D.M.D., P.A., Employee Retirement Benefit Plan
|Walter M. & Amy Metherell                                          | 01/03/00 | 3357 | 028      | Houlton     
|Rena B. Barton                                                     | 01/03/00 | 3357 | 108      | Houlton     
|Roderick G. & Elizabeth M. Lindsay                                 | 01/06/00 | 3358 | 143      | Houlton     
|Bernard & Iona Nadeau                                              | 01/05/00 | 3358 | 083      | Houlton     
|Robert W. Nadeau                                                   | 01/14/00 | 3360 | 260      | Houlton     
|Jack Q. & Donna N. Margison                                        | 01/10/00 | 3358 | 305      | Houlton     
|Virginia Ford                                                      | 01/06/00 | 3358 | 147      | Houlton     
|Ernest Buchalla                                                    | 01/10/00 | 3359 | 045      | Houlton     
|Joey & Trudy Tarr                                                  | 01/07/00 | 3358 | 174      | Houlton     
|Joey & Trudy Tarr                                                  | 01/07/00 | 3358 | 170      | Houlton     
|Gerard J. Berthelette                                              | 01/07/00 | 3358 | 259      | Houlton     
|Paul M. Jr. & Melanie Shields                                      | 01/25/00 | 3362 | 105      | Houlton     
|Merwin H. & Shirley Crandall                                       | 01/24/00 | 3362 | 090      | Houlton     
|Robert Kane                                                        | 01/27/00 | 3363 | 031      | Houlton     
|Lawrence & Mary Winchell                                           | 01/20/00 | 3361 | 197      | Houlton     
|Linwood B. & Jean A. Jones                                         | 01/19/00 | 3361 | 122      | Houlton     
|David W. Barrows                                                   | 01/25/00 | 3362 | 164      | Houlton     
|Joseph H. & Judith A. Anderson                                     | 01/31/00 | 3363 | 202      | Houlton     
|Frank J. & Mary L. Stiles                                          | 02/07/00 | 3365 | 039      | Houlton     
|Judith Small                                                       | 02/03/00 | 3364 | 184      | Houlton     
|Donald P. & Helen I. Woods                                         | 02/10/00 | 3365 | 283      | Houlton     
|David T. & Aimee J. Goff                                           | 02/23/00 | 3368 | 144      | Houlton     
|George N. & Gina Clark                                             | 02/22/00 | 3367 | 286      | Houlton     
|Forest E. & Bobbie Jo Cummings                                     | 02/17/00 | 3367 | 121      | Houlton     
|Bruce & Marla Crandall                                             | 02/25/00 | 3368 | 262      | Houlton     
|David & Vallie H. Condon                                           | 03/08/00 | 3371 | 115      | Houlton     
|David & Vallie H. Condon                                           | 03/08/00 | 3371 | 111      | Houlton     
|David & Vallie H. Condon                                           | 03/08/00 | 3371 | 107      | Houlton     
|David & Vallie H. Condon                                           | 03/08/00 | 3371 | 103      | Houlton     
|David & Vallie H. Condon                                           | 03/08/00 | 3371 | 119      | Houlton     
|Vallie H. Condon                                                   | 03/08/00 | 3371 | 097      | Houlton     
|Virginia Ford                                                      | 03/03/00 | 3370 | 041      | Houlton     
|John R. & Stephanie B. Woods                                       | 03/07/00 | 3370 | 328      | Houlton     
|John A. Graham                                                     | 04/07/00 | 3378 | 118      | Houlton     
|Mary B. Stover                                                     | 04/14/00 | 3381 | 138      | Houlton     
|Joan H. Williams                                                   | 05/02/00 | 3386 | 060      | Houlton     
|Calvin III & Julie Doughty                                         | 05/01/00 | 3385 | 166      | Houlton     
|Clement & Linda McGillicuddy                                       | 05/08/00 | 3387 | 322      | Houlton     
|Paul M. Sr. & Betty I. Shields                                     | 05/18/00 | 3392 | 118      | Houlton     
|Ray A., Annie E. & Brian R. Delong                                 | 05/16/00 | 3391 | 055      | Houlton     
|Brent A. & Karen D. Watson                                         | 05/24/00 | 3395 | 210      | Houlton     
|Shirley Spellman                                                   | 06/01/00 | 3398 | 074      | Houlton     

The foregoing rights-of-way are conveyed subject to reservations, conditions, restrictions, limitations and exceptions referred to or
mentioned in the deeds above listed.

CLAUSE II

All and singular the lands, real estate, chattels real, interests in land, leaseholds, ways, rights-of-way, easements, servitudes,
permits and licenses, lands under water, riparian rights, franchises, privileges, rights and interests, electric generating plants, power
houses, dams, stations, electric transmission and distribution systems, substations, conduits, poles, wires, cables, office buildings,
warehouses, garages, machine shops, and other buildings and structures, implements, meters, tools, and other apparatuses,
appurtenances and facilities materials and supplies and all other property of any nature appertaining to any of the plants, systems,
business or operations of the Company, whether or not affixed to the realty, used in the operation of any of the premises or plants or
systems or otherwise, which are now owned, or which may hereafter be owned or acquired by the Company, other than excepted
property as hereinafter defined.

**CLAUSE III**

All corporate Federal, State, municipal and other permits, consents, licenses, bridge licenses, bridge rights, river permits,
franchises, grants, privileges and immunities of every kind and description, now belonging to or which may hereafter be owned, held,
possessed or enjoyed by the Company (other than excepted property as hereinafter defined) and all renewals, extensions, enlargements
and modifications of any of them.

**CLAUSE IV**

Also all other property, real, personal or mixed, tangible or intangible (other than excepted property as hereinafter defined) of
every kind, character and description and wheresoever situated, whether or not useful in the generation, manufacture, production,
transportation, distribution, sale or supplying electricity now owned or which may hereafter be acquired by the Company, it being the
intention hereof that all property, rights and franchises acquired by the Company after the date of the execution and delivery hereof
(other than excepted property as hereinafter defined) shall be as fully embraced within and subjected to the lien of the Indenture as if
such property were now owned by the Company and were specifically described herein and conveyed hereby.

**CLAUSE V**

Together with (other than excepted property as hereinafter defined) all and singular the plants, buildings, improvements,
additions, tenements, hereditaments, easements, rights, privileges, licenses and franchises and all other appurtenances whatsoever
belonging or in any wise appertaining to any of the property hereby mortgaged or pledged, or intended so to be, or any part thereof, and
the reversion and reversions, remainder and remainders, and the rents, revenues, issues, earnings, income, products and profits thereof,
and every part and parcel thereof, and all the estate, rights, title, interest, property, claim and demand of every nature whatsoever of the
Company at law, in equity or otherwise howsoever, in, of and to such property and every part and parcel thereof.

**CLAUSE VI**

Also any and all property, real, personal or mixed, including excepted property, that may, from time to time hereafter, by
delivery or by writing of any kind, for the purposes of the Indenture be in any wise subjected to the lien of the Indenture or be expressly
conveyed, mortgaged, assigned, transferred, deposited and/or pledged by the Company, or by anyone in its behalf or with its consent, to
and with the Trustee, which is hereby authorized to receive the same at any and all times as and for additional security and also, when
and as provided in the Indenture, to the extent permitted by law.  Such conveyance, mortgage, assignment, transfer, deposit and/or
pledge or other creation of lien by the Company, or by anyone in its behalf, or with its consent, of or upon any property as and for
additional security may be made subject to any reservations, limitations, conditions and provisions which shall be set forth in an
instrument or agreement in writing executed by the Company or the person or corporation conveying, assigning, mortgaging,
transferring, depositing and/or pledging the same and/or by the Trustee, respecting the use, management and disposition of the property
so conveyed, assigned, mortgaged, transferred, deposited and/or pledged, or the proceeds thereof.

**CLAUSE VII**

There is however, expressly excepted and excluded from the lien and operation of the Indenture the following described
property of the Company, herein sometimes referred to as "excepted property":

(a)  Any and all property expressly excepted and excluded from the Original Indenture and from the lien and operation thereof
by Paragraph A of Clause XI of the Granting Clauses thereof and all property of the character expressly excepted or intended
to be excepted and excluded by Paragraphs B through I of said Clause XI; and

(b)  All property which prior to the execution and delivery of this Fifth Supplemental Indenture has been released by the
Trustee or otherwise disposed of by the Company free from the lien of the Indenture, in accordance with the provisions
thereof.

The Company may, however, pursuant to the provisions of Granting Clause VI above, subject to the lien and operation of the
Indenture all or any part of the excepted property.

**TO HAVE AND TO HOLD** the trust estate and all and singular the lands, properties, estates, rights, franchises, privileges
and appurtenances hereby mortgaged, conveyed, pledged or assigned, or intended so to be, together with all the appurtenances thereto
appertaining and the rents, issues and profits thereof, unto the Trustee and its successors in trust and to its assigns, forever:

**SUBJECT, HOWEVER,** to the exceptions, reservations, restrictions, conditions, limitations, covenants and matters recited in
Schedule A to the Original Indenture or otherwise recited in the Original Indenture, as modified and supplemented, and contained in all
deeds and other instruments whereunder the Company has acquired any of the property now owned by it, and to permitted
encumbrances as defined in Subsection B of Section 1.11 of the Original Indenture, and, with respect to any property which the
Company may hereafter acquire, to all terms, conditions, agreements, covenants, exceptions and reservations expressed or provided in
the deeds or other instruments, respectively, under and by virtue of which the Company shall hereafter acquire the same and to any liens
thereon existing, and to any liens for unpaid portions of the purchase money placed thereon, at the time of acquisition;

**BUT IN TRUST, NEVERTHELESS,** for the equal and proportionate use, benefit, security and protection of those who from
time to time shall hold the Bonds authenticated and delivered under the Indenture and duly issued by the Company, without any
discrimination, preference or priority of any one Bond over any other by reason of priority in the time of issue, sale or negotiation
thereof or otherwise, except as provided in Section 12.28 of the Original Indenture, so that, subject to said Section 12.28, each and all
of said Bonds shall have the same right, lien and privilege under the Indenture, and shall be equally secured hereby (except in so far as
any sinking fund, replacement fund or other fund established in accordance with the provisions of the Indenture may afford additional
security for the Bonds of any specific series) and shall have the same proportionate interest and share in the trust estate, with the same
effect as if all of the Bonds had been issued, sold and negotiated simultaneously on the date of the delivery hereof;

**AND UPON THE TRUSTS, USES AND PURPOSES** and subject to the covenants, agreements and conditions in the
Indenture set forth and declared.

**ARTICLE 2**

**Bonds of the 2025 Series and Certain**

**Provisions Relating Thereto**

**Section 2.01.  Terms of the Bonds of the 2025 Series.**  There shall be a series of Bonds, known as and entitled "Second
Mortgage and Collateral Trust Bonds, Series Due 2025" (herein referred to as the "Bonds of the 2025 Series"), and the form thereof
shall be substantially as hereinafter set forth in Section 2.02.

The Bonds of the 2025 Series shall be issued to The Bank of New York, as Agent, to secure the obligations of the Company
under a Letter of Credit and Reimbursement Agreement, dated as of October 1, 2000, among the Company, The Bank of New York
("BNY") and Fleet National Bank ("Fleet") and The Bank of New York, as Agent (in such capacity, "BNY Agent"), and as Issuing
Bank (in such capacity, "BNY Issuing Bank") (the "Reimbursement Agreement"), pursuant to which BNY Issuing Bank has issued its
irrevocable, transferrable, direct-pay letter of credit (the "Letter of Credit") to support certain Maine Public Utility Financing Bank
Public Utility Refunding Revenue Bonds, Series 2025 (Maine Public Service Company Project) (the "Revenue Bonds").

The aggregate principal amount of the Bonds of the 2025 Series which may be authenticated and delivered and outstanding
under this Fifth Supplemental Indenture shall be limited to $4,525,000 except for duplicate Bonds, authenticated and delivered pursuant
to Section 2.12 of the Original Indenture.  The definitive Bonds of the 2025 Series shall be issued only as registered Bonds without
coupons of the denomination of $1.00 and of any multiple thereof and shall be registered in the name of the BNY Agent.

The date of authentication on the original issuance of the Bonds of the 2025 Series shall be the date of commencement of the
first interest period for such Bonds.  All Bonds of the 2025 Series shall mature October 1, 2025, and shall bear interest at the Default
Rate as set forth in, and in accordance with, the Reimbursement Agreement until the payment of the principal thereof.  Both principal of
and interest on the Bonds of the 2025 Series will be paid in any coin or currency of the United States of America which at the time of
payment is legal tender for the payment of public and private debts, at the principal office in The City of New York, New York, of the
Trustee or, at the office of its successor as Trustee.  Interest on the Bonds of the 2025 Series shall, unless otherwise directed by the
respective registered holders thereof, be paid by checks payable to the order of the respective holders entitled thereto, and mailed by the
Trustee by first class mail, postage prepaid, to such holders at their respective registered addresses as shown on the Bond register for
the Bonds of the 2025 Series.

The definitive Bonds of the 2025 Series may be issued in the form of Bonds engraved, printed or lithographed on steel
engraved borders and the signature of the President, or a Vice President and of the Secretary or an Assistant Secretary of the Company
may be facsimile.  Bonds of the 2025 Series may also be issued as temporary printed, lithographed or typewritten Bonds, and, so long
as the registered holder of such Bonds does not request their exchange for Bonds in definitive form, the Company shall not be deemed
to have unreasonably delayed the preparation, execution and delivery of definitive Bonds as called for by Section 2.08 of the Original
Indenture.

Notwithstanding any provision in the Original Indenture to the contrary, the person in whose name any Bond of the 2025
Series is registered at the close of business on any record date (as hereinbelow defined) with respect to any interest payment date shall
be entitled to receive the interest payable on such interest payment date notwithstanding the cancellation of such Bond of the 2025
Series upon any transfer or exchange thereof (including any exchange effected as an incident to a partial redemption thereof)
subsequent to the record date and prior to such interest payment date, except that, if and to the extent that the Company shall default in
the payment of the interest due on such interest payment date, then the registered holders of Bonds of the 2025 Series on such record
date shall have no further right to or claim in respect of such defaulted interest as such registered holders on such record date, and the
persons entitled to receive payment of any defaulted interest thereafter payable or paid on any Bonds of the 2025 Series shall be the
registered holders of such Bonds of the 2025 Series on the record date for payment of such defaulted interest.  The term "record date"
as used in this Section 2.01, and in the form of the Bonds of the 2025 Series, with respect to any interest payment date applicable to the
Bonds of the 2025 Series, shall mean the May 15 next preceding a June 1 interest payment date or the November 15 next preceding a
December 1 interest payment date, as the case may be, or a special record date established for defaulted interest as hereinafter provided.

In the case of failure by the Company to pay any interest when due, the claim for such interest shall be deemed to have been
transferred by transfer of any Bond of the 2025 Series registered on the Bond register, and the Company by not less than 10 days
written notice to bondholders may fix a subsequent record date, not more than 15 days prior to the date fixed for the payment of such
interest, for determination of holders entitled to payment of such interest.  Such provision for establishment of a subsequent record date,
however, shall in no way affect the rights of bondholders or of the Trustee consequent on any default.

Except as provided in this Section 2.01, every Bond of the 2025 Series shall be dated as provided in Section 2.05 of the
Original Indenture except that upon original issuance of the Bonds of the 2025 Series, the Bonds of the 2025 Series shall be dated the
date of authentication.  Notwithstanding any provision in the Original Indenture to the contrary, so long as there is no existing default in
the payment of interest on the Bonds of the 2025 Series, all Bonds of the 2025 Series authenticated by the Trustee between the record
date for any interest payment date and such interest payment date shall be dated such interest payment date and shall bear interest from
such interest payment date.

As permitted by the provisions of Section 2.10 of the Original Indenture and upon payment at the option of the Company of a
sum sufficient to reimburse it for any stamp tax or other governmental charge as provided in Section 2.11 of the Original Indenture,
Bonds of the 2025 Series may be exchanged for other Bonds of the 2025 Series of different authorized denominations of like aggregate
principal amount.  Notwithstanding the provisions of Section 2.11 or the last sentence of the first paragraph of Section 2.12 of the
Original Indenture, no further sum, other than the sum sufficient to reimburse the Company for any stamp taxes or other governmental
charges, shall be required to be paid upon any exchange or replacement of Bonds of the 2025 Series or upon any transfer thereof.

The Bonds of the 2025 Series shall be nontransferable prior to maturity except upon the prior written consent of the Company
or to effect transfer to any successor or assignee of BNY Agent if and to the extent that BNY Agent shall have assigned its rights under
the Reimbursement Agreement, any such transfer to be made at the principal corporate trust office of the Trustee in The City of New
York, New York, upon surrender and cancellation of such Bonds of the 2025 Series, accompanied by a written instrument of transfer in
a form approved by the Company, duly executed by the registered owner of such Bonds of the 2025 Series or by his duly authorized
attorney, and thereupon a new Bond of the 2025 Series, for a like principal amount, will be issued to the successor or assignee of BNY
Agent, in exchange therefor.

The Trustee hereunder shall, by virtue of its office as such Trustee, be the registrar and transfer agent of the Company for the
purpose of registering and transferring Bonds of the 2025 Series.  Notwithstanding any provision in the Original Indenture to the
contrary, neither the Company nor the Trustee shall be required to make transfers or exchanges of Bonds of the 2025 Series for a period
of ten days next preceding any designation of the Bonds of the 2025 Series to be redeemed and neither the Company nor the Trustee
shall be required to make transfers or exchanges of any bonds designated in whole for redemption or that part of any bond designated in
part for redemption.

**Section 2.02.  Form of Bonds of the 2025 Series.**  The text of the Bonds of the 2025 Series and the Trustee's authentication
certificate to be executed on the Bonds of said series, shall be in substantially the following forms, respectively.

[FORM OF FACE OF BOND OF THE 2025 SERIES]

No. [      ]	$

MAINE PUBLIC SERVICE COMPANY

Second Mortgage and Collateral Trust Bond,

Series due 2025

Due October 1, 2025

MAINE PUBLIC SERVICE COMPANY, a Maine corporation (hereinafter sometimes called the "Company"), for value
received, hereby promises to pay to ________________ or registered assigns, on October 1, 2025, the sum of ________________
Dollars (the "Stated Principal Amount") or, if less, the Effective Principal Amount (as hereinafter defined) on such date, and to pay to
the registered owner hereof interest on the Stated Principal Amount or, if less, on the Effective Principal Amount from the date hereof
at the applicable rate of interest as set forth in, and in accordance with, the Reimbursement Agreement (as hereinafter defined) until the
payment of the principal thereof.

The Bonds of the 2025 Series, including this bond, are issued to secure the obligations of the Company under a Letter of
Credit and Reimbursement Agreement, dated as of October 1, 2000 (the "Reimbursement Agreement") among the Company, The Bank
of New York ("BNY") and Fleet National Bank ("Fleet") and The Bank of New York, as Agent (in such capacity, "BNY Agent") and
as Issuing Bank (in such capacity, "BNY Issuing Bank"), pursuant to which BNY Issuing Bank has issued its irrevocable, transferrable,
direct-pay letter of credit (the "Letter of Credit") to support certain Maine Public Utility Financing Bank Public Utility Refunding
Revenue Bonds, Series 2025 (Maine Public Service Company Project) (the "Revenue Bonds"). The obligations and liabilities
(including, but not limited to, obligations with respect to any fees, disbursements or other expenses and indemnification) of the
Company due and to become due under or otherwise in respect of the Reimbursement Agreement, whether direct or indirect, joint or
several, absolute or contingent, liquidated or unliquidated, now or hereafter existing, extended or renewed, deferred, refunded,
refinanced or restructured, and including all indebtedness of the Company under any instrument now or hereafter evidencing any of the
foregoing, are all hereinafter called the "Reimbursement Agreement Obligations".  The "Effective Principal Amount" of this bond as of
the time  of any determination is an amount equal to the Reimbursement Agreement Obligations outstanding and unpaid at such time
multiplied by a fraction, the numerator of which is 4.525 and the denominator of which is 9.525, such product in turn to be multiplied
by a fraction, the numerator of which is the Stated Principal Amount and the denominator of which is $4,525,000.

The obligation of the Company to make any payment of interest on the Bonds of the 2025 Series, when such interest shall be
due and payable (including, but not limited to, October 1, 2025), shall be deemed to be, and shall be, satisfied and discharged if the
Company shall have paid all interest under the Reimbursement Agreement then due and payable.  The obligation of the Company to
make payments with respect to the principal of the Bonds of the 2025 Series at any time shall be deemed to be, and shall be, satisfied
and discharged if, at any time that such payment of principal shall be due (including, but not limited to, October 1, 2025), the Company
shall have paid all amounts then due pursuant to Sections 2.03 and 2.04 of the Reimbursement Agreement or otherwise due with respect
to Reimbursement Agreement Obligations.

The principal of and interest on this bond will be paid in any coin or currency of the United States of America which at the
time of payment is legal tender for the payment of public and private debts at the principal office in The City of New York, New York,
of the Trustee under the Indenture mentioned on the reverse hereof except that in case of the redemption as a whole at any time of the
bonds of this series then outstanding, the Company may designate in the redemption notice other offices or agencies at which, at the
option of the registered holder, this bond may be surrendered for redemption and payment.  Interest on this bond will be payable at the
Corporate Trust Office in The City of New York, New York, of the Trustee provided, however, that interest on this bond shall, unless
otherwise directed by the registered holder hereof, be paid by check payable to the order of the registered holder entitled thereto and
mailed by the Trustee by first class mail, postage prepaid, to such holder at his address as shown on the bond register for the bonds in
this series.

This bond shall not become or be valid or obligatory for any purpose until the authentication certificate hereon shall have been
signed by the Trustee.

The provisions of this bond are continued on the reverse hereof and such continued provisions shall for all purposes have the
same effect as though fully set forth at this place.

IN WITNESS WHEREOF, MAINE PUBLIC SERVICE COMPANY has caused these presents to be executed in its name
and behalf by its President or one of its Vice Presidents and its corporate seal or a facsimile thereof to be affixed hereto and attested by
its Secretary or one of its Assistant Secretaries, all as of __________, 20__.

MAINE PUBLIC SERVICE COMPANY

By:

Vice President

Attest:



Secretary

[FORM OF REVERSE OF BOND OF THE 2025 SERIES]

This bond constitutes the entire series designated as Bonds of the 2025 Series, of an authorized issue of bonds of the
Company, known as Second Mortgage and Collateral Trust Bonds, issued under and equally secured (except in so far as any sinking
fund, replacement fund or other fund established in accordance with the provisions of the Indenture hereinafter mentioned may afford
additional security for the bonds of any specific series) by an Indenture of Second Mortgage and Deed of Trust dated as of October 1,
1985, duly executed and delivered by the Company to The Bank of New York, as successor to J. Henry Schroder Bank and Trust

Company, as Trustee, to which Indenture of Second Mortgage and Deed of Trust as supplemented and modified by indentures
supplemental thereto, including a Fifth Supplemental Indenture dated as of October 1, 2000, duly executed by the Company to said
Trustee and all further indentures supplemental thereto (herein sometimes collectively called the "Indenture").  Reference is hereby
made for a description of the property mortgaged and pledged as security for said bonds, the nature and extent of the security, and the
rights, duties and immunities thereunder of the Trustee, the rights of the holders of said bonds and of the Trustee and of the Company in
respect of such security, and the terms upon which said bonds may be issued thereunder.

This bond shall be subject to redemption as a whole or in part, at any time, at the option of the Company prior to maturity
upon payment of the principal amount hereof in the manner provided for in the Indenture. In the event that the Revenue Bonds
outstanding under the Indenture of Trust, dated as of October 1, 2000, between the Maine Public Utility Financing Bank and State
Street Bank and Trust Company (the "Revenue Bond Indenture") shall become immediately due and payable pursuant to Section
9.01(e) or 9.01(f) of the Revenue Bond Indenture, this bond shall be redeemed by the Company, on the date such Revenue Bonds shall
have become immediately due and payable.  In such event, this bond shall be redeemed by the Company at the Stated Principal Amount
hereof or, if less, the Effective Principal Amount hereof on the date fixed for redemption, plus unpaid interest accrued to the date of
redemption.

If this bond (or any portion thereof (One Dollar or a multiple thereof)) is duly called for redemption and payment duly
provided for as specified in the Indenture, this bond shall cease to be entitled to the lien of the Indenture from and after the date
payment is so provided for and shall cease to bear interest from and after the redemption date.

Except as may be otherwise provided in any agreement entered into pursuant to the provisions of said Fifth Supplemental
Indenture, in the event of the selection for redemption of a portion only of the principal of this bond, payment of the redemption price
will be made only (a) upon presentation of this bond for notation hereon of such payment of the portion of the principal of this bond so
called for redemption, or (b) upon surrender of this bond in exchange for a bond or bonds of authorized denominations of the same
series, for the unredeemed balance of the principal amount of this bond.



The Indenture contains provisions permitting the Company and the Trustee, with the consent of the holders of the not less than
seventy-five percent in principal amount of the bonds (exclusive of bonds disqualified by reason of the Company's interest therein) at
the time outstanding, including, if more than one series of bonds shall be at the time outstanding, not less than sixty percent in principal
amount of each series affected, to effect, by an indenture supplemental to the Indenture, modifications or alterations of the Indenture
and of the rights and obligations of the Company and of the holders of the bonds; provided, however, that no such modification or
alteration shall be made without the written approval or consent of the registered holder hereof which will (a) extend the maturity of this
bond or reduce the rate or extend the time of payment of interest hereon or reduce the amount of the principal hereof, or (b) permit the
creation of any lien, not otherwise permitted, prior to or on a parity with the lien of the Indenture, or (c) reduce the aforesaid percentage
of the principal amount of the bonds, the holders of which are required to approve or consent to such modification or alteration.

The Company and the Trustee and any paying agent may deem and treat the person in whose name this bond shall be
registered upon the bond register for the bonds of this series as the absolute owner of such bond for the purpose of receiving payment of
or on account of the principal of and interest on this bond and for all other purposes, whether or not this bond be overdue; and all such
payments so made to such registered holder or upon his order shall be valid and effectual to satisfy and discharge the liability upon this
bond to the extent of the sum or sums so paid and neither the Company nor the Trustee nor any paying agent shall be affected by any
notice to the contrary.

This bond is nontransferable prior to its maturity except upon the prior written consent of the Company or to effect transfer to
any successor or assignee of BNY Agent if and to the extent that BNY Agent shall have assigned its rights under the Reimbursement
Agreement, any such transfer to be made at the principal corporate trust office of the Trustee in The City of New York, New York,
upon surrender of this bond for cancellation and upon payment, if the Company shall so require, of the stamp taxes and other
governmental charges provided for in said Fifth Supplemental Indenture, accompanied by a written instrument of transfer in a form
approved by the Company, duly executed by the registered owner of this bond or by his duly authorized attorney, and thereupon a new
bond of this series, for a like principal amount, will be issued to the successor or assignee of BNY Agent in exchange therefor, as
provided in the Indenture.

The registered holder of this bond at his option may surrender the same for cancellation at said office of the Trustee and to
receive in exchange therefor the same aggregate principal amount of registered bonds of the same series but of other authorized
denominations upon payment, if the Company shall so require, of the stamp taxes and other governmental charges provided for in said
Fifth Supplemental Indenture and subject to the terms and conditions therein set forth.

Neither the Company nor the Trustee shall be required to make transfers or exchanges of bonds of this series for a period of
ten days next preceding any designation of bonds of said series to be redeemed, and neither the Company nor the Trustee shall be
required to make transfers or exchanges of any bonds designated in whole for redemption or that part of any bond designated in part for
redemption.  Subject to the provisions of said Fifth Supplemental Indenture, if this bond is surrendered for any transfer or exchange
between the record date for any interest payment date and such interest payment date, the new bond will be dated such interest payment
date.

The Indenture provides that in the event of any default in payment of the interest due on any interest payment date, such
interest shall not be payable to the holder of the bond on the original record date but shall be paid to the registered holder of such bond
on the subsequent record date established for payment of such defaulted interest.

If a default as defined in the Indenture shall occur, the principal of this bond may become or be declared due and payable
before maturity in the manner and with the effect provided in the Indenture.  The holders, however, of certain specified percentages of
the bonds at the time outstanding, including in certain cases specific percentages of bonds of particular series, may in these cases, to the
extent and under the conditions provided in the Indenture, waive past defaults thereunder and the consequences of such defaults.

No recourse shall be had for the payment of the principal of or the interest on this bond, or for any claim based hereon, or
otherwise in respect hereof or of the Indenture, against any incorporator, stockholder, director or officer, past, present or future, as such,
of the Company or of any predecessor or successor corporation, either directly or through the Company or such predecessor or
successor corporation, under any constitution or statute or rule of law, or by the enforcement of any assessment or penalty, or otherwise,
all such liability of incorporators, stockholders, directors and officers, as such, being waived and released by the holder and owner
hereof by the acceptance of this bond and as provided in the Indenture.

This bond shall not become or be valid or obligatory for any purpose until the authentication certificate hereon shall have been
manually signed by the Trustee.

[FORM OF TRUSTEE'S AUTHENTICATION CERTIFICATE FOR

BONDS OF THE 2025 SERIES]

This is one of the bonds, of the series designated therein, described in the within mentioned Indenture.

THE BANK OF NEW YORK

As Trustee,

By:

Authorized Officer

**Section 2.03.**  **Discharge of Company's Obligation for Payment.** The obligation of the Company to make any payment
of interest on Bonds of the 2025 Series, when such interest shall be due and payable (including, but not limited to, October 1,
2025), shall be deemed to be, and shall be, satisfied and discharged if the Company shall have paid all interest under the
Reimbursement Agreement then due and payable.  The obligation of the Company to make payments with respect to the principal
of Bonds of the 2025 Series at any time shall be deemed to be, and shall be, satisfied and discharged if, at any time that any such
payment of principal shall be due (including, but not limited to, October 1, 2025), the Company shall have paid BNY Agent all
amounts then due pursuant to Sections 2.03 and 2.04 of the Reimbursement Agreement or otherwise due with respect to the
Reimbursement Agreement Obligations.  The Trustee may conclusively presume that at any particular time, the obligations of the
Company to make payments with respect to the principal of and interest on the Bonds of the 2025 Series shall have been satisfied
and discharged up until such time unless and until the Trustee shall have received a notice as described in Section 12.01(m) of the
Indenture.  Whenever all of the Reimbursement Agreement Obligations shall have been satisfied and the Letter of Credit shall have
been terminated, the aggregate principal amount of all of the Bonds of the 2025 Series shall be surrendered by BNY Agent to the
Trustee for cancellation, and upon such surrender shall be deemed fully paid.

**Section 2.04.**  **Redemption Provisions for the Bonds of the 2025 Series.** The Bonds of the 2025 Series shall be subject
to redemption as a whole or in part, at any time, at the option of the Company prior to maturity upon payment of an amount equal to
the Stated Principal Amount thereof or, if less, the Effective Principal Amount thereof including interest accrued thereon to the
redemption date.

In the event that the Revenue Bonds outstanding under the Indenture of Trust, dated as of October 1, 2000, between the
Maine Public Utility Financing Bank and State Street Bank and Trust Company (the "Revenue Bond Indenture") shall become
immediately due and payable pursuant to Section 9.01(e) or 9.01(f) of the Revenue Bond Indenture, all Bonds of the 2025 Series
then outstanding shall be redeemed by the Company, on the date such Revenue Bonds shall have become immediately due and
payable.  In such event, the Bonds of the 2025 Series shall be redeemed by the Company at the Stated Principal Amount thereof or,
if less, the Effective Principal Amount thereof on the date fixed for redemption, plus unpaid interest accrued to the date of
redemption.

The Trustee may conclusively presume that no redemption of Bonds of the 2025 Series is required pursuant to this Section
2.04 unless and until the Trustee shall have received a written notice from BNY Agent stating that an "Event of Default" under the
Reimbursement Agreement has occurred and is continuing.  Said notice shall also contain a waiver of notice of such redemption by
BNY Agent as holder of all of the Bonds of the 2025 Series then outstanding.

Any redemption pursuant to this Section 2.04 shall be made, together in any case with interest accrued thereon to the
redemption date, upon not less than 30 days' nor more than 90 days' notice given by first class mail, postage prepaid, to the holder
of record at the date of such notice of each Bond of the 2025 Series at his address as shown on the Bond register for Bonds of the
2025 Series.  Such notice shall be sufficiently given if deposited in the United States mail within such period.  Neither the failure to
mail such notice, nor any defect in any notice so mailed to any such holder, shall affect the sufficiency of such notice with respect
to other holders.  No notice of redemption need be given if the holders of all Bonds of the 2025 Series called for redemption waive
notice thereof in writing and such waiver is filed with the Trustee.

**Section 2.05.  Bondholders' List.**  Notwithstanding the provisions of Section 11.02(B) of the Original Indenture, any one
of the holders of the Bonds of the 2025 Series shall be entitled to make application to the Trustee for a Bondholders' list as
provided for in Section 11.02.

**Section 2.06.  Mutilated, Lost or Destroyed Bonds.**  Notwithstanding the provisions of Section 2.12 of the Original
Indenture, for so long as any holder of Bonds of the 2025 Series shall be an institutional holder, an unsecured indemnity provided
by such holder shall be deemed acceptable for purposes of requesting a replacement bond for a mutilated, lost or destroyed Bond of
the 2025 Series.

**Section 2.07.  Duration of Effectiveness of Article Two.**  This Article shall be of force and effect only so long as any
Bonds of the 2025 Series are outstanding.

**ARTICLE 3**

**Modification of the Indenture**

**Section 3.01.**  Section 12.01 of the Indenture is hereby amended by adding a new clause (m) to said Section which reads
as follows:

"(m)  so long as any of the Bonds of the 2025 Series are outstanding, upon receipt by the Trustee of a notice from
the holder of the Bonds of the 2025 Series that an event of default under the Reimbursement Agreement has
occurred and is continuing;"

**Section 3.02.  Duration of Effectiveness of Article Three.**  This Article shall be of force and effect only so long
as any Bonds of the 2025 Series are outstanding.

**ARTICLE 4**

**Authentication and Delivery of Bonds of the 2025 Series**

**Section 4.01.**  Upon the execution and delivery of this Fifth Supplemental Indenture, Bonds of the 2025 Series in
the aggregate amount of Four Million Five Hundred Twenty-five Thousand Dollars ($4,525,000) may forthwith,
or from time to time thereafter, and upon compliance by the Company with the provisions of Article Five of the
Indenture, be executed by the Company and delivered to the Trustee and shall thereupon be authenticated and
delivered by the Trustee to or upon the written order of the Company.  Additional Bonds of the 2025 Series may
be executed, authenticated and delivered from time to time as permitted by the provisions of Article Five of the
Original Indenture.

**ARTICLE 5**

**Section 5.01.**  The Company may enter into an agreement with the holder of any registered Bond without
coupons of any series providing for the payment to such holder of the principal of and the premium, if any, and
interest on such Bond or any part thereof at a place other than the offices or agencies therein specified, and for
the making of notation, if any, as to the principal payments on such Bond by such holder or by an agent of the
Company or of the Trustee.  The Trustee is authorized to approve any such agreement, and shall not be liable for
any act or omission to act on the part of the Company, any such holder or any agent of the Company in
connection with any such agreement.

**Section 5.02.**This Fifth Supplemental Indenture is executed and shall be construed as an indenture supplemental
to the Original Indenture, as amended and supplemented, and shall form a part thereof, and, except as hereby
supplemented, the Original Indenture, as amended and supplemented, is hereby ratified, approved and confirmed.

**Section 5.03.**The recitals contained in this Fifth Supplemental Indenture are made by the Company and not by
the Trustee and all of the provisions contained in the Original Indenture, as amended and supplemented, in
respect of the rights, privileges, immunities, powers and duties of the Trustee shall, except as hereinabove
modified, be applicable in respect hereof as fully and with like effect as if set forth herein in full.

**Section 5.04.**Nothing in this Fifth Supplemental Indenture contained shall be deemed to abrogate, modify or
contravene any provisions of the Original Indenture, as amended and supplemented, required to be included
therein by any of the provisions of Section 310 to 318, inclusive, of the Trust Indenture Act of 1939, it being the
intention hereof that said provisions of the Original Indenture, as amended and supplemented, shall continue in
full force and effect.  Unless otherwise indicated, the terms used in this Fifth Supplemental Indenture are intended
to have the meanings given to such terms in the Original Indenture, as amended and supplemented.

**Section 5.05.**Nothing in this Fifth Supplemental Indenture expressed or implied is intended or shall be
construed to give to any person other than the Company, the Trustee, and the holders of the Bonds issued and to
be issued under the Indenture, any legal or equitable right, remedy or claim under or in respect of the Original
Indenture, as amended and supplemented, or this Fifth Supplemental Indenture, or under any covenant, condition
or provisions therein or herein or in the Bonds contained; and all such covenants, conditions and provisions are
and shall be held to be for the sole and exclusive benefit of the Company, the Trustee and the holders of the
Bonds issued and to be issued under the Indenture.

**Section 5.06.**The titles of Articles and any wording on the cover of this Fifth Supplemental Indenture are
inserted for convenience only.

**Section 5.07.**All the covenants, stipulations, promises and agreements in this Fifth Supplemental Indenture
contained made by or on behalf of the Company or of the Trustee shall inure to and bind their respective
successors and assigns.

**Section 5.08.**Although this Fifth Supplemental Indenture is dated for convenience and for the purpose of
reference as of October 1, 2000, the actual date or dates of execution by the Company and by the Trustee are as
indicated by their respective acknowledgments hereto annexed.

**Section 5.09.**In order to facilitate the recording or filing of this Fifth Supplemental Indenture, the same may be
simultaneously executed in several counterparts, each of which shall be deemed to be an original, and such
counterparts shall together constitute but one and the same instrument.

IN WITNESS WHEREOF, MAINE PUBLIC SERVICE COMPANY has caused this Fifth Supplemental
Indenture to be signed in its corporate name and behalf by its President or one of its Vice Presidents and its
corporate seal to be hereunto affixed and attested by its Secretary, or one of its Assistant Secretaries; and THE
BANK OF NEW YORK in token of its acceptance of the trust hereby created has caused this Fifth Supplemental
Indenture to be signed in its corporate name and behalf by its President or one of its Vice Presidents or one of its
Second Vice Presidents and its corporate seal to be hereunto affixed and attested by its Assistant Secretary, all as
of the day and year first above written.

MAINE PUBLIC SERVICE COMPANY

/s/ Larry E. LaPlante

Name:	Larry E. LaPlante

Title:	Vice President

CORPORATE SEAL

Attest:

/s/ Stephen A. Johnson

Name:	Stephen A. Johnson

Title:	Secretary

Signed, sealed and delivered

by MAINE PUBLIC SERVICE COMPANY

in the presence of:

/s/ Marilyn L. Bouchard

Marilyn L. Bouchard

/s/ Alice E. Shepard

Alice E. Shepard

THE BANK OF NEW YORK

/s/ Julie Salovitch-Miller

Name:	Julie Salovitch-Miller

Title:	Vice President

CORPORATE SEAL

Attest:

/s/ Patrick O'Leary

Name:	Patrick O'Leary

Title:	Assistant Secretary

Signed, sealed and delivered

by THE BANK OF NEW YORK

in the presence of:

/s/ Marie E. Trimboli

Name:	Marie E. Trimboli

Title:	Assistant Treasurer

/s/ Van K. Brown

Name:	Van K. Brown

Title:	Vice President

Exhibit 10(ac)

WHOLESALE POWER SALES AGREEMENT

THIS WHOLESALE POWER SALES AGREEMENT (the "Agreement"), is effective as of the 9th day of
December, 1999 ("Effective Date"), by and between Energy Atlantic, LLC (hereinafter "Atlantic") a Maine
limited liability company, and Engage Energy US, L.P. (hereafter "Engage"), a Delaware limited partnership.
Atlantic and Engage are hereafter sometimes referred to individually as "Party" and collectively as "Parties".

RECITALS

A.	WHEREAS, as of March 1, 2000, the Maine retail electric utility industry will be restructured,
whereby the marketing and sale of electricity will be subject to competitive market forces; and

B.	WHEREAS, Atlantic, being licensed by the Maine Public Utilities Commission as a Competitive
Electricity Provider, is a marketer of energy, capacity, and ancillary services to the retail market in
Maine; and

C. 	WHEREAS, Engage is a supplier of energy products; and

D.	WHEREAS, Engage is also a wholesale marketer of electricity, licensed by the Federal Energy
Regulatory Commission, that purchases and sells energy throughout the United States; and

E.	WHEREAS, Atlantic desires to purchase power from Engage on a wholesale basis for the purpose of
serving Atlantic's retail market.

NOW, THEREFORE, in consideration of the mutual promises and covenants hereinafter contained, and for other
good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the
Parties represent, covenant, and agree as follows:

ARTICLE 1

DEFINITIONS

In addition to terms defined elsewhere in this Agreement, the following definitions

shall apply hereunder.

"Agreement" shall have the meaning ascribed to it in the preamble.

"Ancillary Services" means services which are necessary to support the transmission of electric capacity and energy
from generating resources to loads while maintaining reliable operation of the integrated transmission network in accordance
with the tariffs of applicable transmission

1

providers and requirements, if any, of the Bulk Power Administrators.  Subject to applicable tariffs and rules of the Bulk
Power Administrators, Ancillary Services shall include, without limitation, TMSR (Ten Minute Spinning Reserve);  TMNSR
(Ten Minute Non-Spinning Reserve); TMOR (Thirty Minute Operating Reserve); Regulation and Frequency Response;
ICAP (Installed Capacity or Installed Capability); Scheduling and Dispatch Services, and; Reactive Supply and Voltage
Control.

"Bandwidth" means all deviations of the actual hourly load from the hourly load forecasted by Atlantic within a
range of up to, but no greater than, plus or minus 8% as determined by the relevant Bulk Power Administrator, for the
purpose of allocating any settlement cost, penalties, or revenues pursuant to Sections 4.4 and 7.2.

"Bulk Power Administrator" means any one of two Independent System Administrators that, within their
respective control areas, oversee or administer the electricity market and bulk transmission systems.  The two
Administrators are the Northern Maine Independent System

Administrator (ISA) and the ISO New England, Inc. (ISO).

"Business Day" means any day on which Federal Reserve member banks in New York City are open for business.

"Capacity" means electric capacity delivered by Engage to Atlantic.

"Confirmation Letter" means a written notice substantially in the form set forth on Exhibit "A" specifying the
Customized Terms.

"Contract Quantity" means that quantity of Electric Supply that Engage agrees to deliver, or cause to be
delivered, to Atlantic, and that Atlantic agrees to receive, or cause to be received, from Engage, in a Transaction.

"Credit Risk" means the possibility that any retail customer does not or cannot pay for all or any part of the
Electric Supply consumed by it in accordance with the terms and conditions under which it has purchased such Electric
Supply.

"Customized Terms" means the terms of individual Transactions negotiated specifically for each Transaction,
which terms shall include at a minimum: (i) the identity of Atlantic and Engage, (ii) the Transfer Price, (iii) the Contract
Quantity, (iv) the Schedule, including Period of Delivery, (v) responsibility for control area services, (vi) Delivery Point
and (vii) responsibility and terms for delivery, which may include, without limitation, designation of off-peak and peak
hours, and buy-out provisions.

2



"Delivery Period" means the period of time measured from the date deliveries of Electric Supply are to
commence under a Transaction through the date deliveries are to terminate under a Transaction.

"Delivery Point(s)" means the interface between (i) any transmission and distribution utility  and (ii) the bulk
transmission system used to deliver that Electric Supply to the transmission and distribution utility as set forth in a
Confirmation Letter.

"Electric Supply" means any, Capacity and/or Energy and/or Ancillary Services  that is the subject of any
Transaction and set forth in a Confirmation Letter as contemplated by this Agreement.

"Energy" means electric energy delivered by Engage to Atlantic.

"FERC" means The Federal Energy Regulatory Commission, or any successor thereto.

"Force Majeure" means any cause that the Party claiming Force Majeure ("Claiming Party") was unable, in the
exercise of due diligence, to avoid, overcome and is beyond the reasonable control of, the Claiming Party, including,
without limitation, acts of God, such as floods, earthquakes, landslides, tornadoes, hurricanes, blizzards, or unusually
severe storms; fires, explosions; civil or Public disturbances;  strikes, lockouts, or labor disputes; acts of the Public enemy;
invasions; wars; insurrections or riots; sabotage; action or restraint of any government or governmental authority (so long
as the Claiming Party has not applied for or assisted in the application for, and has opposed where and to the extent
reasonable, such government action); labor or material shortage; force majeure under any supply contract affecting a
transmission provider or supplier of electric services; fuel or supply curtailments; and threatened or actual system
emergencies.  In a Firm Transaction, interruption by a transmission provider shall not be deemed to be an event of Force
Majeure unless (i) the Party contracting with the transmission provider shall have made arrangement with such
transmission provider for the firm transmission, as defined in the transmission provider's tariff, of Energy to be delivered
hereunder and (ii) such interruption is due to force majeure, authorized curtailment, or system emergencies as defined
under the transmission provider's tariff.  The settlement of strikes, walkouts, lockouts, and other labor disputes shall be
entirely within the discretion of a Party.

"Forecasting" means the acts of Atlantic in providing aggregate MW load forecasts on any of an hourly, daily,
weekly, or monthly basis for retail load served in either the ISO or ISA control areas.

"Good Electric Operating Practice" means the practices, methods, and acts engaged in or approved by a
significant portion of the electric power industry during the relevant time period, or the practices, methods, and acts which,
in the exercise of reasonable judgement in light of the facts known at the time the decision was made, could have been
expected to accomplish the

3

desired result consistent with reliability, safety, expedition, the requirements of governmental agencies having jurisdiction
and, if appropriate or relevant under the transaction in question, at the lowest reasonable costs; such term is not intended to
be limited to the optimum practice, method or act to the exclusion of all others, but rather to constitute a spectrum of
acceptable practices, methods or acts.

"Interest Rate" means the lesser of (i) the Prime Rate plus two percent or (ii) the maximum lawful rate of interest
permitted by applicable law.

"MPUC" means the Maine Public Utilities Commission, or any successor thereto.

"Northern Maine" means those portions of Aroostook, Washington, and Penobscot Counties, Maine located
within the control area of the Northern Maine Independent System Administrators.

"Prime Rate" means, for any date, the then-effective per annum prime rate of interest for commercial loans from
U.S. banks, published under "Money Rates" by the Wall Street Journal (adjusted on a daily basis for any change in such
published rate) or the maximum applicable lawful interest rate, whichever is less.

"Retail Sales" means sales of Electric Supply to any retail customers, as defined in Section 2.1 of this Agreement.

"Schedule" or "Scheduling" or "Scheduled" means the acts of Engage, or its designated representative, including
its transmission providers or generators, if applicable, of notifying, requesting and confirming to the appropriate Bulk
System Administrator the quantity and type of Electric Supply, to be delivered hourly pursuant to a Transaction hereunder,
on any given day or days during the Period of Delivery at a specified Delivery Point.

"Standard Offer Service" means electric generation Service provided at retail to any electricity consumer who
does not obtain electric generation Service at retail from a competitive electricity provider pursuant to Chapter 301 (or its
successor) of the MPUC's Rules and Regulations.

"Taxes" means all applicable federal, state, and local ad valorem, property, occupation, utility, gross receipts,
sales, use, excise, and other taxes, governmental charges, duties, tariffs, levies, license fees, licenses, permits and
assessments, other than taxes based on net income or net worth.

"Terms of Service Document" means the document issued to customers by Atlantic pursuant to Chapter 305 of
the MPUC's Regulations.

4

"Trade Secrets" means any documentation, material, data, or other information, collected or compiled, or created
(i) by Atlantic in connection with the Transactions or the Retail Sales, and which consists of any customer lists and
customer files that Atlantic may generate, sales information, lists, statements, or data; prospects lists; information
regarding orders, delivery requirements, and purchasing patterns, marketing, or customer information relating to retail
sales established from performance by Atlantic of the Transactions or the Retail Sales, or both; (ii) by Engage in
connection with the procedures, techniques or other mechanisms by which it manages any of the risks associated with the
purchase and delivery to Atlantic of the Electric Supply; and (iii) all documentation and other information relating to any
of the foregoing.

"Transaction" means any transaction involving the delivery by Engage to Atlantic, of Electric Supply on a
wholesale basis, in accordance with the terms and conditions set forth in a Confirmation Letter and in this Agreement.

"Transfer Price" shall have the meaning ascribed in Section 7.2.

"Wholesale" means that which is not retail.

ARTICLE 2

EXCLUSIVITY

2.1	Exclusivity. Atlantic agrees that it will obtain all its electric energy requirements (including, without
limitation, its requirements for energy, capacity, and Ancillary Services) for retail sales exclusively from Engage, provided
that Engage is in compliance with the terms of this Agreement.  Engage, in turn, agrees that it shall use all commercially
reasonable efforts to comply with any reasonable request by Atlantic to supply Atlantic with electric energy (including,
without limitation, its requirements for energy, capacity and Ancillary Services) for such retail sales.  Engage further
agrees that it will not directly sell to (a) any other party licensed as a competitive electricity provider in the State of Maine
for the purpose of resale to the Maine retail electric market, or (b) to any retail customer in the State of Maine, provided
that Atlantic is in compliance with the terms of this Agreement.  As used herein "retail" means those sales of electric
energy, capacity, and Ancillary Services that, under Maine law, may only be made by a party licensed by the MPUC to
make such sales including, without limitation, sales made directly to (i) a customer for its own end-use and not for re-sale
to others, (ii) to an entity, such as an aggregator or broker, acting on behalf of such end-use customers, or (iii) a customer
who subscribes to Standard Offer Service.

2.2	Consultation.   Atlantic shall be responsible for all retail electric

marketing-related activities (except as set forth in Section 3.3). Engage shall assist in the marketing effort by having its
representative, who is knowledgeable in power sales, available from time to time to consult with, or participate in,
marketing meetings, proposals, training

5

sessions, or other activities, upon the request of Atlantic; provided that under no circumstances shall Engage be required to
carry out any activity that would require it to obtain a Competitive Energy Provider license, other retail sales license, or
authorization of any kind, from the MPUC.

2.3	Wholesale Sales.  Atlantic may act in the capacity of a broker bringing Wholesale opportunities to
Engage for compensation to be determined on a case-by-case basis.  Atlantic is not authorized to bind Engage.  Engage
reserves the right in its sole and unlimited discretion to decline to participate in any Wholesale opportunities presented by
Atlantic. Wholesale sales shall not be subject to the exclusivity provisions of Section 2.1.

ARTICLE 3

CREDITWORTHINESS

3.1	Guaranty to Atlantic.  Subject to receipt of all requisite approvals, on or before the forty-five days
following the Effective Date, Engage shall provide to Atlantic a guaranty from one or both of its parent entities agreeing to
guarantee Atlantic the payment of any Interruption Damages to which Atlantic may be entitled under Section 4.9 of this
Agreement, not to exceed $35 million.  This guarantee shall be in the form set forth in Exhibit C and shall remain in effect
with respect to any Transactions consummated during the term of this Agreement for a period of two years after the
termination of this Agreement.

3.2	Pledge of Receivables.  As of the Effective Date, Atlantic shall issue a Pledge and grant a first priority
security interest in: (a) its cash; and (b) all of its receivables (irrespective of whether such receivables are associated with
the sale of energy) to secure the payment of the Transfer Price and performance of Atlantic's obligations under Article 7 of
this Agreement by executing a Security Agreement in a form as set forth on Exhibit D and other documents associated
therewith which may be necessary for Engage to perfect such security interest.  Nothing herein shall be construed so as to
create an obligation on the part of Atlantic's parent company in favor of Engage.

3.3 	 Retail Credit Approval.   Engage and Atlantic shall mutually agree upon retail Credit Risk with respect
to any particular retail customer or particular group of retail customers whose load exceeds or is expected to exceed 1
MW.  This mutual responsibility shall not, however, in any way modify the Revenue Sharing formula established under
Article 7.

ARTICLE 4

TRANSACTIONS

4.1	Transaction Procedures.  The Parties shall enter into Transactions pursuant to the following procedures:

6

(a)	Within ten (10) days prior to the first day of every month, Engage shall provide Atlantic Transfer Prices
for Energy, Capacity, and Ancillary Services by customer class, customer groups, or in any other form as the Parties may
agree, which price shall be firm for a period of days to be specified and shall remain firm for a Delivery Period to be
specified.  For Standard Offer Service, Engage shall provide Atlantic a Transfer Price which shall be firm for the delivery
period as requested in the applicable bid request.

(b)	Five (5) days prior to the first day of every month, Atlantic will provide Engage a forecast of volumes,
by customer class, customer group, or in any other form as the Parties agree.  After receipt of the forecast, Engage shall
prepare a Confirmation Letter(s) in a form as set forth on Exhibit A, to be executed by the Parties, setting forth the terms
of the Transaction for the Delivery Period(s).

(c)	Upon receipt of the executed Confirmation Letter(s), Engage shall Schedule deliveries to the Delivery
Point(s), pursuant to the terms of the Confirmation Letter(s).  Atlantic may amend the forecast at any time and request an
amendment to the schedules accordingly.  Engage will make commercially reasonable efforts to accommodate such
requests, which if made will be effective upon acceptance by the Bulk Power Administrator.

(d)	Atlantic, or the applicable T&D on behalf of Atlantic, shall provide any information reasonably
requested by Engage for purposes of reconciling schedules, deliveries, and payments, by customer class and customer
group, including but not limited to, invoiced amounts per billing cycle, expected remittance dates, sales tax broken out on
invoice amounts, copies of invoices, etc.

(e)	Each Party consents to the recording of its representatives' telephone conversations and if duly
authenticated, such recordings may be introduced into evidence to prove the existence and terms of any oral Transaction.

(f)	In the event of a conflict between the terms of this Agreement and the terms of an executed
Confirmation Letter, the terms of the Confirmation Letter shall prevail, provided however that the Transfer Price shall be
applied to actual quantities delivered to the Delivery Point in accordance with Section 7.6 below.

4.2  Engage's Obligations.  With respect to each Transaction, Engage shall provide and deliver, or cause to be
delivered, the Electric Supply to the Delivery Point.  Subject to reimbursement under Section 7.2, Engage shall be
responsible for any costs or charges imposed on or associated with the delivery of the Electric Supply,  including control
area services, and loss charges relating to the transmission of the Electric Supply up to the Delivery Point.  All Energy
delivered hereunder shall be three-phase sixty-hertz and shall be delivered at standard nominal voltages at the Delivery
Point.  Engage shall also be responsible for providing information that it is able to obtain, using commercially reasonable
efforts, from its sources of

7

supply in order to assist Atlantic in meeting the requirements set forth in the MPUC's Chapter 311 (Renewable Resources)
as well as with respect to the fuel and emissions requirements of the information Disclosure Label under the MPUC's
Regulations in Chapter 306.  Notwithstanding any other provisions of this Agreement, Engage shall not be under any
obligation to take part in any activity that would require it to obtain any license or other authorization from the MPUC.

4.3 Atlantic's Obligations.  With respect to each Transaction, Atlantic shall receive, or cause to be received, the
Electric Supply from the Delivery Point.  Subject to reimbursement under Section 7.2, Atlantic shall be responsible for any
costs or charges imposed on or associated with the delivery of the Electric Supply,  at and after the Delivery Point.

4.4  Forecasting Errors.

(a)	Underforecasting Errors occur in any hour in which Atlantic forecasts a load that is less than the actual
load as determined by the applicable Bulk Power Administrator.  Overforecasting Errors occur in any hour in which
Atlantic forecasts a load that is greater than the actual load as determined by the Bulk Power Administrator.

(b)	With respect to all Transactions, Engage shall be the party to the settlement account with the applicable
Bulk Power Administrator, and shall monitor forecasting errors accordingly.

(c)	With respect to Underforecasting Errors, Atlantic will pay Engage a sum equal to: the quantity of
underforecasted Electric Supply that is outside the Bandwidth multiplied by the applicable Bulk Power Administrator's
clearing price, together with any penalties that are due the applicable Bulk Power Administrator for any Underforecasting
Errors attributable to quantities outside of the Bandwidth. All costs and penalties resulting from Underforecasting Errors
within the Bandwidth shall be treated as Direct Incremental Costs to be included in the calculation of Net Margin pursuant
to Section 7.2.

(d)	With respect to Overforecasting Errors, Atlantic will pay Engage an amount equal to any penalties
imposed on Engage as a result of overforecasting errors outside of the Bandwidth.  Beyond that however, Engage will pay
Atlantic a sum equal to: the lesser of: (i)  the energy and capacity component of the applicable Transfer Price, and (ii) the
applicable Bulk Power Administrator's clearing price, multiplied by the quantity of overforecasted Electric Supply that is
outside the Bandwidth. All costs and penalties resulting from Overforecasting Errors within the Bandwidth shall be treated
as Direct Incremental Costs to be included in the calculation of Net Margin pursuant to Section 7.2. All revenues resulting
from Overforecasting Errors within the Bandwidth shall be treated as offsets to Direct Incremental Costs, and if all Direct

8

Incremental Costs are offset, then as Net Margin to be distributed according to the

provisions of Article 7.

4.5 	Retail Credit Approval.  Engage and Atlantic shall mutually agree upon retail Credit Risk with respect to
any particular retail customer or particular group of customers whose load exceeds or is expected to exceed 1 MW.

4.6	Transmission and Scheduling.  Engage shall arrange and be responsible for transmission Service to the
Delivery Point and shall Schedule or arrange for Scheduling services with its transmission provider to deliver the Electric
Supply to the Delivery Point.

4.7	Title, Risk of Loss, and Indemnity.  As between the Parties, Engage shall be deemed to be in exclusive
control (and responsible for any damages or injury caused thereby) of the delivery of the Electric Supply up to the
Delivery Point.  Engage warrants that it will deliver to Atlantic the Electric Supply free and clear of all liens, claims, and
encumbrances arising prior to the Delivery Point.  Title to and risk of loss related to the Electric Supply shall transfer from
Engage to Atlantic at the Delivery Point.  Engage and Atlantic shall each indemnify, defend, and hold harmless the other
Party from any claims arising from any act or incident occurring when title to the Electric Supply is vested in the
indemnifying Party, unless such claims are caused by the sole negligence, gross negligence, or willful misconduct of the
other Party.

4.8	Force Majeure.  If either Party is rendered unable by Force Majeure to carry out, in whole or in part, its
obligations hereunder and such Party gives notice and full details of the event to the other Party as soon as practicable
(such notice and details to be confirmed in writing within 10 days after the occurrence of the Force Majeure), then during
the pendency of such Force Majeure but for no longer period, the obligations of the Party affected by the event (other than
the obligation to make payments then due or becoming due with respect to performance prior to the event) shall be
suspended to the extent required.  The Party affected by the Force Majeure shall use diligent efforts to remedy or remove
the inability caused by the event of Force Majeure and shall give the other Party prompt written notice when the affected
Party is able to resume full performance hereunder.

4.9	Failure to Deliver.  Unless excused by Force Majeure or otherwise agreed to pursuant to a Confirmation
Letter, if Engage fails to provide or deliver all or any part of the Electric Supply pursuant to the terms of any Transaction,
Atlantic shall be entitled to Interruption Damages from Engage, provided however that if Energy Atlantic assigns its rights
under the guaranty provided pursuant to Section 3.1 herein, then payment to Energy Atlantic of any Interruption Damages
will only be made after receipt of a release and indemnification from the assignee of the rights under the Guaranty. In
addition, Energy Atlantic agrees that any payment by the Guarantor under the Guaranty provided pursuant to Section 3.1
herein shall constitute full and complete satisfaction of any duties and responsibilities of Engage hereunder.  Under no
circumstances will payment of Interruption Damages for the same failure be made under both the

9

guaranty to an assignee of Energy Atlantic and to Energy Atlantic.  Atlantic's Interruption Damages shall equal an amount
for each unit of the deficiency equal to the positive difference, if any, obtained by subtracting the Transfer Price from the
Replacement Price.  The Replacement Price shall equal (i) the price at which Atlantic, acting in a commercially reasonable
manner, purchases substitute Electric Supply not provided or delivered by Engage or, absent such a purchase, the market
price for such quantity had it been delivered to the Delivery Point as determined by Atlantic in a commercially reasonable
manner, and (ii) any resulting cost, expenses, penalties, demand, or similar charges incurred or born by Atlantic on
account of Engage's failure to provide or deliver.

4.10	Failure to Accept.  Unless otherwise agreed to pursuant to a Confirmation Letter, if Atlantic fails to
accept the delivery of Electric Supply in violation of the terms of a Transaction and is not excused by Force Majeure,
Engage shall be entitled to Interruption Damages from Atlantic.  Engage's Interruption Damages shall equal an amount for
each unit of the deficiency equal to the positive difference, if any, obtained by subtracting the Sale Price from the Transfer
Price.  The Sale Price shall equal (i) the price at which Engage, acting in a commercially reasonable manner, resells the
Electric Supply not accepted by Atlantic or, absent such a sale, the market price for such quantity had it been delivered to
the Delivery Point as determined by Engage in a commercially reasonable manner and (ii) any resulting costs, expenses,
penalties, demand or similar charges incurred or borne by Engage on account of Atlantic's failure to accept delivery.

4.11	Payment.  Interruption Damages shall become immediately due and payable.

The Party owing Interruption Damages shall pay the other Party any amounts due under Sections 4.9 and 4.10 within five
(5) Business Days of receipt by such other Party of a demand for payment setting forth in reasonable detail the basis for
calculation of the amount demanded.  In the event the Party owing Interruption Damages fails to pay Interruption Damages
when due, the other Party shall have the right to (i) suspend performance under the Transaction for which Interruption
Damages are due until such amounts plus interest at the Interest Rate have been paid, (ii) exercise any remedy available at
law or in equity to enforce payment of such amount plus interest, (iii) or both.  Any payment disputes surrounding
Interruption Damages shall be resolved in accordance with the provisions of Article10 hereof.

ARTICLE 5

TERM AND TERMINATION

5.1	Termination; Transactions.  This Agreement may terminate under Sections 5.2, 5.3, 5.4, or 6.2, below.
In the event of termination of this Agreement under any such Section(s), Transactions then in effect shall continue in effect
until full payment has been received by Engage for Electric Supply delivered through the end of their respective Delivery
Periods.

10

5.2	Primary Term.  This Agreement shall take effect upon the date first indicated on page one herein and
will continue through February 28, 2002.  This Agreement may be extended on a year to year basis by mutual agreement
of the Parties at least six months prior to the initial expiration date and any anniversary thereof.

5.3	Change of Circumstance.  If a Party determines, in its reasonable judgment, that

(a)	any change in federal, state, or local law statute, regulation, or ordinance, or local utility state or federal
tariff provision will be unduly burdensome to that Party such that the change in question materially impairs the
commercial value of this Agreement to the burdened party, or

(b)	persistent change in market or economic conditions has occurred which materially impairs the benefits
and burdens of this Agreement as to either party or both Parties,

then not later than sixty (60) days after learning of such change, the Party subject to such new change(s) shall
initiate a good faith effort to negotiate with the other Party to modify this Agreement to cure the effect of such unduly
burdensome change.  If no such cure is agreed upon by the Parties within thirty (30) days of the first meeting to negotiate,
then the affected Party may terminate this Agreement upon written notice to the other Party, which notice shall take effect,
and this Agreement shall terminate, upon the expiration of ninety (90) days after the notice is received.

5.4	Other Termination Rights.  Either Party shall have the right to suspend performance, or
terminate this Agreement upon five (5) days written notice if: (a) the other Party fails to perform any material obligation
hereunder, or (b) if as the result of an audit or otherwise, either Party has reasonable grounds for insecurity as to the
performance of the other Party hereunder and such other Party fails to provide adequate assurance, of its performance, as
determined by the insecure Party in its reasonable discretion, within five (5) days of a written request therefore. Further,
Engage shall have the right to suspend performance, or terminate this Agreement upon five (5) days written notice if
Atlantic is in violation of the Pledge, or Security Agreement between the Parties, and Atlantic shall have the right to
suspend performance, or terminate this Agreement upon five (5) days written notice in the event of a default under the
guaranty issued on behalf of Engage for the benefit of Atlantic pursuant to Section 3.1 above, or if the guaranty is
terminated by the guarantor prior to the termination of this Agreement and not replaced within five (5) days.

ARTICLE 6

CONDITIONS PRECEDENT

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6.1	Condition Precedent.  The effectiveness of this Agreement and the obligations of the Parties under this
Agreement are subject to the following conditions precedent:

6.1.1	Conditions for the Benefit of Atlantic.  Unless this condition has been waived by Atlantic in its sole and
absolute discretion:

(a)	Atlantic shall have received, by December 15, 1999, authorization by its parent company and managing
Member, Maine Public Service Company, to the extent required to be bound by this Agreement.

(b)	By January 1, 2000, Atlantic shall have received the guaranty issued on behalf of Engage pursuant to
Section 3.1 above.

(c)	There is no change if federal, state, or local law, statute, regulation, ordinance, or local utility state or
federal tariff provision prior to March 1, 2000 that would be unduly burdensome to Atlantic such that the
change impairs the value of this Agreement to Atlantic in its sole discretion.

6.1.2  Conditions for the Benefit of Engage.  Unless the following conditions have been  waived by Engage in its
sole and absolute discretion:

(a)	Engage shall have received, by December 15, 1999,  an affirmative vote of its Board of
Directors, or equivalent body, to the extent required to be bound by this Agreement, and by
January 1, 2000 Engage shall have received all requisite parental approvals for issuance of the
guaranty, for which such approvals the board(s) reserve absolute discretion:

(b)	Atlantic and the Escrow Agent shall have executed an Escrow Agreement in conformance with
Exhibit B by January 1, 2000, and Atlantic shall have executed a Security Agreement in
conformance with Exhibit D, contemporaneously with this Agreement:

- Atlantic shall execute agreements with the applicable Transmission and Distribution
Utility(ies), pursuant to Chapters 301(if Atlantic makes a successful bid to provide Standard
Offer Service) and 322 of the MPUC's Regulations, as well as an agreement regarding the
designated account for deposit, that are acceptable in form and content with Engage in its sole
and absolute discretion; and

(d)	There is no change if federal, state, or local law, statute, regulation, ordinance, or local utility
state or federal tariff provision prior to March 1, 2000 that would be unduly burdensome to
Engage such that the change impairs the value of this Agreement to Engage in its sole
discretion.

6.2	If Not Satisfied.  In the event the Conditions Precedent stated in Section 6.1 are not satisfied or waived
by the date(s) provided, then the Parties hereto shall be released of their obligations hereunder, and this
Agreement shall be terminated.

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ARTICLE 7

COMPENSATION

7.1	Deposit of Receipts from Retail Sales.  For Retail Sales other than Standard Offer Service Sales
and Retail Sales for which the Transmission and Distribution Utility is not acting as agent for billing and
collection, Atlantic shall require, within its Terms of Service Document or otherwise applicable contract with a
retail sales customer, that  payments for all invoices issued by Atlantic be sent to an Escrow Account established
by the Parties pursuant to a Escrow Agreement substantially in the form set forth in Exhibit B. Such requirement
within Atlantic's Terms of Service Document, or otherwise applicable retail sales contract, shall not be amended
without the express written consent of Engage.  With respect to Retail Sales made via Standard Offer Service, or
other Retail Sales for which the Transmission and Distribution Utility is acting as agent for billing and collection,
Atlantic shall require the applicable Transmission and Distribution Utility (or such other billing agent, or if
applicable, Atlantic) to direct all payments received to the Escrow Account. Disbursements from such Escrow
Account  will be permitted only for the purposes set forth and in the manner described in this Agreement and
such Escrow Agreement.

7.2	Participation Fee.   As part of its compensation for services performed hereunder Engage shall
receive a Participation Fee which is a percentage of the net revenues derived from the Retail Sales (the "Net
Margin"), which Net Margin shall be determined by subtracting from the total revenues invoiced from the Retail
Sales, in order (i) applicable Sales Taxes, (ii) the Transfer Price; and (iii) Direct Incremental Costs.

(i)	The Transfer Price shall consist of a price quoted by Engage to cover the estimated cost to
Engage of:

(a)	  Energy and Capacity;

(b)	 Any Ancillary Services supplied;

(c)	 Transmission and transmission/distribution line losses; as well as,

(d)	A charge for portfolio supply functions performed by Engage (the "Portfolio Supply Charge"),
which charge shall be one dollar ($1.00) per MWH, except that the Portfolio Supply Charge
will not apply to any power sold in Northern Maine if that power's source of supply is New
Brunswick Power Corporation.

The Transfer Price shall also include any sums due Engage pursuant to Section 4.4.

The Transfer Price shall not include any estimated profit margin, but only an estimate of the costs set
forth above. The Transfer Price shall be set forth on each Confirmation Letter for

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any Transaction and shall be applicable to the actual deliveries of Electric Supply delivered to the Delivery
Point(s) calculated in accordance with Section 7.6.

(ii)	Direct Incremental Cost shall consist of:

(a)	Load-based charges by the applicable Bulk Power Administrator and the annual FERC load-based assessment;

(b)	Settlement costs, revenues, or penalties paid to or received from the applicable Bulk Power
Administrator as a result of forecasting errors that fall within the Bandwidth, as described in
Section 4.4.

(c)	One-time Customer acquisition cost allocated to Atlantic in the amount of: $140 for each retail
customer whose load is estimated to be equal or greater than 100 kW (annual peak demand);
and $50 for each retail customer whose load is less than 100 kW (annual peak demand).  This
item (b) shall not apply to any Retail Sales made pursuant to Standard Offer Service.

The Direct Incremental Costs shall not include any amounts reflecting a profit margin or any overhead costs of
either Party.  Both Parties shall be paid or reimbursed for any Direct Incremental Cost either paid by, or owed to, either
Party out of the revenues received from Retail Sales.

After making deduction for the applicable Sales Taxes, the Transfer Price and Direct Incremental Costs, the Net
Margin for all Retail Sales shall be allocated between Atlantic and Engage as follows:

Atlantic			Engage

Standard Offer Sales

-	Northern Maine		70 %                          30 %

-	All Other				35 %			65 %

All Other Retail Sales                        70 %                         30 %

7.3	Net Margin Distribution.  For each calendar month after the commencement of Retail Sales by Atlantic
(each calendar month is a "Computation Period"), the Parties shall calculate the Net Margin on the revenues invoiced for
Retail Sales during that Computation Period within ten (10) days of the expiration of the Computation Period.  The
revenues deposited

14

in the Escrow Account shall be distributed in accordance with Section 7.2 within fifteen (15) days after the expiration of
each Computation Period. In calculating the Net Margin, the Parties shall calculate the Transfer Price and the Direct
Incremental Costs of all Retail Sales made in the last Computation Period.  Any elements of the Transfer Price or the
Direct Incremental Cost not then ascertainable shall be estimated by the Parties and shall be adjusted in subsequent
Computation Periods to account for any difference between the estimates and actual costs.

If the revenues from Retail Sales in any Computation Period are less than the combined amounts of the applicable
Sales Taxes, Transfer Price and the Direct Incremental Costs, the Parties shall apply such revenues first to the payment of
the Sales Taxes, and then the Transfer Price, with any remaining amounts being applied to the payment or reimbursement
of each component of the Direct Incremental Costs on a pro-rata basis.  Any Sales Taxes, Transfer Price or Direct
Incremental Cost not paid or reimbursed from Retail Sales revenues during the appropriate Computation Period
("Uncompensated Amounts") shall be carried forward into the next subsequent Computation Period or Periods and applied
to the appropriate category in that Period or Periods (i.e. any Uncompensated Transfer Price would be added to the
Transfer Price in the next Period, and any Uncompensated Direct Incremental Cost would be added to the appropriate
component of the next Period's Direct Incremental Cost) until such Uncompensated Amounts have been fully paid or
reimbursed. Any Uncompensated Amounts shall accrue interest at the Interest Rate until paid.

7.4	Portfolio Supply Charge.  The Portfolio Supply Charge of one dollar per MWh specified in Section 7.2
(i)(d) shall remain in effect only for one year from the Effective Date.  The amount and duration of any subsequent
Portfolio Supply Charge shall be agreed to by the Parties.

7.5	Allocation of and Indemnity for Taxes.  Engage is liable for and shall pay or cause to be paid, or
reimburse Atlantic if Atlantic shall have paid, all Taxes applicable to power sold prior to the Power reaching the Delivery
Point ("Engage's Taxes").  In the event Atlantic is required to remit any of Engage's Taxes, the amount thereof shall be
deducted from any sums becoming due to Engage hereunder.  Engage shall indemnify, defend, and hold harmless Atlantic
from any claims arising out of or in connection with Engage's Taxes.  Atlantic is liable for and shall pay or cause to be
paid or reimburse Engage if Engage shall have paid Taxes applicable to power sold at and after the Delivery Point
("Atlantic's Taxes").  Atlantic shall indemnify, defend, and hold harmless Engage from any claim arising out of or in
connection with Atlantic's Taxes.  Either Party, upon written request of the other, shall provide a certificate of exemption
or other reasonable satisfactory evidence of exemption if either Party is exempt from Taxes, and shall use reasonable
efforts to obtain and cooperate with obtaining any exemption from or reduction of any Taxes.  Each Party shall use
reasonable efforts to administer this Agreement and implement the provisions in accordance with the intent to minimize
Taxes.

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7.6	Electric Supply Statement.   Engage shall render a statement to Atlantic setting forth the total quantity of
Electric Supply that was delivered or that Atlantic was obligated to accept and the amount due to Engage therefore, during
each Computation Period.  The listed quantities for Energy delivered shall be based upon measurements taken in
accordance with ISA or ISO standards, within their respective control areas, unless actual measurements are not available
at the time the statement is prepared in which case scheduled amounts may be used.  Adjustments to actual measurements
shall be made in the following statement.  If sold as a separate product, the quantity of Capacity and Ancillary Services
will be determined in accordance with the relevant power pool, control area, or reliability council requirements.  Each
statement shall contain a clear identification of the amount due and the basis therefor and shall be accompanied by
sufficient information to enable Atlantic to determine the accuracy thereof.   All amounts due Engage for Electric Supply
shall be paid out of the revenues received from Retail Sales in the manner set forth in Section 7.3.

7.7	Billing Disputes.  If either Party disputes any portion of any calculation of any item set forth in Section
7.2, allocations nevertheless shall be made as invoiced and such Party shall provide the other Party a written explanation
of the basis for the dispute. The Parties shall work together in good faith to resolve the dispute.  Upon determination of the
correct amount, if any amount is determined to be refunded, it shall be paid in the next Computation Period after such
determination, along with interest accrued at the Interest Rate from the date of payment to the date the refund payment is
transmitted.  If a resolution is not obtained within thirty (30) days, the Parties shall proceed with the Dispute Resolution
process procedures set forth in Article10 below.

7.8	Audits.  Each Party shall keep complete accurate records and memoranda of its actions taken hereunder
and shall maintain such records and memoranda as may be necessary to determine or justify with reasonable accuracy
items relevant to this Agreement.  Either Party shall have the right to audit the books and records of the other Party, at
reasonable times and dates, to the extent necessary to verify the accuracy of any statement, payment, charge, or
computation made pursuant to the provisions of this Agreement.  The cost of the audit shall be borne by the auditing Party,
provided however that Engage shall conduct an audit of Atlantic two (2) times annually, the cost of which shall be borne
by each Party on a 50/50 basis.  Atlantic shall bear the cost of its own annual audit performed independent of the two
audits for which the Parties will share the cost. .  Further, Atlantic shall provide reports as requested by Engage on a
reasonable periodic basis, that reflect the then-current status of Atlantic's accounts. Audits shall be completed within
eighteen (18) months following the end of the year in which such statement, payment, charge, or computation was
tendered.  If any audit reveals an inaccuracy resulting in an error in any item described in Section 7.2, the auditing Party
shall present its claim for necessary adjustments in such item to the other Party within one (1) month of the completion of
the audit.  The Parties shall use their best efforts to make necessary adjustments and any agreed debits or credits shall be
reflected in the Computation Period following the Parties' agreement on the adjustment.  No adjustments shall be made
more than twenty-four (24) months after the month in

16

which the Transaction involving the claim occurred, provided that the inception of Dispute Resolution under Article 10 of
this Agreement to resolve a disagreement shall toll this twenty-four (24) month adjustment period.

7.9	Accounting.  Each party shall retain on its books of accounts a separate account for all Transactions
under this Agreement.  Each such account shall be maintained according to an accounting methodology mutually agreed
upon and shall be in accordance with U.S. Generally Accepted Accounting Principals.  The account for these Transactions
shall be used to determine the Revenue Sharing set forth in Article 7 and the financial performance of every Transaction
shall be reported using the same accounting method used to maintain such accounts.

ARTICLE 8

LIABILITY

8.1	Limitation on Warranties.	OTHER THAN THOSE EXPRESSLY STATED IN THIS AGREEMENT,
THERE ARE NO EXPRESS OR IMPLIED GUARANTEES OR WARRANTIES OF MERCHANTABILITY, FITNESS,
OR SUITABILITY OF POWER OR ANY SERVICE PROVIDED HEREIN BY ANY PARTY FOR ANY
PARTICULAR PURPOSE NOTWITHSTANDING ANY COURSE OF PERFORMANCE OR USAGE OF TRADE, OR
LACK THEREOF, THAT MAY BE INCONSISTENT WITH THIS SECTION.

8.2	Limitation of Liability.	FOR BREACH OF ANY PROVISION FOR WHICH AN EXPRESS
REMEDY OR MEASURE OF DAMAGES IS PROVIDED IN THIS AGREEMENT, THE LIABILITY OF THE
DEFAULTING PARTY SHALL BE LIMITED AS SET FORTH IN SUCH PROVISION.  IF NO REMEDY OR
MEASURE OF DAMAGES IS EXPRESSLY PROVIDED FOR A BREACH OF THIS AGREEMENT, THEN THE
LIABILITY OF THE DEFAULTING PARTY SHALL BE LIMITED TO DIRECT DAMAGES AND, AS PART OF
THE CONSIDERATION FOR THIS AGREEMENT, EACH PARTY AGREES TO WAIVE ALL OTHER TYPES OF
DAMAGES OR REMEDIES TO WHICH IT MIGHT BE ENTITLED FOR SUCH BREACH.  UNDER NO
CIRCUMSTANCES SHALL EITHER PARTY, OR THEIR DIRECTORS, OFFICERS, EMPLOYEES, AFFILIATES,
AGENTS, REPRESENTATIVES OR THOSE FOR WHOM THEY ARE LEGALLY RESPONSIBLE, BE LIABLE TO
THE OTHER PARTY FOR, AND AS PART OF THE CONSIDERATION FOR THIS AGREEMENT EACH PARTY
AGREES TO WAIVE ANY RIGHT TO, SPECIAL, INDIRECT, OR CONSEQUENTIAL DAMAGES ARISING OUT
OF THE PERFORMANCE OR NON-PERFORMANCE OF ANY OBLIGATION UNDER THIS AGREEMENT OR
THE BREACH OF ANY REPRESENTATION, WARRANTY, OR COVENANT UNDER THIS AGREEMENT.

8.3	Indemnity for Personal Injury or Property Damage.	 Subject to Sections 8.1 and 8.2 above, each Party
agrees to indemnify, defend, and hold harmless the other Party against any

17

and all claims, liability, loss, damage, or expense arising from injury to individuals or damage to tangible property caused
by or resulting from the misconduct or negligent acts or omissions of the indemnifying Party, its employees or agents
related to this Agreement.

8.4	Survival.	The rights and obligations of the Parties under this Agreement shall survive termination of this
Agreement with respect to any act, occurrence, or omission occurring prior to termination of this Agreement.

ARTICLE 9

ASSIGNMENT AND SUCCESSION

9.1	Neither Party shall assign this Agreement or its rights hereunder without the prior written consent of the
other Party, which consent shall not be unreasonably withheld or delayed, with the following exceptions.  Unless otherwise
prohibited, either Party may, without the need for consent from the other Party (and without relieving itself from liability
hereunder), (a) transfer, pledge, or assign this Agreement as security for any financing with financial institutions; or (b)
transfer or assign this Agreement to an Affiliate of such Party, provided the Affiliate has substantially equivalent financial
capability to that of the assignor; or (c) transfer or assign this Agreement to any person or entity succeeding to all or
substantially all of the assets of such Party, provided any such assignee expressly agrees to be bound by the terms and
conditions hereof.  Any assignment made in compliance with this Article 9 shall inure to and be binding upon the
successors and assigns of the assigning Parties.

ARTICLE 10

DISPUTE RESOLUTION

10.1	Good Faith Negotiation.  In the event of a dispute between the Parties with respect to performance under
this Agreement, the Party disputing an action or inaction by the other Party shall submit a written explanation of the
dispute to the other Party along with any available supporting documentation.  The Parties shall then cooperate in good
faith to resolve the dispute as expeditiously as possible.

10.2	Arbitration.  If the Parties' CEO's or their respective designees do not reach a mutually agreeable
resolution of the dispute within thirty (30) days of the matter being referred to them, then the matter shall be submitted to
non-binding arbitration by one arbitrator, who has not been previously employed by either Party, and does not have a
direct or indirect interest in either Party or the subject matter of the arbitration.  Such arbitrator shall be mutually agreed
by the Parties within thirty (30) days after Written notice from either Party requesting arbitration, or failing agreement,
shall be selected under the Expedited Rules of the American Arbitration Association ("AAA").  Such arbitrator shall be
experienced in law, accounting, energy trading, or other appropriate expertise familiar with the nature of the dispute.  Such
arbitration shall be held

18

in  New York, New York.  The rules of the AAA shall apply to the extent not inconsistent with the rules herein specified.
The arbitration shall be conducted according to the following: (a) Not later than seven (7) days prior to the hearing date set
by the arbitrator, each Party shall submit a brief with a single proposal for settlement; (b) The hearing shall be conducted
on a confidential basis without continuance or adjournment, (c) The arbitrator shall be limited to selecting only one of the
two proposals submitted by the Parties; (d) Each Party shall equally divide the costs of the arbitrator and the hearing, and
each Party shall be responsible for its own expenses and those of its counsel and representatives, and (e) evidence
concerning the financial position or organizational make-up of the Parties, any offer made or the days of any negotiation
prior to the arbitration and the cost to the Parties of their representatives and counsel shall not be admissible.  In the event
either Party fails to comply with the decision of the arbitrator within fifteen (15) days of the date the decision is issued,
either Party may thereafter seek any remedy available to it whether at law or in equity.

ARTICLE 11

REPRESENTATIONS AND WARRANTIES

11.1	Each Party makes the following representations and warranties to the other Party that, as of the Effective
Date and each time it enters into a Transaction:

(a)  It is duly organized and validly existing, is qualified to do business and in good standing in its place of
incorporation or organization, and has all requisite power, authority, and franchises, corporate or otherwise, to
enter into this Agreement and perform its obligations hereunder and under any Transaction;

(b)  The execution, delivery, and performance of this Agreement and any Transaction have been duly authorized
by such Party in accordance with all organizational instruments, that such Party has full power to execute, deliver,
and perform its obligations under this Agreement and any Transaction, and that this Agreement has been duly
executed and delivered by an authorized representative of such Party;

(c)  The execution, delivery, and performance of this Agreement and any Transaction will not (i) result in a
breach of, or constitute a default under, any agreement, lease, or instrument to which it is a party or by which it or
its properties may be bound or affected, or (ii) violate any applicable law, rule, regulation, statute, ordinance,
writ, order, or determination of an arbitrator or a court or other governmental authority;

(d)  No litigation, investigation, or other legal, administrative, or arbitration proceeding is pending or, to the best
of its knowledge, threatened against it or any of its properties or revenues, existing or future, which if adversely
determined could have a material adverse effect on its ability to perform hereunder;

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(e)  This Agreement and any Transaction constitutes a legal, valid, and binding obligation
against it, enforceable in accordance with its terms, except to the extent that enforcement may
be limited by applicable bankruptcy, insolvency, reorganization, or other similar laws affecting
creditors' rights generally and by principles of equity; and

(f)  All government authorizations and approvals necessary to enter into this Agreement and
any Transaction and perform each of its obligations hereunder and thereunder have been
obtained and are in effect.

ARTICLE 12

MISCELLANEOUS

12.1	UCC.  Except as otherwise provided for herein, the Uniform Commercial Code ("UCC") shall
be deemed to apply to all Transactions and Electric Supply shall be deemed to be a "good" for purposes of the
UCC.

12.2	Responsibility for Compliance.  Each Party shall be responsible for its own compliance with all
applicable laws and regulations, including those relating to the environment, and each Party shall hold the other
Party harmless from any liability, loss, cost, damage or expense (including, but not limited to reasonable
attorneys' fees) arising out of its failure to comply with such laws and regulations.

12.3	Reliability Guidelines.  Each Party agrees to adhere to Good Electric Operating

Practice and any regional or subregional operating requirements.

12.4	Forward Contract.  The Parties acknowledge and agree that all Transactions

constitute "forward contracts" within the meaning of the United States Bankruptcy Code.

12.5	Regulatory.  It is understood by the Parties that this Agreement and performance hereunder is
subject to all present and future valid and applicable laws, orders, statutes, and regulations of courts or regulatory
bodies (state or federal) having jurisdiction over the Parties or any Transaction hereunder.

12.6	Notices.  Any non-billing/payment notice, request, demand, statement, or payment provided for
in this Agreement shall be confirmed in writing and shall be made as specified below.  A notice sent by facsimile
transmission shall be deemed received by the close of the Business Day on which such notice was transmitted if
transmitted prior to 4:00 p.m. prevailing time at the location of receipt, otherwise deemed received by the close of
the following Business Day, or such earlier time as confirmed by the receiving Party and notice by overnight mail
or courier shall be deemed to have been received two (2) Business Days after it was sent or such earlier time as is
confirmed by the receiving Party unless it confirms a prior

20

verbal communication in which case any such notice shall be deemed received on the day sent.  The addresses of
the Parties are as follows:

NOTICES & CORRESPONDENCE:

Atlantic:

Energy Atlantic, LLC

P. O. Box 1148

Presque Isle, Maine 04769-1148

Attn: Calvin D. Deschene

Fax No.:  (207) 764-4657

Engage:

Engage Energy US, L.P.:

Five Greenway Plaza, Suite 1200

Houston, Texas 77046

Attn: Contract Administration

Fax No.:  (713) 297-1026

12.7	Entirety.  This Agreement including the appendices and exhibits hereto, including, without
limitation, any effective Confirmation Letters, constitute the entire agreement between the Parties.  There are no
prior or contemporaneous agreements or representations affecting the same subject matter other than those herein
expressed.  No amendment, modification, or change herein shall be enforceable, except as specifically provided
for in this Agreement, unless reduced to writing and executed by both Parties.

12.8	GOVERNING LAW.  THIS AGREEMENT AND ALL DISPUTES ARISING OUT OF THIS
AGREEMENT SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE THE LAWS OF THE
STATE OF MAINE, WITHOUT REGARD TO THE LAWS OF SUCH STATE REQUIRING THE
APPLICATION OF THE LAWS OF ANOTHER STATE, AND FEDERAL LAW, AS APPLICABLE.

12.9	Waiver.  None of the provisions of this Agreement shall be considered waived

by either Party except when such waiver is given in writing. The failure of either Party to

insist in any instance on strict performance of any of the provisions of this Agreement shall not

be construed as a waiver of any such provision or the relinquishment of any rights hereunder in the future.

12.10	Severability.  The invalidity or unenforceability of any provision of Agreement shall not affect
the validity and enforceability of any other provision, and each provision of this Agreement shall be enforced to
the maximum extent permitted by applicable law.

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12.11	Headings.  The captions, headings, table of contents, and arrangements are for convenience
only and do not and shall not be deemed to affect, limit, amplify, or modify the terms and provisions hereof.

12.12	"Set-Off".  Each Party reserves to itself all rights, set-offs, counterclaims, and other remedies or
defenses to which it is or may be entitled, arising from or out of this Agreement.  All outstanding Transactions
and the obligations to make payment in connection therewith, or under this Agreement, may be offset against
each other, set-off or recouped therefrom.

12.13	Confidentiality. The Parties shall treat all terms hereunder, as well as any other proprietary or
confidential information designated as such by the other Party, as confidential information ("Confidential
Material").  Except as may be required by applicable law, FERC, MPUC, or order of any other regulatory agency
or court, neither Party will, without the express written agreement of the other Party, publish, disclose, or
otherwise divulge Confidential Material to any person at any time.  If required by applicable law, FERC, or
governmental or judicial order, the Parties may release Confidential Material, provided the Party to whom the
order applies uses reasonable efforts to cause the governmental body or court to treat the information in a
confidential manner and prevent such information from entering the public.  The Parties shall give notice to one
another of the existence of such an order and shall reasonably cooperate with each other in any proceeding to
oppose disclosure of Confidential Material.

12.14	Public Announcements.  No Party shall issue any press release or make any other public
announcement relating to the transaction contemplated hereby or disclose the content of this Agreement without
the prior written consent of the other Party hereto, except if required

under applicable law or the rules of any stock exchange on which such Party's shares are listed; provided,
however, that if such disclosure is required, prior to such disclosure, a Party shall provide a copy of such
announcement to the other party hereto.



12.15 	Trade Secrets.      During the term of this Agreement and thereafter, each Party shall not to use,
copy, reproduce, disseminate, transmit, summarize, quote for itself or for others, and shall not disclose to others,
any Trade Secrets, except with prior written consent of the other Party, or as otherwise provided in this
Agreement.  It is understood and agreed that the Trade Secrets are valuable, special, and unique, and that Trade
Secrets are private and Confidential Materials.  Each Party agrees and acknowledges that Trade Secrets created
by the other Party are the exclusive property of that other Party. The provisions of this Section 12.15 shall not be
binding on Engage in the event that Atlantic: (a) is no longer certified or approved to perform retail sales in
Maine; (b) makes an assignment or any general arrangement for the benefit of creditors, (c) files a petition or
otherwise commences, authorizes or acquiesces in the commencement of a proceeding or cause of action under
the bankruptcy or similar law for the protection of creditors, or has such petition filed against it and such petition
is not withdrawn or dismissed for 30 days after such filing, (d) otherwise becomes bankrupt or insolvent, (e) is

22

unable to pay its debts as they become due, or (f) otherwise ceases to conduct business.

12.16	Cumulative Remedies.  Unless otherwise restricted by this Agreement, the remedies heretofore
provided are cumulative, not exclusive of any remedies provided by law or in equity, and may be pursued
separately, successively, or concurrently by the Party aggrieved.

12.17	Counterparts.  This Agreement may be executed in any number of counterparts, and each
executed counterpart shall have the same force and effect as an original instrument.

12.18	No Third Party Benefitted.  This Agreement and any Transactions entered into pursuant to this
Agreement are for the sole benefit of Engage and Atlantic and not for any third party whatsoever.

12.19	Legal Relationships.  This Agreement creates no partnership, joint venture, or any other form of
organization or association.  This Agreement creates no agency or other type of legal relationship between the
Parties except that of independent contracting parties, and there shall be no other legal relationship between the
Parties.  This Agreement creates no fiduciary duty, and there shall be no fiduciary relationship between the
Parties.

12.20	Further Assurances.  If either Party reasonably determines or is reasonably advised that any
further instruments or any other things as are necessary or desirable to carry out the terms of this Agreement, the
other Party shall execute and deliver all such instruments and

assurances and do all things reasonably necessary and proper to carry out the terms of this Agreement.

23

IN WITNESS WHEREOF, the Parties have executed this Wholesale Power Sales Agreement to be
effective as of the Effective Date.

ENGAGE ENERGY US, L.P.			ENERGY ATLANTIC, LLC

By: /s/ James C. Dyer IV 				By: /s/ Stephen A. JohnsonName:  James C. Dyer, IV				Name: Stephen A. Johnson

Title: Executive Vice President & C.O.O.		Title: Vice President & General Counsel

24

GUARANTY			EXHIBIT C

Guaranty dated effective as of December 1, 1999, by The Coastal Corporation, a Delaware corporation (hereinafter
referred to as the "Guarantor"), in favor of Energy Atlantic, L.L.C., a Maine limited liability company (hereinafter referred
to as "Creditor").

WHEREAS, Creditor and Engage Energy US, L.P., a Delaware limited partnership (hereinafter referred to as
"Debtor"), have entered into that certain Wholesale Power Sales Agreement dated December 9, 1999 (the "Agreement"); and

WHEREAS, as a condition precedent to the effectiveness of the Agreement, Creditor is requiring Guarantor to provide
a guaranty in form and substance satisfactory to Creditor; and

WHEREAS, Guarantor has agreed to provide such a guaranty to Creditor as provided herein;

NOW, THEREFORE, for and in consideration of the premises, Guarantor hereby agrees as follows:

1. Guaranty. Guarantor guarantees to Creditor the payment of amounts due and payable by Debtor pursuant to Section
4.9 of the Agreement up to a maximum amount in the aggregate of thirty million dollars ($35,000,000) (such obligations being
hereinafter referred to as the "Obligations"); provided, however, that as to Obligations which Guarantor is called upon to
honor, Guarantor is and shall be entitled to assert any and all claims, counterclaims, defenses, offsets and other rights which
Debtor could assert against Creditor with respect to the Obligations, except as provided in paragraph 7 below. In the event
Debtor defaults in the payment of any of the Obligations, after thirty days' written notice to Guarantor at the address provided
below, Guarantor shall make such payment or otherwise cause same to be paid. Guarantor's obligations are subject to its
receiving from Creditor copies of any and all notices of defaults and events of default given by Creditor to Debtor pursuant
to the Agreement in the same manner and at the same time as such notices are given by Creditor to Debtor, except to
Guarantor's address for notice set forth in this Guaranty.

2. Termination. Guarantor may terminate its liability hereunder by delivering written notice thereof at least thirty (30)
days prior to the effective date of such termination, and in any event, this Guaranty shall terminate on February 28, 2002.
Termination shall not affect any obligation of Guarantor hereunder as to any amounts which became due and payable by
Debtor under the Agreement prior to the effective date of such termination.

3. Waivers. Except as is otherwise provided in this Guaranty, Guarantor waives notice of acceptance of the guaranty
contained herein, presentment, demand, notice of dishonor, protest and notice of protest, and prosecution of litigation in
connection with the Obligations.

4. Assignment. Neither Guarantor nor Creditor may assign its respective rights or obligations under this Guaranty
without the other's written consent. Subject to the foregoing, this Guaranty shall be binding upon and inure to the benefit of
the parties hereto and their respective successors, permitted assigns, and legal representatives.

H:\CGL\JSG\GUARANTY\ENERATLI.wpd

5. Notices. Any notice or other communication required or permitted to be given to Guarantor under this Guaranty
shall be deemed to have been given when delivered personally or otherwise actually received or on the tenth (10th) day after
being deposited in the United States mail if registered or certified, postage prepaid, or one (1) day after delivery to a nationally
recognized overnight courier service, fee prepaid, return receipt requested, if in writing and addressed as follows: The Coastal
Corporation, Nine Greenway Plaza, Houston, Texas 77046, Attention: Secretary.

6. APPLICABLE LAW. THIS GUARANTY SHALL IN ALL RESPECTS BE GOVERNED BY AND
INTERPRETED IN ACCORDANCE WITH THE LAWS OF THE STATE OF TEXAS WITHOUT REGARD TO
PRINCIPLES OF CONFLICT OF LAWS.

7. Effect of Certain Events. Guarantor agrees that Guarantor's liability hereunder will not be released, reduced,
impaired or affected by the occurrence of anyone or more of the following events:

a.	The insolvency, bankruptcy, reorganization, or disability of Debtor;

b.	The renewal, consolidation, extension, modification, or amendment from

time to time of the Agreement;

c.	The failure, delay, waiver, or refusal by Creditor to exercise any right or

remedy held by Creditor with respect to the Agreement;

d.	The sale, encumbrance, transfer or other modification of the ownership of

Debtor or the change in the financial condition or management of Debtor.

8. Prior Guaranties. This Guaranty supersedes and replaces all previous guaranties of Guarantor with respect to
Debtor's obligations to Creditor.

IN WITNESS WHEREOF, Guarantor has duly executed this Guaranty effective as of the date first written
above.

THE COASTAL CORPORATION

By:   /s/ J. B. Levos, Vice President and Controller

Exhibit 10(ac)

ADDENDUM TO

WHOLESALE POWER SALES AGREEMENT

Energy Atlantic, LLC (Atlantic) and Engage Energy US L.P. (Engage), for good and valuable consideration, the
receipt of which is acknowledged by the parties, hereby enter into this Addendum to a Wholesale Power Purchase
Agreement by and between Atlantic and Engage dated as of December 9, 1999 (the Power Agreement).



Recitals

Whereas, Atlantic has been awarded the right to supply Standard Offer Service to Central Maine Power
Company's (CMP) Residential and Small Non-Residential Customer Class (the CMP Standard Offer Sale); and

Whereas, as an essential part of the CMP Standard Offer Sale, Engage has acquired the energy and capacity
available through CMP's Capacity and Energy Sale pursuant to Chapter 307 of the Maine Public Utilities Commission's
(MPUC) Regulations; and

Whereas, the CMP Standard Offer Sale differs sufficiently from other Transactions contemplated by the Power
Agreement that Engage and Atlantic have agreed that their respective compensations for the CMP Standard Offer Sale
should depart from certain terms set forth in Article 7 of that Power Agreement.

Therefore, intending to be legally bound by this Addendum, Engage and Atlantic hereby agree as follows:

1.  Definitions.  Unless otherwise stated, all terms shall have the same meaning as in the Power Agreement.

2.  Compensation.  Notwithstanding any contrary provision in the Power Agreement, the parties agree that each
of them shall receive the Net Margin set forth below on all revenues realized from the CMP Standard Offer Sale, which
Net Margin shall, on a month-by-month basis be determined by subtracting from the total monthly revenues paid to the
Escrow Account by CMP (acting as the billing and collecting agent) under the CMP Standard Offer Sale, in order, (i) the
applicable sales tax, (ii) the Transfer Price, (iii) Direct Incremental Costs, as defined in this Section 2(b).

(a)  The total Transfer Price for the CMP Standard Offer Sale shall be an amount equal to $0.03667 per kwh sold
under the CMP Standard Offer Sale.

(b)  Direct Incremental Costs for the CMP Standard Offer Sale shall consist of:

-2-

(i)  The items described in Article 7.2(ii)(a) and (b) of the Power Agreement; and

(ii)  An allowance for the cost of billing each customer under the CMP Standard offer Sale in an amount equal to
$0.26 per customer per month; and

(iii)  An allowance for the cost of mailing to each customer the Information Disclosure Label required under
Chapter 306 of the MPUC's Regulations in an amount equal to $0.26 per customer per required mailing; and

(iv)  An allowance for the cost of providing the surety bond for the CMP Standard Offer Sale as required by
Chapter 301 of the MPUC's Regulations in an amount equal to 1.75% of the face amount of such bond.

(d) After making deduction for the applicable Sales Tax and the other items set forth in (a) through (c) above, the
parties agree that the Net Margin for the CMP Standard Offer Sale shall be allocated 79% to Atlantic and 21% to Engage.

3.  Survival of Power Agreement Terms.     Except as expressly varied in Section 2 above, all other terms and
conditions set forth in the Power Agreement, including all terms of Article 7 thereof, shall apply with full force and effect
to the CMP Standard Offer Sale.

In Witness Whereof, the parties have executed this Addendum to the Wholesale Power Sales Agreement this
14th day of December, 1999.

ENGAGE ENERGY US, LP                             ENERGY ATLANTIC, LLC

By   /s/ James C. Dyer, IV                                 By   /s/ Stephen A. Johnson

Name: James C. Dyer, IV                                  Name: Stephen A. Johnson

Title: Executive Vice President & C.O.O.         Title:   Vice President & General Counsel

Exhibit 10(ac)

Amendment

This Amendment is entered into effective as of March 10, 2000 by and between Energy Atlantic, LLC
("Atlantic"), a Maine Limited Liability Company, and Engage Energy US, L.P., a Delaware limited partnership
("Engage").  Atlantic and Engage are sometimes each referred to as a "Party" or collectively as "Parties".

Witnesseth:

WHEREAS, the Parties entered into an Wholesale Power Sales Agreement dated as of December 9, 1999 ("the
Agreement"); and

WHEREAS, the Parties also entered into an Addendum to the Wholesale Power Sales Agreement dated
December 9, 1999; and

WHEREAS, the Parties now desire to amend the Agreement to reflect different acquisition charges for
residential customers.

NOW THEREFORE, in consideration of the promises and mutual covenants set forth herein, the Parties agree as
follows:

1.  Item 7.2 (ii) (c) of the Agreement is hereby deleted and the following shall be substituted in its place:

"(c)  One-time Customer acquisition cost allocated to Atlantic in the amount of: $140 for each
non-residential retail customer whose load is estimated to be equal to or greater than 100 kw (annual
peak demand); $50 for each non-residential retail customer load is less than 100 kw (annual peak
demand); and $25 for each retail residential customer (as defined by the terms and conditions of the
serving transmission and distribution

utility). This item (c) shall not apply to any Retail Sales made pursuant to Standard Offer Service."

2.	Except as expressly varied by this Amendment, all terms, conditions, representations and covenants of
the Agreement shall remain in full force and effect.

3.	This Amendment represents the entire agreement and understanding of the parties with respect to the
subject matter, and supercedes all prior agreement and understandings with respect to the subject matter.

IN WITNESS WHEREOF, the Parties hereto have caused this Amendment to be executed in duplicate originals
and effective as of March 10, 2000.

ENGAGE ENERGY US, L.P 			ENERGY ATLANTIC, LLC

By: /s/ James C. Dyer, IV         			By: /s/ Stephen A. Johnson

Name: James C. Dyer, IV				Name: Stephen A. Johnson

Title: Executive Vice President & C.O.O.		Title: Vice President and General Counsel



Exhibit 10(ac)

Amendment

This Amendment is entered into effective as of August 1, 2000 by and between Energy Atlantic, LLC
("Atlantic"), a Maine Limited Liability Company, and Engage Energy US, L.P., a Delaware limited partnership
("Engage").  Atlantic and Engage are sometimes each referred to as a "Party" or collectively as "Parties".

Witnesseth:

WHEREAS, the Parties entered into an Wholesale Power Sales Agreement dated as of December 9, 1999 ("the
Agreement"); and

WHEREAS, the Parties also entered into an Addendum to the Wholesale Power Sales Agreement dated
December 9, 1999; and

WHEREAS, the Parties entered into an Amendment to the Wholesale Power Sales Agreement which such
Amendment was dated March 10, 2000; and

WHEREAS, the Parties now desire to amend the Agreement to reflect various changes to which the Parties have
agreed.

NOW THEREFORE, in consideration of the promises and mutual covenants set forth herein, the Parties agree as
follows:

1.	Sections 4.4(c) and 4.4 (d) shall be deleted in their entirety and replaced with the following:

"(c)   Underforecasting Errors will be treated differently depending on whether such Underforecasting Errors fall
within the Bandwidth or outside of the Bandwidth.

(i)  For Underforecasting Errors that fall outside of the Bandwidth, Atlantic will pay Engage an amount
equal to any penalties imposed on Engage as a result of Underforecasting Errors outside of the
Bandwidth.  In addition, Atlantic will pay Engage a sum equal to the positive difference, if any, between
the applicable Bulk Power Administrator's clearing price less the energy and capacity component of the
applicable Transfer Price,  multiplied by the quantity of underforecasted Electric Supply that is outside
the Bandwidth. If there is a negative difference between the applicable Bulk Power Administrator's
clearing price less the energy and capacity component of the applicable Transfer Price, the benefit shall
accrue solely to Engage. Any payments due Engage from Atlantic pursuant to this subparagraph shall be
treated as "Transfer Payments" for purposes of the priority of distribution from the Escrow Account.

(ii)  For Underforecasting Errors that fall within the Bandit,  the parties shall calculate the difference
between the  applicable Bulk Power Administrator's clearing price less the energy and capacity
component of the applicable Transfer Price, and multiply it by the quantity of underforecasted Electric
Supply.  If  the resulting number is positive, it shall be treated as Direct Incremental Costs to be included
in the calculation of Net Margin pursuant to Section 7.2. If the resulting number is negative, it shall be
treated as an offset to Direct Incremental Costs, and if all Direct Incremental Costs are offset, then as
Net Margin to be distributed according to the provisions of Article 7. All costs and penalties resulting
from Underforecasting Errors within the Bandwidth shall be treated as Direct Incremental Costs to be
included in the calculation of Net Margin pursuant to Section 7.2.

(d)	Overforecasting Errors will be treated differently depending on whether such Overforecasting Errors fall
within the Bandit or outside of the Bandit.



(i)	For Overforecasting Errors that fall outside of the Bandit, Atlantic will pay Engage an amount
equal to any penalties imposed on Engage as a result of overforecasting errors outside of the Bandwidth.
In addition, Atlantic will pay Engage a sum equal to the  positive difference, if any, between the energy
and capacity components of the applicable Transfer Price less the applicable Bulk Power
Administrator's Clearing Price, multiplied by the quantity of overforecasted Electric Supply that is
outside the Bandwidth.  If there is a negative difference between the energy and capacity components of
the applicable Transfer Price less the Bulk Power Administrator's clearing price, the benefit  shall
accrue solely to Engage. Any payments due Engage from Atlantic pursuant to this subparagraph shall be
treated as "Transfer Payments" for purposes of the priority of distribution from the Escrow Account.

2

(ii)	 For Overforecasting Errors that fall within the Bandit,  the parties shall calculate the difference
between the energy and capacity component of the applicable Transfer Price less the  applicable Bulk
Power Administrator's clearing price, and multiply it by the quantity of overforecasted Electric Supply.
If  the resulting number is positive, it shall be treated as Direct Incremental Costs to be included in the
calculation of Net Margin pursuant to Section 7.2. If the resulting number is negative, it shall be treated
as an offset to Direct Incremental Costs, and if all Direct Incremental Costs are offset, then as Net
Margin to be distributed according to the provisions of Article 7.All costs and penalties resulting from
Overforecasting Errors within the Bandwidth shall be treated as Direct Incremental Costs to be included
in the calculation of Net Margin pursuant to Section 7.2."

1.  The following sentence shall be added at the end of Section 7.2:

"The Parties acknowledge and agree that Central Maine Power Company ("CMP") in its capacity as a
billing and collection agent for Atlantic, shall offset amounts due CMP from EA for (a) Standard Offer
billing and collection charges, (b) disclosure label charges, and (c) a charge to reflect the change in
payment terms made effective in August, 2000 which will be calculated by utilizing a discount factor of
$0.335% (the "Discount Charge").  The Standard Offer billing and collection charges, and the disclosure
label charges will be treated as Direct Incremental Costs.  The Discount Charge, on the other hand, will
be deducted from Atlantic's allocation of Net Margin and added to Engage's allocation of Net Margin.
In addition, costs for Ancillary Services in Northern Maine which are paid by Atlantic shall be
distributed from the Escrow Account in the priority as set forth on the Distribution Request form that is
attached as Exhibit 4.2 to the parties' Escrow and Pledge Agreement, as amended."

2.  The first paragraph of Section 7.3 shall be deleted in its entirety and replaced with the following:

"Net Margin Distribution. For each calendar month after the commencement of Retail Sales by Atlantic
(each calendar month is a "Computation Period"), the Parties shall calculate the Net Margin on the
billed revenues invoiced for Retail Sales during that Computation Period no later than the 15th day after
the expiration of the Computation Period.  The Transfer Price, Direct incremental Costs, and Net Margin
calculated for each Computation Period (including all Uncompensated Amounts rolled forward from
previous Computation Periods) shall be distributed from all revenues deposited in the Escrow Account
through the 10th day of the month following each Computation Period.   The billed revenues

3

deposited in the Escrow Account shall be distributed in accordance with Section 7.2 within twenty (20)
days after the expiration of each Computation Period (the "Due Date"). In calculating the Net Margin,
the Parties shall calculate the Transfer Price and the Direct Incremental Costs of all Retail Sales made
for the last Computation Period. Any elements of the Transfer Price or the Direct Incremental Costs not
then ascertainable shall be estimated by the Parties and shall be adjusted in subsequent Computation
Periods to account for any difference between the estimates and the actual costs."

3.  The last sentence of Section 7.3 shall be deleted in its entirety and replaced with the following:

"Any Uncompensated Amounts shall accrue interest at the Interest Rate from the Due Date  until paid.
For purposes of the priority of distribution from the Escrow Account, such interest shall be distributed
according to the same priority as the underlying category to which it applies.  For example, interest on
uncompensated Transfer Payments shall be paid at the same priority as Transfer Payments, and interest
on uncompensated Direct Incremental Costs shall be paid at the same priority as Direct Incremental
Costs.  Engage shall have the right to direct the Escrow Agent to make distributions to Engage on each
Friday for the purpose of paying Uncompensated Amounts related to Transfer Pricing only".

4. Except as expressly varied by this Amendment, all terms, conditions, representations and covenants of the
Agreement shall remain in full force and effect.

5.      This Amendment represents the entire agreement and understanding of the parties with respect to the
subject matter, and supercedes all prior agreement and understandings with respect to the subject matter.

IN WITNESS WHEREOF, the Parties hereto have caused this Amendment to be executed in duplicate originals
and effective as of August 1, 2000.

ENGAGE ENERGY US, L.P 		ENERGY ATLANTIC, LLC

By: /s/ James C. Dyer, IV			By: /s/ Stephen A. Johnson

Name: James C. Dyer, IV			Name: Stephen A. Johnson

Title: Executive Vice President & C.O.O.	Title: Vice President and General Counsel

4

Exhibit 10(ac)

December 1, 2000

VIA FAX 207-764-4657

Calvin D. Deschene

President

Energy Atlantic LLC

P.O. Box 1148

Presque Isle, Maine 04769-1148

Re:	Wholesale Power Sales Agreement between Engage Energy America Corp. and Energy 	Atlantic L.L.C. dated December 9, 1999 ("Agreement").

Dear Cal:

The purpose of this letter is to set forth the understanding that was reached at our meeting on November 25, 2000 regarding certain
accounting matters under the above-referenced Agreement.  At that meeting it was agreed that:

1.	Until the parties are able to address Section 4.4 of the Agreement and the other matters 	identified in this letter, in a more formal amendment, effective December 1, 2000, the 	rights 	and obligations under Section 4.4 are suspended, except that
Energy Atlantic will provide 	accurate forecasts, but the parties will no longer settle imbalance amounts against these 	forecasts.

2.	The Portfolio Supply Charge of $1.00/MWh shall remain in force.

3.	It was clarified that ISO-NE Schedules 2 and 3 are "load-based charges".

It is the intent of the parties to further investigate the above matters, in addition to other matters (e.g. retail profit sharing margins,
incremental components of wholesale pricing, and development of a "wholesale block" concept, or alternative risk/reward sharing
mechanisms) and to formally amend the Agreement by January 31, 2001 to reflect the parties' resolution of such issues.

To evidence your agreement with the foregoing, please execute this letter in the space provided below.

Sincerely,

/s/Mark Stiers

Mark Stiers

President

AGREED AND ACCEPTED:

ENERGY ATLANTIC L.L.C.

/s/ Calvin D. Deschene

Calvin D. Deschene

Director

Exhibit 13

Maine Public Service --  Front Cover

Maine Public Service Company

We put a lot of energy into Northern Maine

(Photo)

The Dawn of a New Millennium

2000 Annual Report

Maine Public Service  --  Inside Front Cover

Maine Public Service Company

209 State Street

P. O. Box 1209

Presque Isle, Maine  04769-1209

Tel. No. (207) 768-5811    -    FAX No. (207) 764-6586

Home Page:  http://www.mainepublicservice.com

E-Mail:  mainepub@ mfx.net

Maine Public Service  1

Maine Public Service Company

The primary goal of Maine Public Service Company is to deliver reliable, economical electrical power to Northern Maine.
The Company is an investor-owned electric utility with two wholly-owned subsidiaries, Maine and New Brunswick Electrical
Power Company, Ltd., (Maine and New Brunswick) and Energy Atlantic, LLC, (EA).



The year 2000 was one of transition, as retail competition began on March 1, 2000.  As discussed on Page 5 of this Annual
Report, the Company no longer sells electricity, but continues to provide transmission and distribution service, while EA provides
electricity state-wide.

Maine Public Service Company is committed to providing highly reliable delivery services to more than 35,000 retail
electric customer accounts in a 3,600 square mile service territory, at the lowest possible cost.  The electrical system is strengthened
by interconnections with New Brunswick, Canada, allowing support from the New Brunswick system and indirectly from the
Hydro-Quebec system.  Major business activities in the area center around the production of agricultural and forest products.

|Table of Contents                                                  
|-------------------------------------------------------------------
|Profile and Table of Contents                                      
|President's Letter                                                 
|You Can Count On Us                                                
|Analysis of Financial Condition and Review of Operations - 2000    
|Shareholder Information                                            
|Five-Year Summary of Selected Financial Data                       
|Report of Independent Accountants                                  
|Financial Statements and Notes                                     
|Consolidated Financial Statistics                                  
|Consolidated Operating Statistics                                  
|Directors                                                          
|Executive Officers, Officer Changes, and Stock Transfer Information

(Photo)

The Dawn of a New Millennium  --  We began the year 2000 with an uneventful Y2K rollover and continued our journey down the
road of change, meeting many challenges associated with restructuring.  MPS has a tradition of providing first-rate customer
service and now, as always, we are fully focused on delivering energy and answering the electricity needs of Northern Maine.

Maine Public Service  2 and 3

President's Letter to our Shareholders and Employees

(Photo)

Paul  R. Cariani

President and CEO

The year 2000 produced impressive earnings for your Company of $3.34 per share compared to $2.48 in 1999.  Energy
Atlantic, LLC, (EA), our unregulated power marketing subsidiary, made a major contribution of $1.06 per share, whereas Maine
Public Service (MPS), the regulated delivery company, earned $2.28 per share on a stand-alone basis.  MPS had net income of $3.6
million versus $4.4 million in 1999, whereas EA had earnings of $1.7 million in 2000 compared to a $0.4 million loss in 1999.

Overall, the Company's return on equity was 13.8%.  However, earnings of the delivery company declined due to the
elimination of wholesale sales as a result of deregulation, effective March 1, 2000.  Although the allowed return on equity for the
delivery company is 10.7%, it earned 9.7%.  The Maine Public Utilities Commission (MPUC) has imputed an equity ratio of 51%
for ratemaking purposes, whereas the actual equity ratio for the delivery company was approximately 55%, after removing the
escrow balances from long-term debt, thereby reducing the earned return.  The Company did repurchase 45,000 shares of Common
Stock in 2000 and the stock buyback program is still in effect, if market conditions permit.

EA has a wholesale power supply contract with Engage Energy America, LLC, (Engage), and derives its earnings from
providing Standard Offer Service (SOS) in Central Maine Power's territory, as well as supplying customers as a Competitive
Electric Provider (CEP).  SOS expires on March 1, 2002, whereas the majority of CEP contracts expire in 2001.  The competitive
electric supply market continues to develop in Maine, however, at a slower pace than we would prefer.  Volatile energy markets
and contractual issues with Engage have hampered the ability of EA to expand its customer base in recent months.  This could
adversely affect EA's financial performance in 2001.  For more detailed information, please refer to Note 3 of the Notes to
Consolidated Financial Statements, "Energy Atlantic".

The solid financial performance in 2000 allowed the Company to increase the annual dividend from $1.20 to $1.28 on October
1, 2000.  Stock prices performed very well in our industry and our stock performed quite nicely as it increased 51.8% for the year.

Maine Yankee (MY) is moving forward with plant decommissioning after encountering some delays due to the bankruptcy of
Stone and Webster, the former Decommissioning Operation Contractor (DOC) of the Plant.  The MY management team will direct
the overall decommissioning of the Plant, including responsibilities of the DOC.

The Company also reached an agreement with the MPUC and Maine's Public Advocate regarding replacement power costs for
MY.  Under the Agreement, the Company will not incur any liability for 2001, however, for calendar year 2002 through 2004 the
Company will be subject to the auction price of independent power production contracts as a proxy for MY replacement power.
We cannot predict the amount, if any, of the liability resulting from the auction price exceeding the levels outlined in the MY
decommissioning study.  For more detailed information regarding this settlement, please refer to Note 11 of the Notes to
Consolidated Financial Statements, "Commitments, Contingencies and Regulatory Matters -- Maine Yankee".

The economy in our territory has slowed a bit.  However, McCain Foods, our largest customer, recently completed a major
expansion and is in the process of another major expansion.  Loring Commerce Centre has two major clients looking to locate
there, pending the improvement of market conditions.

Restructuring issues in California have raised concerns throughout the country, especially in states that have deregulated.
Deregulation in Northern Maine, which includes the MPS service territory, has worked reasonably well in the short time that it has
been in existence.  The MPS service territory is part of the Northern Maine Independent System Administrator (NMISA) and is not
part of the rest of New England administered by the Independent System Operator-New England (ISO-NE).  NMISA is a Federal
Energy Regulatory Commission (FERC) approved Regional Transmission Group (RTG) and provides for independent and non-discriminatory administration of transmission assets and the monitoring and operation of the energy markets in Northern Maine.
NMISA provides administrative oversight versus administrative and operational control that ISO-NE has over its participants.
Northern Maine has not been subject to the occasional price spikes seen in ISO-NE.  Northern Maine and New England do not have
the energy supply shortages as seen in California and the MPS service territory has generation available to serve its load, as well as
surpluses available from Canada.

While restructuring presents uncertainties in other parts of the industry, our delivery company continues to face a relatively
stable regulatory environment.  Later this year we will be filing a rate case, which is likely to include Performance Based
Ratemaking (PBR) with some sort of productivity incentive.  We look forward to working with the regulators to develop a PBR
plan that is beneficial to all and does not jeopardize the quality of service that our employees provide with pride.

The success of your Company is due to the quality and dedication of our workforce.  I appreciate the support of you, our
shareholders, and the dedication and efforts of our employees.  We appreciate your confidence and trust as owners of the Company.

Sincerely,

Paul R. Cariani

President and CEO

Maine Public Service  4

(Photo)

Delivering Superior Service  --  MPS line workers and electrical technicians are all trained experts, backed by years of experience.
In January, 2001, they were named  "County All-Stars" by WAGM-TV for their extraordinary efforts responding to system-wide
electrical outages caused by December high winds reaching gusts of over 70 mph.  (See photo at right)    MPS Company's
responsiveness can be attributed to individual dedication, willingness to endure wintery weather conditions, and many long, hard
hours.

You Can Count On Us

Over the years, the diligence and skills of our employees have earned MPS a well-deserved reputation for responsiveness to
customer needs.

(Photo)

Commitment to Excellence  --  When customers flip a switch, they expect the lights to go on.  MPS has an excellent record of
providing customers with that type of service, with reliability in excess of 99.97 %.  Nonetheless, we are committed to improving
this record  --  first by preventing interruptions of service and second by restoring service safely and as quickly as possible when
interruptions do occur.

(Photo)

A Stronger System  --  MPS enhances the reliability of its electrical system by making significant capital expenditures  to improve
substations and power lines.  This assures our customers greater reliability at increasingly lower operating costs.

Maine Public Service  5

(Photo)

Analysis of Financial Condition and Review of Operations - 2000

Electric Industry Restructuring

Begins March 1, 2000



Beginning with the 1995 Annual Report, the Company has reported the progress of Maine's electric industry restructuring and its
impact on shareholders and customers.  As required by law, the Company divested its generating assets in 1999 with the gain from
the sale of these assets deferred on our balance sheet to be used to offset stranded costs.  On March 1, 2000, the Company began
providing customers with transmission and distribution services only.  The associated changes affect many aspects of the
Company's financial and operational results in 2000, causing significant differences from previous year's results.  An
understanding of the following points will enhance comprehension of information presented in this Annual Report:

1.	Electric restructuring began on March 1, 2000 and, therefore, only two months of the results for 2000 were reported
in a manner consistent with prior years.  Comparisons of both prior and future periods to 2000 are complicated by
this mixture.

2.  	Since March 1, 2000, the Company has provided only transmission and distribution (T & D) services.  These
delivery services charged to our customers are determined by the Federal Energy Regulatory Commission (FERC)
for transmission services and by the Maine Public Utilities Commission (MPUC) for distribution services, using
traditional rate base, rate of return ratemaking principals used by the regulatory agencies.

3.  	The Company's revenue dollars decreased significantly after the beginning of retail competition, because the
customers now buy their power from energy providers.  Although the energy supply is reflected on its customers'
bills, the Company merely collects and remits to the supplier.  Until the Company sold its generating assets on June
8, 1999, related generating costs were expensed.  Following the generating asset sale and until March 1, 2000,
purchased electricity was expensed.  Revenues included the recovery of these costs in rates approved by the MPUC
and by FERC.  On the other hand, Energy Atlantic, LLC, (EA or Energy Atlantic) the Company's wholly-owned
unregulated marketing subsidiary, sells energy supply in the competitive retail market.



4.  	The Company's sales in MWH's are comparable to pre-March 1, 2000 results because the new T & D rates are still
applied to MWH's delivered.  The prior year data has been reclassified consistent with the new classifications,
effective March 1, 2000.

5.  	On March 1, 2000, the MPUC allowed the recovery of stranded costs from our customers.  The contractual amounts
paid to Wheelabrator-Sherman (W-S) above the market price received from an unrelated power marketer for the
output is recorded as stranded cost by the Company.  The entire contractual amount was reported as purchased
power expense prior to March 1, 2000.  The Seabrook amortization is also classified as stranded cost effective
March 1, 2000.  These MPUC approved charges to stranded costs are partially offset by the amortization of the
deferred gain from the generating asset sale.

Please refer to Note 11 of the Notes to Consolidated Financial Statements, "Commitments, Contingencies, and Regulatory Matters"
for details of the industry restructuring and the related rate orders of the MPUC.  Note 3 of the Notes to Consolidated Financial
Statements, "Energy Atlantic" describes the Company's wholly-owned unregulated subsidiary's activities in detail.

Maine Public Service  6

RESULTS OF OPERATIONS

Operating Revenues and Energy Deliveries

Consolidated revenues and MWH delivered for the years 2000, 1999, and 1998 are as follows:

Consolidated Revenues and Megawatt Hours Delivered*Dollars in Thousands*

|                                | 2000     | 1999      | 1998    
|------------------------------- | -------- | --------- | --------
|                                | Dollars  | MWH       | Dollars 
|Residential                     | $ 14,605 | 166,049   | $ 21,708
|Large
Commercial                | 6,111    | 171,023   | 10,596  
|Medium
Commercial               | 5,908    | 103,914   | 9,578   
|Small
Commercial                | 7,075    | 87,867    | 10,248  
|Other Retail                    | 783      | 3,259     | 885     
|Total
Regulated
Retail          | 34,482   | 532,112   | 53,015  
|Energy Atlantic Competitive    
|Energy Supply                   | 37,054   | 754,189   | -       
|Total Retail                    | 71,536   | 1,286,301 | 53,015  
|Sales for
Resale                | 1,798    | 38,010    | 12,536  
|Total
Deliveries of
Electricity | 73,334   | 1,324,311 | 65,551  
|Other
Operating
Revenues        | 2,130    |           | 1,905   
|Total
Operating
Revenues        | 75,464   |           | 67,456  
|Energy Atlantic Standard       
|Offer Service
Margin            | 2,774    |           | -       
|Total
Revenues                  | $78,238  |           | $67,456 



As discussed in "Electric Industry Restructuring Begins March 1, 2000", above, revenues in 2000 are not
comparable with previous years.  Beginning March 1, 2000, the Company provides transmission and
distribution services to our retail customers but no longer supplies electricity, whereas the Company's
wholly-owned subsidiary, Energy Atlantic, LLC, (EA), provides electricity at competitive rates.  Sales by the
Company under rates determined by the Maine Public Utilities Commission (MPUC) are referred to as
"Regulated Retail".  However, MWH deliveries continue to be comparable and, therefore, will be the focus of
the following analysis.  Total retail sales in 2000 were 1,286,301 MWH, an increase of 774,940 MWH and
795,827 MWH over 1999 and 1998, respectively.  The principal reason for this increase was EA's  retail sales
of 754,189 MWH, of which 674,291 MWH, or 89.4%, were made to two large industrial customers in Central
Maine Power's service territory.  Regulated retail sales were 532,112 MWH, which was 20,751 MWH (4.1%)
higher than 1999 and 41,638 MWH (8.5%) higher than 1998.  While residential sales decreased 4,432 MWH
(2.6%) compared to 1999, they increased 2,976 MWH (1.8%) compared to 1998.  The principal reason for this
fluctuation was the Company's conversion of residential customers from bi-monthly to monthly meter reading
in 1999.  This conversion was also principal reason for the 7,408 MWH increase in 1999 compared to 1998.
Without this one-time event, 2000's sales are more comparable to 1998.  Large commercial sales were
171,023 MWH in 2000, representing increases of 21,044 MWH (14.0%) and 24,003 MWH (16.3%) over 1999
and 1998, respectively, reflecting increased activity at our food processing and the lumber and wood products
customers.  Our largest customer, McCain Foods, Inc., completed a major expansion in 1999, which
contributed additional sales of approximately 17,000 MWH in 2000 compared to 1999.  Medium commercial
sales in 2000 were 103,914 MHW, reflecting increases of 4,793 MWH (4.8%) and 9,184 MWH (9.7%)
compared to 1999 and 1998, respectively, due to an increase in the commercial activity at the former Loring
Air Force Base.  Activity in the small commercial class

Maine Public Service  7

decreased by 703 MWH (.8%) to 87,867 MWH in 2000 compared to 1999, but 2000 sales were 5,394 MWH
(6.5%) more than 1998.  Sales for resale were 38,010 MWH in 2000, reflecting sales by the Company and EA
through March 1, 2000.  Sales in 1999 of 390,587 MWH represented an increase of 267,193 MWH over 1998,
principally EA's wholesale activity which began in 1999, partially offset by the termination of sales to Perth-Andover Light and Power in June 1999 with the sale of the Company's generating assets.

During 1996 and 1997, the Company entered into long-term discount contracts with five of its largest
customers.  All five of these customers produced evidence of hardship to continue operations in the area or
were investigating self-generation, criteria that the MPUC reviewed before approving these load-retention
contracts.  On August 4, 2000, the MPUC approved new contracts with two of these customers for up to
eleven years, retaining these valuable customers.  In addition, the MPUC authorized revenue recognition and
establishment of a regulatory asset for the difference between the amounts billed under these contracts and the
stranded costs being recovered in rates from these two customers, which totaled $380,000 in 2000, recorded
as other revenues.

The MPUC has jurisdiction over retail rates.  As discussed in the "Regulatory Proceedings -- MPUC
Approves Elements of Rates Effective March 1, 2000" section below, the MPUC approved rates for the
Company's Transmission and Distribution (T&D) utility as of March 1, 2000, exclusive of the energy supply,
now purchased by customers from competitive  energy providers or standard offer service.  Until February 29,
2000, the Company operated under a four-year rate plan which had granted rate increases of 4.4%, 2.9% and
3.9% effective January 1, 1996, February 1, 1997 and February 1, 1998, respectively.  For the final year of
the rate plan, the MPUC approved a stipulation allowing a 3.66% specified rate increase as of April 1, 1999.
Rather than increase customer rates, the MPUC allowed the recognition of these revenues as an offset to the
available value from the sale of the generating assets.  The 3.66% increase totaled $1,316,000 in 1999 and
$379,000 for the first two months of 2000, and has been recorded as other operating revenues.  Other
operating revenues were $2,130,000 in 2000, compared to $1,905,000 and $1,852,000 in 1999 and 1998,
respectively.  The $225,000 increase in 2000, compared to 1999, reflects a $483,000 increase in unbilled
revenue because of the 1999 transition to monthly meter reading, a $343,000 increase in wheeling revenues,
partially offset by a $557,000 decrease in the regulatory revenue adjustments, which were previously
discussed.  The Federal Energy Regulatory Commission (FERC) has jurisdiction over transmission rates.

As discussed in the "Energy Atlantic" section below, EA's Standard Offer Service Margin of
$2,774,000 in 2000, represents the accrued net margin of its Standard Offer Service (SOS) activity, recorded
as revenue beginning March 1, 2000.  The principal source of this margin is the SOS provided by EA to
approximately 525,000 residential and small commercial customer accounts in Central Maine Power's service
territory.

Operating Expenses

For the three-year period 1998-2000, energy supply and transmission and distribution operation and
maintenance expenses are as follows:

|                                               | *(Dollars in Thousands)*
|---------------------------------------------- | ------------------------
|                                               | 2000                    
|Energy Supply                                  |                         
|Purchased Power                                |                         
|Wheelabrator-Sherman                           | $2,567                  
|Maine Yankee                                   | 571                     
|Northeast Empire                               | 1,508                   
|Other Purchases                                | 2,398                   
|Energy Atlantic                                | 36,433                  
|Total Purchased Power                          | 43,477                  
|Deferred Fuel                                  | 114                     
|Net Purchased Power                            | 43,591                  
|Generation                                     |                         
|Fuel Expense                                   | **--**                  
|Other                                          | 2                       
|Total Generation                               | 2                       
|Total Energy Supply                            | $43,593                 
|T&D Operation and Maintenance                  |                         
|Transmission and Distribution                  | $3,219                  
|Customer Accounting and General
Administrative | 7,493                   
|Energy Atlantic                                | 1,351                   
|Other Oper. & Maint                            | $12,063                 
|Stranded Costs                                 |                         
|Wheelabrator-Sherman                           | $10,694                 
|Maine Yankee                                   | 2,727                   
|Seabrook                                       | 925                     
|Amortization of Gain from Asset Sale           | (5,440)                 
|Total Stranded Costs                           | $8,906                  

As discussed in "Electric Industry Restructuring Begins March 1, 2000", above, energy supply
expenses in 2000 are not comparable with previous years.  Energy supply is comprised of purchased power
and generation expenses.  Beginning March 1, 2000, the Company no longer supplies electricity to our retail
customers and, therefore, ceased purchasing power on that date.  The Company's wholly-owned unregulated
marketing subsidiary, Energy Atlantic, LLC, (EA), on the other hand, entered the retail market as an energy
provider throughout the State of Maine on March 1, 2000, after participating in the wholesale market prior to
February 29, 2000.  As discussed in the "Energy Atlantic" section below, EA's competitive energy provider
sales and purchase power expenses are recognized on a gross basis throughout 2000.

Energy supply expenses were $43,593,000 in 2000, an increase of $3,329,000 and $11,943,000 over
1999 and 1998, respectively.  As reflected in the table above, net purchased power expenses for 2000 were
$43,591,000, an increase of $4,518,000 over 1999.  Purchases by EA increased  $29,109,000 in 2000,
compared to 1999 principally due to EA's retail sales after March 1, 2000 as described above.  During 1999
and for the first two months of 2000, EA's sales were limited to bulk power sales.  As explained above, the
Company supplied power to its customers until February 29, 2000.  Purchases from

Maine Public Service  8

Wheelabrator-Sherman (W-S), Northeast Empire, other suppliers, as well as decommissioning
expenses for Maine Yankee, during the first two months were classified as Energy Supply expenses.
Payments continued after March 1, 2000 to W-S and Maine Yankee, but were classified as stranded costs, as
discussed below.  W-S purchases for 1999 were $14,205,000, a $375,000 or a 2.7% increase from 1998,
because of a 1.3% increase in output and a contractual price increase.  Maine Yankee expenses were
$3,760,000 in 1999, a decrease of $1,910,000 compared to 1998 reflecting higher decommissioning expenses
in 1998, an insurance refund in 1999 due to the curtailment of operations, and a FERC rate stipulation
approved in early 1999.  Purchases from Northeast Empire in 1999, principally Maine Yankee replacement
power, of $7,768,000 were 8.5% more than purchases in 1998.  Other purchases in 1999 of $7,619,000 were
$2,527,000 more than 1998, reflecting additional bulk power sales by the Company in 1999 and contractual
purchases from WPS-PDI after the sale of the generation assets.  Deferred fuel expense, a component of
purchased power, was a positive $114,000 in 2000, compared to a negative $1,603,000 and a negative
$2,234,000 in 1999 and 1998, respectively.  A positive deferred fuel expense indicates that amounts collected
through rates exceed current costs, which occurred during the first two months of 2000.  A negative deferred
fuel expense indicates expenses deferred to a future period when these costs will be collected in rates.  As
more fully discussed in Note 11 of the Notes to Consolidated Financial Statements, "Commitments,
Contingencies and Regulatory Matters -- Four-year Rate Stabilization Plan", the Company was allowed to
defer one-half of the Maine Yankee replacement power costs, offset by the savings from the amended
purchase power agreement with W-S until the termination of the plan on February 29, 2000.  Generation
expenses in 1998 were $2,132,000 and $1,191,000 until the generating assets were sold on June 8, 1999.

As a result of the changes in the Company's business on March 1, 2000, discussed above, the related
sources of energy also changed substantially.  Purchases by the Company in January and February of 2000
totaled 118,560 MWH, compared to 556,132 MWH and 501,007 MWH for the years 1999 and 1998,
respectively.  Please see discussion on stranded costs below for details about the Company's accounting for
energy provided by W-S after March 1, 2000.  EA's purchases in 2000 of 824,845 MWH, included 802,173
MWH of energy provided by Engage Energy America, LLC, (Engage), EA's sole provider of energy for its
retail activity, which began March 1, 2000.  The remainder of EA's purchases in 2000 were for wholesale
power marketing sales from other parties.  EA's purchases for standard offer service purchased from Engage,
described in "Energy Atlantic", below, are not reflected as purchases because that activity is recorded on a
net basis.

Transmission and distribution (T&D) expenses were $3,219,000 in 2000, an increase of $211,000 over
1999.  Load dispatching expenses in 2000 were $333,000 more than 1999, primarily due to fees paid to the
Northern Maine Independent System Administrator beginning on March 1, 2000.  In addition, a severe
windstorm in December, 2000 increased expenses by $125,000.  These increases were partially offset by a
$274,000 decrease in tree trimming expenses.  The $606,000 decrease in T&D expenses from 1998 to 1999
was principally due to the termination of a wheeling contract with NB Power, partially offset by a $302,000
increase in the tree trimming expenses.  Customer accounting and general administrative expenses were
$7,493,000 in 2000, an increase of approximately $250,000 over 1999 and 1998, principally due to wage
increases.  EA's other operation expenses were $1,351,000 in 2000, an increase of $314,000 over 1999,
primarily due to increased wages of $334,000 and bad debt expenses associated with retail sales activity in
2000, partially offset by a $197,000 decrease in wholesale transmission and ancillary service expenses.

The Company recognized $8,906,000 of stranded costs in 2000.  Beginning on March 1, 2000, as
detailed in the table above and discussed below in "Regulatory Proceedings -- MPUC Approves Elements of
Rates Effective March 1, 2000", the Company is now classifying certain expenses as stranded costs.  The
Wheelabrator-Sherman and Maine Yankee costs of $10,694,000 and $2,727,000, respectively, are comparable
to expenses recorded as purchased power prior to March 1, 2000.  The Seabrook cost of $925,000 represents
the amortization of the unrecovered costs beginning March 1, 2000 and is comparable to expenses previously
classified as amortization.  As stipulated, the Company is allowed to offset these stranded costs with the
amortization of the deferred gain from the generating asset sale of June 1999, described in detail in Note 11
of the Notes to Consolidated Financial Statements, "Commitments, Contingencies and Regulatory Matters --
Capacity Arrangements - Generating Asset Sale".

Interest expenses for 2000 were $2,459,000, compared to $4,236,000 and $4,327,000 for 1999 and
1998, respectively.  The decrease from 1999 to 2000 of $1,777,000 is primarily due to the redemption of
long-term debt with proceeds from the generating asset sale, as discussed in Note 9 of the Notes to
Consolidated Financial Statements, "Long-Term Debt", partially offset by increased short-term borrowing
interest costs in 2000 to meet working capital needs, accounting for $1,023,000 of the decrease.  The
Company was allowed to recognize $768,000 in stranded cost carrying charges in 2000 as a reduction to
interest expense and an increase to deferred fuel to be collected in future periods.  The $48,000 decrease in
Interest and Dividend Income in 2000 compared to 1999 was primarily due to a $342,000 decrease in interest
earned on generating asset sale proceeds, offset by a $243,000 increase in EA's interest income from their
escrow arrangement with Engage Energy America, LLC, and by interest earned on the proceeds of the tax-exempt borrowing beginning in October 2000.

Energy Atlantic

In January, 1999, Energy Atlantic, the Company's wholly-owned unregulated marketing subsidiary,
formally began operations.  This marketing subsidiary was  involved in wholesale energy transactions during
1999 and the first two months of 2000, and began selling to retail customers on March 1, 2000, the
commencement of retail competition in the State of Maine.  EA's net income was $1,688,000 for 2000,
compared to a loss of $354,000 for 1999.  The increase is primarily due to its new retail business.

Energy Atlantic provides standard offer service (SOS) and competitive energy supply (CES) to retail
customers, both of which utilize power provided via a contract with Engage Energy America, LLC, (Engage).
Revenues are received and expenses are paid directly by an escrow agent which is controlled by Engage.  EA
receives a percentage of the net profit from the sale of energy.  EA is the SOS provider for approximately
525,000 residential and commercial customer accounts in the Central Maine Power (CMP) service territory
and was awarded 20% of the medium non-residential customer base in the Company's service territory.  The
utilities bear SOS account collection risk, as they are required to remit the amounts billed 26 days after the
billing date to the escrow account mentioned above and maintain the billing and customer service
relationship.  EA records the

Maine Public Service 9

accrued net margin of the SOS activity as revenue in the financial statements.  EA's CES activity is
principally two large industrial customers in CMP's service territory, as well as residential and small non-residential customer accounts throughout Maine.  For CES sales, EA negotiates the price directly with the
customer, maintains customer service responsibility and has collection risk.  CES activity is recorded on a
gross basis to include the related revenues and purchased power expenses.

The contract between EA and Engage has recently been the subject of negotiations between the
parties.  On December 5, 2000, the Federal Energy Regulatory Commission (FERC) issued an order that would
increase the Installed Capacity (ICAP) Deficiency Charge in the New England market from $0.17 to $8.75 per
kw/month.  On January 9, 2001, FERC stayed this order subject to a rehearing.  Engage informed EA that the
proposed ICAP increase would dramatically increase Engage's cost of meeting commitments to EA's
customers, who are generally entitled to electrical power through a designated period at a fixed price.  In
December 2000, Engage sent EA a letter giving notice that it was invoking certain contract renegotiation
rights and setting forth its position that an increase of this magnitude would give it grounds to cancel its
contract with EA.  EA responded by stating its view that the contract requires Engage to sustain the market
risks of increases in the cost of supplying power and that the notice was in breach of the contract.  Without
agreeing with EA's position, Engage did withdraw its notice.  Engage has subsequently expressed the view
that it has multiple grounds to terminate the contract.  The parties have attempted to negotiate some
resolution of these matters with no success to date.  On March 7, 2001, FERC issued its order reinstating the
$8.75 per kw/month ICAP charge effective April 1, 2001.  As of this date, the Company is unable to predict
the effect of this order on the relationship between EA and Engage.

If Engage were to cease providing power at the previously-negotiated prices, EA would likely be
unable to find alternative sources of supply at those prices.  It is unclear whether and to what extent EA would
be required to absorb the increased costs associated with its customer contracts.  The Coastal Corporation, a
former affiliate of Engage, has provided a $35 million guaranty of performance by Engage.  Whether the
guaranty would be available would depend on whether Engage were determined to have breached the contract,
a question that likely would not be resolved except by litigation.  Moreover, the aggregate cost of supplying
power to EA's customers at the prices set forth in existing retail contracts could well exceed the amount of the
guaranty, in which case EA may not be able to meet its financial obligations.

EA's management is actively involved in seeking a resolution of this situation, but is unable to assess
the effect of these uncertainties on EA.  Resolution of these matters may depend on numerous factors beyond
EA's control, such as possible challenges to FERC's order, future actions of FERC in setting the ICAP rates,
future actions of the Maine Public Utilities Commission in reforming the SOS or providing some other
remedy, changes in the market price of electrical power, and future actions of Engage.  Nonperformance by
Engage under the contract could have a material adverse impact on the financial position and results of
operations of EA.  Management believes the risk of loss for MPS as parent would be the after-tax impact of its
investment in EA and accumulated earnings, which amounted to $.9 million and $.8 million, respectively, as
of December 31, 2000.  To date, Engage has continued to meet its prior commitments to supply power to EA
customers and make all required payments and the parties are continuing their discussion of this matter.

Until November 2000, EA was subject to risk in scheduling electric load in the New England retail
market in accordance with its contract with Engage.  A letter of agreement, dated December 1, 2000, to amend
the contract at that time, removed the penalties and benefits to EA resulting from under- and over-forecasts of
load and volatile market price changes.

Maine Yankee

The Company owns 5% of the Common Stock of Maine Yankee, which operated an 860 MW nuclear
power plant (the "Plant") in Wiscasset, Maine.  On August 6, 1997, the Board of Directors of Maine Yankee
voted to permanently cease power operations and to begin decommissioning the Plant.  The Plant experienced
a number of operational and regulatory problems and did not operate after December 6, 1996.  The decision to
close the Plant permanently was based on an economic analysis of the costs, risks and uncertainties associated
with operating the Plant compared to those associated with closing and decommissioning it.  The Plant's
operating license from the Nuclear Regulatory Commission (NRC) was due to expire on October 21, 2008.

The Maine Agreement for the decommissioning of Maine Yankee requires the Maine owners, (Central
Maine Power, Bangor Hydro-Electric Company and the Company) for the period from March 1, 2000 through
December 1, 2004, to hold their Maine retail ratepayers harmless from the amounts by which the replacement
power costs for Maine Yankee exceed the replacement power costs assumed in the report to the Maine Yankee
Board of Directors that served as a basis for the Plant shutdown decision, up to a maximum cumulative
amount of $41 million.  The Company's share of the maximum amount would be $4.1 million for the period.
For the year ended December 31, 2000, the Company selected the price based on the two year entitlement
auction which was allowed under the agreement.  Since this price was below the assumed replacement power
price, there was no liability for this period.  The Company again selected the two year entitlement auction
price for the year ended December 31, 2001, but on October 11, 2000, the Maine Agencies, (the MPUC and
the Office of the Public Advocate) rejected the Maine Owners' selection of the sales auction price as the
benchmark for calendar year 2001.  On December 11, 2000, in separate negotiations, the Company reached an
agreement in principal with the Maine Agencies.  Under this Agreement, the Company will incur no liability
for calendar year 2001.  For the calendar years 2002 through 2004, the Company will be required to use the
auction price as the appropriate proxy.  At this time, the Company cannot predict the auction price for 2002 to
2004 and, if it were to exceed the assumed replacement power price, how much, if any, of the maximum $4.1
million will be required to be recognized during these three years.

With the closing of Maine Yankee, a provision of the Company's rate plan allowing the deferral of
50% of the Maine Yankee replacement power costs went into effect on June 6, 1997.  Beginning in May, 1998,
Maine Yankee replacement power costs have been offset by net savings from the restructured Purchase Power
Agreement with Wheelabrator-Sherman, in accordance with the rate plan stipulation.

Maine Public Service  10

Beginning in April, 1999, the Company began amortizing an additional $150,000 per month as part of
a stipulation described in "Regulatory Proceedings -- Four-Year Rate Stabilization Plan", above.  As of
December 31, 2000, the Company has a deferred Maine Yankee replacement power cost balance of
approximately $3.0 million, in accordance with the rate plan.

On September 1, 1997, Maine Yankee estimated the sum of the future payments for the closing,
decommissioning and recovery of the remaining investment in Maine Yankee to be approximately $930
million, of which the Company's 5% share would be approximately $46.5 million.  In December, 1998, June,
1999 and again in September 2000, Maine Yankee updated its estimate of decommissioning costs based on the
Settlement.  Legislation enacted in Maine in 1997 calls for restructuring the electric utility industry and
provides for recovery of decommissioning costs, to the extent allowed by federal regulation, through the rates
charged by the transmission and distribution companies.  Based on the Maine legislation and regulation
precedent established by the FERC in its opinion relating to the decommissioning of the Yankee Atomic
nuclear plant, the Company believes that it is entitled to recover substantially all of its share of such costs
from its customers and, as of December 31, 2000, is carrying on its consolidated balance sheet a regulatory
asset and a corresponding liability in the amount of $28.1 million, which is the September, 1997 cost estimate
of $46.5 million discussed above reduced by the Company's post-September 1, 1997 cost-of-service payments
to Maine Yankee and reflects the cost  adjustments agreed to in the settlement.

The MPUC, on January 27, 2000, approved a Stipulation providing for the recovery of stranded
investment, which includes the Company's share of Maine Yankee decommissioning expenses, Maine Yankee
replacement costs, and the remaining Maine Yankee investment.

On May 4, 2000, Maine Yankee notified its decommissioning operations contractor, Stone & Webster
Engineering Corporation (Stone & Webster), that it was terminating its decommissioning operations contract
pursuant to the terms of the contract.  Subsequently, Stone & Webster notified Maine Yankee that it was
disputing Maine Yankee's grounds for terminating the contract.  On May 8, 2000, Stone & Webster announced
a proposed transaction in which it would transfer substantially all of its assets in exchange for an immediate
credit facility and other consideration, including cash and stock.  Stone & Webster said the credit facility was
intended to enable it to address its liquidity difficulties and continue to operate its businesses until the asset
sale was completed.  Stone & Webster also announced that it intended to seek bankruptcy court approval of
the asset sale and credit agreement.

On June 2, 2000, Stone & Webster filed a voluntary petition under Chapter 11 of the United States
Bankruptcy Code with the United States Bankruptcy Court for the District of Delaware.  By Sale Order dated
July 13, 2000, the Bankruptcy Court approved the sale of substantially all of Stone & Webster's assets to the
successful bidder in the Chapter 11 sale, The Shaw Group, Inc., (Shaw), for cash, stock, and the assumption
of certain liabilities of Stone & Webster, and the proposed transaction announced earlier by Stone & Webster
was terminated.  Stone & Webster reported that the Shaw transaction was effectively closed on July 14, 2000,
and that it would continue to operate as a Debtor-in-Possession subject to the supervision and orders of the
Bankruptcy Court.

Commencing in May, 2000, Maine Yankee entered into interim agreements with Stone & Webster in
order to allow decommissioning work to continue and avoid the adverse consequences of an abrupt or
inefficient demobilization from the Plant site.  After obtaining assignments of several subcontracts from
Stone & Webster, Maine Yankee at least temporarily assumed the general contractor role.  The
decommissioning of the Plant site continued throughout the year 2000, with major emphasis directed to
maintaining the schedule on critical-path projects such as construction of the ISFSI and preparation of the
Plant's reactor vessel for eventual shipment to an off-site disposal facility.  During this period Maine Yankee
evaluated its long-term alternatives for safely and efficiently completing the decommissioning, including
detailed proposals from prospective successor general contractors.  On January 26, 2001, Maine Yankee
announced its decision to reject the proposals and continue to manage the decommissioning project itself
without an external general contractor.

On June 30, 2000, Federal Insurance Company (Federal), which provided performance and payment
bonds in the amount of $37.6 million each in connection with the decommissioning operations contract, filed
a Complaint for Declaratory Judgement against Maine Yankee in the United States Bankruptcy Court for the
District of Delaware, which was subsequently transferred to the United States District Court in Maine.  The
Complaint, which seeks a declaration that Federal has no obligation to pay Maine Yankee under the bonds,
alleges that Maine Yankee improperly terminated the decommissioning operations contract with Stone &
Webster and failed to give proper notice of the termination to Federal under the contract, and that Federal,
therefore, had no further obligations under the bonds.

On August 24, 2000, Maine Yankee also filed a $78.2 million claim (later increased to $86.0 million)
in the Stone & Webster Bankruptcy Court proceeding in Delaware seeking to recover its additional costs
caused by Stone & Webster's contract default.  Maine Yankee expects the court hearings in both proceedings
to take place later in 2001.  Maine Yankee believes that its termination of the Stone & Webster contract was
proper and that it is entitled to recover such additional costs in the bankruptcy proceeding or under the bonds,
but cannot predict the outcome of the litigation.

In December 2000, Maine Yankee distributed approximately $20 million to its owners from proceeds
received as a result of the termination of Maine Yankee's membership in a nuclear industry mutual insurance
company.  The Company received its 5% ownership share, or $1.0 million, and recorded a regulatory liability,
awaiting rate treatment.

Earnings and Dividends

Earnings per share for 2000 were $3.34 based on net income available for Common Stock of
$5,300,632 and 1,588,009 average shares outstanding.  The Company's wholly-owned unregulated marketing
subsidiary, Energy Atlantic, contributed net income of $1,687,522, $1.06 per share, while the Company's core
business, transmission and delivery services, provided net income of $3,613,110, $2.28 per share.  For 1999,
earnings per share were $2.48 based on net income available for Common Stock of $4,005,556 and 1,617,250
average shares outstanding.  In 1999, in its first year of operations, EA had a net loss of $353,508, which
reduced earnings per share by $.22.  Earnings per share for 1998 were $1.39 based on net income available for
Common Stock of $2,252,915 and 1,617,250

Maine Public Service  11

average shares outstanding.  As discussed in the "Maine Yankee" section of this Annual Report, the decision
to close Maine Yankee in 1997 and the beginning of decommissioning resulted in additional costs, such as
termination benefits to former Maine Yankee employees, assessed to the Company in 1998 as capacity
charges.  These additional costs adversely impacted the Company's earnings in 1998 compared to 2000 and
1999.  For 2000, the Company's return on equity was 13.8% compared to 11.1% and 6.51% for 1999 and
1998, respectively.



During 1999, the Company sold its generating assets and deferred a net gain of $19.9 million.  In
accordance with the previously mentioned mega-case order for T&D rates, (see "Electric Industry
Restructuring Begins March 1, 2000", above) beginning March 1, 2000, the deferred gain is being amortized,
which significantly reduces other stranded cost revenue requirements.  However, in 1999 the Company did
recognize $389,000 of net income associated with excess deferred income taxes and unamortized investment
tax credits associated with the assets sold.

During the three year period, dividends have been increased  twice.  Your Board of Directors
increased the quarterly dividend from $.25 to $.30 per share effective with the October 1, 1999 payment.  One
year later, your Board increased the dividend to $.32 per share, an increase of $.02.  Dividends paid during
2000 were $1.22 per share compared to $1.05 and $1.00 for 1999 and 1998, respectively.

Liquidity

The accompanying "Statements of Consolidated Cash Flows" reflect the Company's liquidity and
financial strength.  The statements report the net cash flows generated from or used for operating, financing,
and investing activities.

In 2000, net cash flows provided by operations were $4.7 million.  During 2000, the Company
withdrew asset sale proceeds from the trustee of $19 million, using $15 million for the redemption of the
9.775% Series of first mortgage bonds and $2.1 million for the associated redemption premium on that debt.
In addition, the Company paid taxes on the generating asset sale of approximately $7.9 million.  During 2000,
as more fully explained in the "Capital Resources" section of this Annual Report, the Maine Public Utilities
Financing Bank issued $9 million of its tax-exempt bonds, the 2000 Series, on behalf of the Company to be
drawn for the reimbursement of issuance costs of $.3 million and for qualifying expenditures for distribution
property.  During 2000, $1.6 million was drawn from the trust account.  As of December 31, 2000, the
Company had approximately $7.5 million remaining in the tax-exempt bond trust fund for the 2000 Series to
be used for the construction of qualifying property.  As more fully explained in the "Capital Resources"
section of this Annual Report, the Company reinstated a stock buy back program during 2000 and spent $.9
million for 45,000 shares of Common Stock.  In 2000, the Company paid $1.9 in dividends and spent $4.7
million for electric plant.  During 2000, an additional $1.3 million was borrowed under the Company's short-term credit facilities.

The June 8, 1999 sale of the generating assets provided proceeds of $37.5 million which were
deposited with the first mortgage trustee in accordance with mortgage indentures.  Net cash flows provided by
operating activities for 1999 were $5.3 million.  A total of $18.0 million of the proceeds was deposited with
the first mortgage trustee, subsequently a $4.0 million drawdown was used for the final redemption of $2.5
million of the 9.6% Series of second mortgage bonds and a redemption of $1.4 million of the 1996 Series of
tax-exempt bonds.  In addition to the redemptions mentioned above, $1.3 million of scheduled principal
payments were made, for a total of $5.2 million in long-term debt retirements.  During 1999, the Company
paid $1.3 million in dividends and spent $4.8 million for electric plant.  The Company also withdrew the final
$.4 million from the proceeds held in trust from the 1996 tax-exempt bond issuance and decreased short-term
borrowings by $4.5 million with a portion of the asset sale proceeds.

The restructuring of the amended power purchase agreement with Wheelabrator-Sherman Energy
Company (W-S) as more fully discussed later in the "Capital Resources" section of this Annual Report was
the most significant financial activity in 1998.  Net cash flows used for operating activities for 1998 were
$2.1 million, which includes the $8.7 million payment to W-S under the terms of the new agreement.  To
finance this payment to W-S, the Company issued $11.5 million of long-term debt through the Finance
Authority of Maine (FAME) with $2.4 million held in escrow in accordance with the loan agreement with
FAME and the remaining proceeds used for financing costs.  During 1998, the Company made the final
sinking fund payment on the 7 1/8% Series of first mortgage bonds of $2.9 million, as well as $1.3 million in
sinking fund payments for a total of $4.2 million in long-term debt retirements.  During 1998, the Company
paid $2 million in dividends and spent $3.7 million for electric plant.  The Company also withdrew $1.9
million from the proceeds held in trust from the 1996 tax-exempt bond issuance and had additional short-term
borrowings of $900,000.  As of December 31, 1998, the Company had approximately $400,000 remaining in
the tax-exempt bond trust fund to be used for the construction of qualifying property.

For additional information regarding construction expenditures for 1998 to 2000 and anticipated
construction expenditures for 2001, see Note 11 of Notes to Consolidated Financial Statements,
"Commitments, Contingencies, and Regulatory Matters -- Construction Program".

To satisfy working capital requirements, the Company uses short-term borrowings from its revolving
credit agreement.  In October, 1999, the Company's credit agreement was reduced to $6 million.  The
agreement is secured by $6 million of first mortgage bonds and its due date has been extended to May, 2002.
In September, 2000, the Company obtained an additional $2.5 million unsecured line of credit for a period of
six months.  This additional line of credit was required to cover the high costs of the W-S power contract
during 2000.  At the end of 2000, the Company had $4.9 million of short-term debt compared to $3.6 million
and $8.1 million at the end of 1999, and 1998, respectively.  During 1998 to 2000, the interest rates on these
short-term borrowings were below the existing prime rate.  For additional information on the short-term credit
facility, see Note 6 of the Notes to Consolidated Financial Statements, "Short-Term Credit Arrangement".
Based on current projections, the Company estimates that operating cash flows will be sufficient to cover its
other sinking fund payments, construction activities, and other financial obligations.

Maine Public Service  12

Capital Resources

The sale of the Company's generating assets on June 1999, has significantly impacted the Company's
capital structure.  The after-tax proceeds from the sale of the generating assets and the liquidation of the
Canadian subsidiary were used to reduce the Company's debt.  In 1999, the Company reduced long-term debt
by $3.9 million, redeeming the outstanding second mortgage bonds of the 9.6% Series of $2.5 million and
$1.4 million of the 1996 Series of tax-exempt bonds for  property sold previously, financed with this tax-exempt issue.  In 2000, the Company used $1.9 million to reduce short-term borrowings and redeemed its
highest coupon debt, the 9.775% Series of first mortgage bonds of $15 million, and paid the associated early
redemption premium.

As more fully explained in the "Regulatory Proceedings-MPUC Approves Elements of Rates Effective
March 1, 2000", the deferred gain on the generating asset sale of approximately $19.9 million at the end of
1999 was amortized beginning March 1, 2000, to reduce stranded cost revenue requirements, principally the
power costs associated with the Wheelabrator-Sherman contract.  In accordance with the rate decision, $5.4
million of the gain was amortized during 2000.  In addition, $7 million was used to offset the remaining
unrecovered costs on Seabrook.  Based on the current ratemaking treatment, the deferred gain should be fully
amortized in 2002.

After several years of negotiations, the Company restructured its Power Purchase Agreement (PPA)
with the Wheelabrator-Sherman Energy Company (W-S).  Under the terms of the original PPA, the Company
was obligated to purchase the entire output up to 126,582 MWH  of the 17.6 MW biomass plant owned by W-S
through December 31, 2000.  The PPA could be renewed by either party for an additional fifteen years at
prices to be determined by mutual agreement or, absent mutual agreement, by the MPUC.  In October 1997,
the Company and W-S agreed to amend the PPA.  Under the terms of this agreement, W-S agreed to accept an
up-front payment of $8.7 million and reduce the price of purchased power by $10 million through December
31, 2000.  The Company and W-S agreed to renew the PPA for an additional six years at set prices.  In May
1998, the Company made the up-front payment of $8.7 million to W-S with a financing provided by the
Finance Authority of Maine (FAME).  This payment is reflected as a regulatory asset; and, based on the
MPUC rate order effective March 1, 2000, the Company will begin amortizing and recovering this stranded
cost in 2001.  The amended PPA helped relieve the financial pressure caused by the closure of Maine Yankee
in 1997 as well as the need for substantial increase in retail rates.

On May 29, 1998, FAME issued $11,540,000 of its Taxable Electric Rate Stabilization Revenue
Notes, Series 1998A (Maine Public Service Company) (the Notes) on behalf of the Company.  The Notes were
issued pursuant to, and are secured under, a Trust Indenture by and between FAME and Peoples Heritage
Bank, Portland, Maine, as Trustee (the Trustee), for the purpose of:  (i) financing the up-front payment to
Wheelabrator-Sherman of approximately $8.7 million, as required under an amended purchase power
agreement; (ii) for the Capital Reserve Fund, as required by FAME under their Electric Rate Stabilization
Program; and (iii) for issuance costs.  The Notes are limited obligations of FAME, payable solely out of the
trust estate available under the Indenture, principally the Loan Note and Loan Agreement with the Company
and the Capital Reserve Fund held by the Trustee.  The Company has issued $4 million of its first mortgage
bonds and $7.54 million of its second mortgage bonds as collateral for its performance under the Loan Note
issue pursuant to the Loan Agreement.  The Notes will bear interest at a Floating Interest Rate, initially at
5.7% per annum, and will be adjusted weekly.  On June 1, 1998, the Company purchased an interest rate cap
of 7% at a cost of $172,000, to expire June, 2008, to limit its interest rate exposure to quarterly U.S. LIBOR
rates.  At the end of 2000, the cumulative effective interest rate, including issuance costs and credit
enhancement fees, since issuance for this Series was 6.78%.

On October 19, 2000, the Maine Public Utilities Financing Bank (MPUFB) issued $9 million of its
tax-exempt bonds due October 1, 2025 (the 2000 Series) on behalf of the Company.  The proceeds have been
placed in trust to be drawn down for the reimbursement of issuance costs and for the construction of
qualifying distribution property.  As of December 31, 2000, approximately $7.5 million is available for
qualifying capital expenditures.  Pursuant to the long-term note issued under a loan agreement between the
Company and the MPUFB, the Company has agreed to make payments to the MPUFB for the principal and
interest on the bonds.  Concurrently, pursuant to a letter of credit and reimbursement agreement, the Company
caused a Direct Pay Letter of Credit for an initial term of nineteen months to be issued by The Bank of New
York for the benefit of the holders of such bonds.  To secure the Company's obligations under the letter of
credit and reimbursement agreement, the Company issued first and second mortgage bonds, in the amounts of
$5 million and $4.525 million, respectively.  The Company has the option of selecting weekly, monthly,
annual or term interest rate periods for the 2000 Series, and at issuance, selected the weekly interest period,
with an initial interest rate of 4.35%.  On November 17, 2000, the Company purchased an interest rate cap of
6% for this Series and the 1996 Series of tax-exempt bonds issued by the MPUFB with $13.6 million
outstanding for a total cost of $36,386.

The Company has the ability to finance through the issuance of Common and Preferred Stock.  The
Company is authorized to issue up to 3,000,000 shares of Common Stock.  In addition, the Company's articles
of incorporation authorized the issuance of 200,000 shares of Preferred Stock with the par value of $100 per
share and 200,000 shares of Preferred Stock with the par value of $25 per share.  The Company can also issue
second mortgage bonds of $14.3 million without bondable property additions.

Effective March 1, 2000, the Company is required to maintain a capital structure with 51% common
equity, in accordance with a stipulation approved by the MPUC on December 1, 1999 in the Company's rate
design and stranded cost recovery cases.  In anticipation of this requirement, the Company sought approval,
which the MPUC granted on November 17, 1999, to repurchase up to 500,000 shares of its Common Stock
over a five-year period through an open market program, which began in February 2000.  During 2000, the
Company purchased 45,000 shares under this program at a cost of $922,000.

Maine Public Service  13

Employees

At the end of 2000 and 1999, respectively, the Parent Company had 142 full-time employees.  The
Parent's Canadian subsidiary, Maine and New Brunswick Electrical Power Company, Ltd., (Maine and New
Brunswick) has had no employees since the generating asset sale on June 8, 1999.  Energy Atlantic, the
Parent's unregulated marketing subsidiary, had 11 full-time employees for 2000, compared to 10 for 1999.
Consolidated payroll costs were $6.7 million for 2000 and $6.8 million for 1999.

Local 1837 of the International Brotherhood of Electrical Workers ratified a three-year contract with
the Parent Company, effective on October 1, 1999.  The agreement included a 3.34% wage increase in the first
year and a 3.5% increase in each of the last two years of the new contract.



**Regulatory Proceedings**

Industry Restructuring

On May 29, 1997, legislation titled "An Act to Restructure the State's Electric Industry" was signed
into law by the Governor of Maine.  The principal provisions with accounting impact on the Company are as
follows:

1.	Beginning on March 1, 2000, all consumers of electricity have the right to purchase generation
services directly from competitive electricity suppliers who will not be subject to rate regulation.

2.	By March 1, 2000, the Company, Central Maine Power Company (CMP), and Bangor Hydro-Electric
Company (BHE) must divest themselves of all generation related assets and business functions except
for:

a)	contracts with qualifying facilities, such as the Company's power contract with Wheelabrator-Sherman (W-S), and conservation providers;

b)	nuclear assets, namely, the Company's investment in the Maine Yankee Atomic Power Company;

c)	facilities located outside the United States, i.e., the Company's hydro facility in New Brunswick,
Canada; and

d)	assets that the MPUC determines necessary for the operation of the transmission and distribution
services.  The MPUC can grant an extension of the divestiture deadline if the extension will
improve the selling price.  For assets not divested, the utilities are required to sell the rights to the
energy and capacity from these assets.  For more information about the Company's sale of its
generating assets, see Note 11 of the Notes to Consolidated Financial Statements, "Commitments,
Contingencies, and Regulatory Matters -- Capacity Arrangements", below.

3.	The Company will continue to provide transmission and distribution services which will be subject to
continued rate regulation by the MPUC.

4.	Maine electric utilities will be permitted a reasonable opportunity to recover legitimate, verifiable and
unmitigable costs that are otherwise unrecoverable as a result of retail competition in the electric
utility industry (so-called "stranded costs").  The MPUC shall determine these stranded costs by
considering:

a)	the utility's regulatory assets related to generation, i.e., the Company's unrecovered Seabrook
investment;

b)	the difference between net plant investment in generation assets compared to the market value for
those assets; and

c)	the difference between future contract payments and the market value of the purchased power
contracts, i.e., the W-S contract.

5.	The MPUC shall include in the rates to be charged by the transmission and distribution utility
decommissioning expenses for Maine Yankee.  In 2003, and every three years  thereafter until the
stranded costs are recovered, the MPUC shall review and adjust the stranded cost recovery amounts
and related transition charges.  However, the MPUC may adjust the amounts at any point in time that
they deem appropriate.  Since the legislation provides for our recovery of stranded costs by the
transmission and distribution company, the Company will continue to recognize existing regulatory
assets and plant costs as provided by Emerging Issues Task Force 97-4 "Deregulation of the Pricing of
Electricity" (EITF 97-4).

6.	Billing and metering services will be subject to competition beginning March 1, 2002, but permits the
MPUC to establish an earlier date, no sooner than March 1, 2000.  The implementation of this
provision was subsequently delayed, and the Company cannot predict when or if it will begin.

7.	All competitive providers of retail electricity must be licensed and registered with the MPUC and meet
certain financial standards, comply with customer notification requirements, adhere to customer
solicitation requirements and are subject to unfair trade practice laws.  Competitive electricity
providers must have at least 30% renewable resources in their energy portfolios, including hydro-electric generation.

8.	A standard offer service will be available, ensuring access for all customers to reasonably priced
electric power.  Unregulated affiliates of CMP and BHE providing retail electric power are prohibited
from providing more than 20% of the load within their respective service territories under the standard
offer service, while any unregulated affiliate of the Company does not have a similar restriction.

9. 	Employees other than officers, displaced as a result of retail competition will be entitled to certain
severance benefits and retraining programs.  These costs will be recovered through charges collected
by the regulated transmission and distribution company.

According to EITF 97-4, entities should cease to apply Statement of Financial Accounting Standards No.
71 (SFAS 71), "Accounting for the Effects of Certain Types of Regulations" when a deregulation plan is in
place and the terms are known.  With respect to the generation

Maine Public Service  14

portion of the Company's business, this occurred in the fourth quarter of 1999, when the terms where
substantially agreed upon by stipulations in the MPUC's proceeding on revenue requirements, rate design and
stranded costs in Docket 98-577.  This stipulation was approved by the MPUC on January 27, 2000.  As more
fully discussed in Note 11 of the Notes to Consolidated Financial Statements, "Commitments, Contingencies,
and Regulatory Matters -- Capacity Arrangements", the Company sold all generating assets on June 8, 1999.
Correspondingly, the Company adopted SFAS 101 "Regulated Enterprises - Accounting for the
Discontinuation of  Application of FASB Statement No. 71" for the generation segment of its business in the
fourth quarter of 1999.  SFAS 101 requires a determination of impairment of plant assets under SFAS 121
"Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of" and the
elimination of all effects of rate regulation that have been recognized as assets and liabilities under SFAS 71.
The Company has determined no such impairment exists.

The Company believes that its electric transmission and distribution operations continue to meet the
requirements of SFAS 71 and that regulatory assets associated with those operations, as well as any
generation-related costs that the MPUC has determined to be recoverable from ratepayers, also meet the
criteria.  At December 31, 2000, $77.5 million of regulatory assets remain on the Company's books.  These
assets will be amortized over various periods in accordance with the MPUC approved Phase II filing.

For further discussion of the specific impacts of the industry restructuring on the Company and related
ratemaking activity, see "MPUC Approves Elements of Rates Effective March 1, 2000", below.

MPUC Approves Elements of Rates Effective March 1, 2000

On October 14, 1998, and subsequently amended on February 9, 1999, August 11, 1999, and December 15,
1999, the Company filed its determination of stranded costs, transmission and distribution costs, and rate
design with the MPUC.  The Company's amended testimony supported its $95.7 million estimate of stranded
costs, net of available value from the sale of the generating assets, when deregulation occurred on March 1,
2000.  The major components include the remaining investment in Seabrook, the above-market costs of the
amended power purchase agreement and recovery of fuel expense deferrals related to Wheelabrator-Sherman,
the obligation for remaining operating expenses and recovery of the Company's remaining investment in
Maine Yankee, and the recovery of several other regulatory assets.

On October 15, 1999, the Company filed with the MPUC a Stipulation resolving the revenue requirement
and rate design issues for the Company's Transmission and Distribution (T&D) utility.  This Stipulation was
signed by the Public Advocate and approval was recommended by the MPUC Staff.  Under the Stipulation, the
Company's total annual T&D revenue requirement of $16,640,000, went into effect on March 1, 2000.  This
revenue requirement includes a 10.7% return on equity with a capital structure based on 51% common equity.
The Stipulation further provided that the precise level of stranded cost recovery could not be determined until
final determination of all costs associated with the sale of the Company's generating assets, but did set forth
some general principles concerning the Company's ultimate stranded costs recovery, including agreement that
the major components of the Company's stranded costs are legitimate, verifiable and unmitigable, and
therefore subject to recovery in rates.  Furthermore, the Stipulation allowed the 3.66% foregone revenue
increase as a result of a rate plan Stipulation approved by the MPUC in its April 6, 1999 Order in Docket 98-865 to be recovered through a reduction in the deferred gain on the asset sale.  The Stipulation also provided
that the Company's recovery of unamortized investment tax credits and excess deferred income taxes
associated with the Company's generating assets must await a final determination ruling from the IRS, which
ruling was sought by Central Maine Power Company (CMP).  On December 1, 1999, the MPUC approved the
October 15, 1999 Stipulation, as described above.  In early January, 2000, CMP received its ruling from the
IRS which concluded that the unamortized investment tax credits and excess deferred income taxes associated
with the sale of the generating assets could not be used to reduce customer rates without violating the tax
normalization rules for public utilities.  Therefore, in 1999, the Company recognized these excess deferred
taxes in income, which amounted to an increase in net income of approximately $389,000.

On January 27, 2000, the MPUC approved a Stipulation in Phase II of Docket No. 98-577 that provided
for the recovery in rates of the Company's stranded investment.  The major element of the Phase II Stipulation
was the $12.5 million of stranded investment recoverable annually beginning March 1, 2000.  This revenue
requirement includes a return on unrecovered stranded investment based on the capital structure approved by
the MPUC in its December 1, 1999 Order.  The approved capital structure consists of 51% common equity
with an authorized return on equity of 10.7%.  The Phase II Stipulation also allowed the Company to offset its
unrecovered stranded investment in Seabrook by approximately $7 million, (details provided in chart in Note
11 of the Notes to Consolidated Financial Statements, "Capacity Arrangements -- Generating Asset Sale",
below) representing an amount equal to 35% of the available value from the sale of the generation assets.  The
parties to the Phase II Stipulation also resolved several rate design issues, principally the elimination of the
inclining block rate for residential customers.  In addition, the Company was granted several accounting
orders incorporating certain accounting methodologies used in determining the elements of stranded costs.
On August 4, 2000, the MPUC authorized the Company to record the difference between the approved
contracts for two large industrial customers and their current special discount rates, designed for customer
retention, as revenue and a regulatory asset.  During 2000, this flexible pricing adjustment resulted in
recognition of $380,000 of revenues and a corresponding regulatory asset.  The annual revenue requirement
associated with the recovery of stranded costs will be reviewed at least every three years.  The Company
expects to file annual revenue requirements with the MPUC in the Fall of 2001 to determine rates for the next
rate period.

WPS Complaint

On October 30, 2000, WPS Energy Services (WPS), a Competitive Electricity Provider (CEP) offering
retail sales of electricity in the Company's service territory, filed a Complaint (Docket No. 00-894) against
the Company as well as a Petition to Alter or Amend the MPUC's September 2, 1998 Order in Docket No. 98-138.

The Complaint alleges that the Company has violated various provisions of Chapter 304 of the MPUC's
Regulation governing relations between the Company and all CEPs, including the

Maine Public Service  15

Company's own marketing subsidiary, Energy Atlantic, LLC, (EA).  According to the Complaint, various of
the Company's employees have engaged in conduct that either awards EA a competitive advantage over other
CEPs or has burdened WPS with an unfair disadvantage relative to EA.  These allegations include such
practices as denying WPS information made available to EA, or providing EA with information about WPS's
customers that is not available publicly.  The Company does not believe it has in any way violated any
provisions of Chapter 304 and has so argued to the MPUC.

In its September 2, 1998 Order in Docket No. 98-138 authorizing the formation of EA, the Commission
allowed the Company and EA to share the services of certain employees under certain conditions on the
grounds that such sharing was in the public interest and would not have any anti-competitive effect on the
retail market for electricity.  WPS claims that the sharing does not conform to the conditions set forth in the
Order and that, in any event, the Commission should now find such sharing not in the public interest, thereby
amending its original September 2, 1998 Order.

The Complaint and Petition to Amend the September 2, 1998 Order, in addition to requesting a
prohibition on the sharing of certain employees, also seeks a formal investigation of the Complaint, penalties
for any violations of the Commission's rules and certain specific relief for violations of Chapter 304.

The Company believes the Complaint and Petition are completely without merit and are motivated by EA's
recent competitive successes against WPS in the local retail electricity market.  The Company intends to
vigorously contest the matter at the MPUC, but cannot predict the outcome of this proceeding.

**Generating Asset Sale

On June 8, 1999 the Company sold its generating assets to WPS Power Development, Inc.  The sale of the
assets, 91.8 megawatts of generating capacity, for $37.4 million was required by the State's electric industry
restructuring law.  For further information, see Note 11 of the Notes to Consolidated Financial Statements,
"Commitments, Contingencies, and Regulatory Matters -- Capacity Arrangements - Generating Asset Sale".

Four-Year Rate Stabilization Plan

The Maine Public Utilities Commission (MPUC) approved a stipulation on November 13, 1995 that
established a multi-year rate plan, effective January 1, 1996 through March 1, 2000.  The plan provided our
customers with predictable rates and shared operating risks and benefits between the Company's shareholders
and customers.  For further information, see Note 11 of the Notes to Consolidated Financial Statements,
"Commitments, Contingencies, and Regulatory Matters -- Four-Year Rate Stabilization Plan".

Restructured Agreement with Wheelabrator-Sherman

On December 22, 1997, the MPUC approved an amended purchase power agreement between the
Company and Wheelabrator-Sherman, a 17.6 MW biomass plant.  The agreement has helped relieve the
financial pressure caused by the closure of Maine Yankee, as well as the need for substantial increases in its
retail rates.  For further information, see Note 11 of the Notes to Consolidated Financial Statements,
"Commitments, Contingencies, and Regulatory Matters -- Capacity Arrangements - Wheelabrator-Sherman".



Open Access Transmission Tariff

On March 31, 1995, the Company filed an open access transmission tariff with the Federal Energy
Regulatory Commission (FERC).  This tariff provides fees for various types and levels of transmission and
transmission-related services that are required by transmission customers.  The tariff, as filed, substantially
increases some of the fees for transmission services and provides separate fees for various transmission-related services.  On May 31, 1995, the FERC approved the filed tariff, subject to refund.  The filing was
vigorously contested by the Company's wholesale customers.  In April, 1996, the FERC issued Order 888, a
final rule on open transmission access and stranded cost recovery.  As a result, the Company refiled its tariff
on July 9, 1996 to comply with the Order.  Utilities are required to file tariffs under which they would provide
transmission services, comparable to that which they provide themselves, to third parties on a non-discriminatory basis.  On December 22, 1998, FERC issued its order establishing new tariffs for the Company.
Based on the FERC order, the Company reflected the $1.2 million refunds as liabilities as of December 31,
1998 and made the payments to these customers on May 20, 1999.

**Forward-Looking Statements

The above discussion may contain "forward-looking statements", as defined in the Private Securities
Litigation Reform Act of 1995, related to expected future performance or our plans and objectives.  Actual
results could potentially differ materially from these statements.  Therefore, there can be no assurance that
actual results will not materially differ from expectations.

Factors that could cause actual results to differ materially from our projections include, among other
matters, electric utility restructuring; future economic conditions; changes in tax rates, interest rates or rates
of inflation; and developments in our legislative, regulatory, and competitive environment.

Shareholder Information

General

The Company's Common Stock is listed and traded on the American Stock Exchange.  As of December 31,
2000 and 1999, Common Stock shares issued and outstanding were 1,572,898 and 1,617,250, respectively.  As
of December 31, 2000, shares were held by 1,075 shareholders or nominees in forty-six states, the District of
Columbia, Canada, and the United Kingdom.

The annual meeting of shareholders is held each year on the second Tuesday in May at the Company's
headquarters in Presque Isle.  Market price and dividend information relative to the two most recent calendar
years are shown in the tabulation on the following page.

Maine Public Service  16

Income Tax Status of 2000 Dividends

The Company has determined that the Common Stock dividends paid in 2000 are fully taxable for
federal income tax purposes.  These determinations are subject to review by the Internal Revenue Service, and
shareholders will be notified of any significant changes.

|                | Market Price | Dividends
Paid | Dividends
Declared
|--------------- | ------------ | -------------- | ------------------
|                | High         | Low            | Per Share         
|2000           
|First Quarter   | $18          | $16            | $  .30            
|Second Quarter  | $20.75       | $17.38         | .30               
|Third Quarter   | $25.60       | $20.25         | .30               
|Fourth Quarter  | $27.13       | $23.75         | .32               
|Total Dividends |              |                | $1.22             
|1999           
|First Quarter   | $16-1/8      | $13-1/8        | $  .25            
|Second Quarter  | $17-7/8      | $12-7/8        | .25               
|Third Quarter   | $19-1/8      | $17-7/16       | .25               
|Fourth Quarter  | $19          | $16-1/2        | .30               
|Total Dividends |              |                | $1.05             

Dividends declared within the quarter are paid on the first day of the succeeding quarter.

Five-Year Summary of Selected Financial Data

|                                             | 2000         | 1999             | 1998             | 1997             | 1996            
|-------------------------------------------- | ------------ | ---------------- | ---------------- | ---------------- | ----------------
|Revenues                                     | $78,238,279  | $67,456,117      | $56,626,906      | $55,072,196      | $57,264,165     
|Net Income (Loss)
Available for Common
Stock | $5,300,632   | $4,005,556       | $2,252,915       | $(2,177,137)     | $2,110,694      
|Net Income (Loss) Per
Share of Common
Stock  | $3.34        | $2.48            | $1.39            | $(1.35)          | **$1.31**       
|Dividends Per Share of Common Stock:        
|Declared Basis                               | $1.24        | **$1.10**        | **$1.00**        | **$1.00**        | **$1.84**       
|Paid Basis                                   | $1.22        | **$1.05**        | **$1.00**        | **$1.21**        | **$1.84**       
|Total Assets                                 | $150,969,376 | **$171,548,480** | **$164,295,548** | **$163,480,739** | **$117,192,566**
|Long-Term Debt
Outstanding                   | $35,990,000  | **$42,015,000**  | **$47,190,000**  | **$39,805,000**  | **$41,120,000** 
|Less amount due
within one year              | $1,050,000   | **$25,000**      | **$1,275,000**   | **$4,155,000**   | **$1,315,000**  
|Long-Term Debt                               | $34,940,000  | **$41,990,000**  | **$45,915,000**  | **$35,650,000**  | **$39,805,000** 

Maine Public Service  17

Report of Independent Accountants

To The Directors and Shareholders of

MAINE PUBLIC SERVICE COMPANY:

In our opinion, the accompanying consolidated balance sheets and statements of
capitalization and the related consolidated statements of income, common shareholders'
equity and cash flows present fairly, in all material respects, the financial position of Maine
Public Service Company and its Subsidiaries as of December 31, 2000 and 1999, and the
results of their operations and their cash flows for each of the three years in the period
ended December 31, 2000 in conformity with accounting principles generally accepted in
the United States of America.  These financial statements are the responsibility of the
Company's management; our responsibility is to express an opinion on these financial
statements based on our audits.  We conducted our audits of these statements in accordance
with auditing standards generally accepted in the United States of America, which require
that we plan and perform the audit to obtain reasonable assurance about whether the
financial statements are free of material misstatement.  An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in the financial statements,
assessing the accounting principles used and significant estimates made by management,
and evaluating the overall financial statement presentation.  We believe that our audits
provide a reasonable basis for the opinion expressed above.

/s/ PricewaterhouseCoopers, L.L.P.

PricewaterhouseCoopers, L.L.P.

Portland, Maine

February 9, 2001, except for Note 3 for which the date is March 7, 2001

***Maine Public Service  18*

MAINE PUBLIC SERVICE COMPANY AND SUBSIDIARIES

Statements Of Consolidated Income

|                                                           | Year Ended December 31,
|---------------------------------------------------------- | -----------------------
|                                                           | 2000                   
|Revenues                                                   |                        
|Operating Revenues                                         | $75,464,430            
|EA Standard Offer Service Margin                           | 2,773,849              
|Total Revenues                                             | 78,238,279             
|Operating Expenses                                         |                        
|Energy Supply                                              | 43,593,025             
|T&D Operation & Maintenance                                | 12,063,273             
|Depreciation                                               | 2,310,252              
|Amortization of Stranded Costs                             | 8,905,707              
|Amortization                                               | 297,360                
|Taxes other than Income                                    | 866,259                
|Provision for Income Taxes                                 | 2,891,160              
|Total Operating Expenses                                   | 70,927,036             
|Operating Income                                           | 7,311,243              
|Other Income (Deductions)                                 
|Equity in Income of Associated Companies                   | 334,136                
|Interest and Dividend Income                               | 854,093                
|Allowance for Equity Funds used During Construction        | 35,809                 
|Provision for Income Taxes                                 | (598,896)              
|Other - Net                                                | (176,732)              
|Total                                                      | 448,410                
|Income Before Interest Charges                             | 7,759,653              
|Interest Charges                                           |                        
|Long-Term Debt & Notes Payable                             | 3,245,138              
|Less Stranded Cost Carrying Charge                         | (767,751)              
|Less Allowance for Borrowed Funds Used During Construction | (18,366)               
|Total                                                      | 2,459,021              
|Net Income Available for Common Stock                      | $5,300,632             
|Basic and Diluted Earnings Per Share of Common Stock       | $3.34                  
|Average Shares Outstanding                                 | 1,588,009              

See Notes to Consolidated Financial Statements

Maine Public Service  19

MAINE PUBLIC SERVICE COMPANY AND SUBSIDIARIES

Statements of Consolidated Cash Flows

|                                                                                   | Year Ended December 31,
|---------------------------------------------------------------------------------- | -----------------------
|                                                                                   | 2000                   
|Cash Flow From Operating Activities                                               
|Net Income                                                                         | $5,300,632             
|Adjustments to Reconcile Net Income to Net Cash Provided by (Used For) Operations:
|Depreciation                                                                       | 2,310,252              
|Amortization                                                                       | 1,178,684              
|Amortization of Deferred Gain from Asset Sale                                      | (5,439,750)            
|Deferred Income Taxes - Net                                                        | 4,228,605              
|Deferred Investment Tax Credits and Excess Deferred
              Income Taxes     | (35,539)               
|Allowance for Funds Used During Construction                                       | (54,175)               
|Income on Tax-Exempt Bonds - Restricted Funds                                      | (97,105)               
|Change in Deferred Regulatory and Debt Issuance
        Costs                      | 464,808                
|Wheelabrator-Sherman Contract Restructuring                                        | -                      
|Gain on Sale of Miscellaneous Property                                             | (205,237)              
|Change in Deferred Revenues                                                        | -                      
|Change in Benefit Obligations                                                      | 86,395                 
|Change in Current Assets and Liabilities:                                          |                        
|Accounts Receivable and Unbilled Revenue                                           | (4,305,676)            
|Deferred Fuel and Purchased Energy Cost                                            | -                      
|Other Current Assets                                                               | (217,420)              
|Accounts Payable                                                                   | 2,308,867              
|Accrued Taxes and Interest                                                         | (799,475)              
|Other Current Liabilities                                                          | 2,581                  
|Other-Net                                                                          | (44,735)               
|Net Cash Flow Provided By (Used For) Operating
Activities                          | 4,681,712              
|Cash Flow From Financing Activities                                               
|Dividend Payments                                                                  | (1,948,371)            
|Purchase of Common Stock                                                           | (921,763)              
|Bond Issuance Costs                                                                | (322,755)              
|Drawdown (Deposit) of Asset Sale Proceeds with
    Trustee, net                    | 18,957,051             
|Deposit - FAME Capital Reserve Fund                                                | -                      
|Deposit of Land Sale Proceeds with Trustee                                         | (211,400)              
|Issuance of Long-Term Debt                                                         | 9,000,000              
|Retirements on Long-Term Debt                                                      | (15,025,000)           
|Premium on Retirement of Long Term Debt                                            | (2,105,470)            
|Short-Term Borrowings, Net                                                         | 1,300,000              
|Net Cash Flow Provided By (Used For) Financing
Activities                          | 8,722,292              
|Cash Flow From Investing Activities                                               
|Investment in Restricted Funds                                                     | (9,000,000)            
|Drawdown of Tax-Exempt Bond Proceeds                                               | 1,612,305              
|Proceeds from Sale of Generating Assets                                            | -                      
|Payment of Taxes on Generating Asset Sale Deferred
             Gain               | (7,853,047)            
|Proceeds from Sale of Miscellaneous Property                                       | 208,319                
|Investment in Electric Plant                                                       | (4,746,144)            
|Net Cash Flow Provided By (Used For) Investing
Activities                          | (19,778,567)           
|Increase (Decrease) in Cash and Cash Equivalents                                   | (6,374,563)            
|Cash and Cash Equivalents at Beginning of Year                                     | 6,985,273              
|Cash and Cash Equivalents at End of Year                                           | $610,710               
|Supplemental Disclosure of Cash Flow Information:                                 
|Cash Paid During the Year For:                                                    
|Interest                                                                           | $3,198,874             
|Income Taxes  (2000, 1999 and 1998 are net of tax refunds of                      
|$499,201, $208,836 and $2,083,783, respectively)                                   | $7,505,312             

*See Notes to Consolidated Financial Statements*

Maine Public Service 20 and 21

MAINE PUBLIC SERVICE COMPANY AND SUBSIDIARIES

Consolidated Balance Sheets

|                                                                                                                  | December 31,
|----------------------------------------------------------------------------------------------------------------- | ------------
|                                                                                                                  | 2000        
|Assets                                                                                                           
|Utility Plant                                                                                                    
|Electric Plant in Service                                                                                         | $78,824,891 
|Less Accumulated Depreciation                                                                                     | 36,289,791  
|Net Electric Plant in Service                                                                                     | 42,535,100  
|Construction Work-in-Progress                                                                                     | 1,467,818   
|Total                                                                                                             | 44,002,918  
|Investment in Associated Companies                                                                                | 3,907,818   
|Net Utility Plant and Investments in Associated Companies                                                         | 47,910,736  
|Current Assets:                                                                                                  
|Cash and Cash Equivalents                                                                                         | 610,710     
|Deposits with Trustee-Asset Sale                                                                                  | -           
|Accounts Receivable (less allowance for uncollectible accounts of
$334,690 in 2000 and $215,000 in 1999)          | 9,140,199   
|Unbilled Revenue                                                                                                  | 3,358,301   
|Inventory                                                                                                         | 465,314     
|Income Tax Refund Receivable                                                                                      | 761,037     
|Prepayments                                                                                                       | 231,597     
|Total                                                                                                             | 14,567,158  
|Regulatory Assets:                                                                                               
|Uncollected Maine Yankee Decommissioning Costs                                                                    | 28,055,741  
|Recoverable Seabrook Costs (less accumulated amortization and write-offs in 2000, $35,968,399; 1999, $29,735,499) | 17,218,611  
|Regulatory Assets - SFAS 109 & 106                                                                                | 8,101,240   
|Deferred Fuel and Purchased Energy Costs                                                                          | 11,977,239  
|Regulatory Asset - Power Purchase Agreement Restructuring                                                         | 8,705,750   
|Unamortized Debt Expense (less accumulated amortization of $735,776 in
2000 and $880,497 in 1999)                 | 3,234,805   
|Deferred Regulatory Costs, less accumulated amortization                                                          | 233,381     
|Total                                                                                                             | 77,526,767  
|Other Assets:                                                                                                    
|Restricted Investments (at cost, which approximates market)                                                       | 9,876,037   
|Miscellaneous                                                                                                     | 1,088,678   
|Total                                                                                                             | 10,964,715  
|Total Assets                                                                                                      | $150,969,376

|*See Notes to Consolidated Financial Statements*           
|-----------------------------------------------------------
|                                                           
|                                                           
|Capitalization and Liabilities                             
|Capitalization (see accompanying statements):              
|Common Shareholders' Equity                                
|Long-Term Debt                                             
|Total                                                      
|Current Liabilities:                                       
|Long-Term Debt Due Within One Year                         
|Notes Payable to Banks                                     
|Accounts Payable                                           
|Accounts Payable - Associated Companies                    
|Accrued Employee Benefits                                  
|Deferred Income Taxes Related to Deferred Fuel Costs       
|Dividends Declared                                         
|Customer Deposits                                          
|Taxes Accrued                                              
|Interest Accrued                                           
|Total                                                      
|Deferred Credits:                                          
|Uncollected Maine Yankee Decommissioning Costs             
|Income Taxes                                               
|Investment Tax Credits                                     
|Deferred Gain & Related Accounts-Generating Asset Sale     
|Miscellaneous                                              
|Total                                                      
|Commitments, Contingencies and Regulatory Matters (Note 11)
|Total Capitalization and Liabilities                       

Maine Public Service 22

MAINE PUBLIC SERVICE COMPANY AND SUBSIDIARIES

Statement of Consolidated Common Shareholders' Equity

|                               |           | Par Value   | Paid-in | Retained    | Treasury    
|------------------------------ | --------- | ----------- | ------- | ----------- | ------------
|                               | Shares    | Issued      | Capital | Earnings    | Stock       
|Balance, January 1, 1998       | 1,617,250 | $13,070,750 | $38,317 | $26,902,671 | $(5,714,376)
|Net Income                     |           |             |         | 2,252,915   |             
|Dividends:                    
|Common Stock ($1.00 per
share) |           |             |         | (1,617,250) |             
|Balance, December 31, 1998     | 1,617,250 | 13,070,750  | 38,317  | 27,538,336  | (5,714,376) 
|Net Income                     |           |             |         | 4,005,556   |             
|Dividends:                    
|Common Stock ($1.10 per
share) |           |             |         | (1,778,975) |             
|Balance, December 31, 1999     | 1,617,250 | 13,070,750  | 38,317  | 29,764,917  | (5,714,376) 
|Net Income                     |           |             |         | 5,300,632   |             
|Dividends:                    
|Common Stock ($1.24 per
share) |           |             |         | (1,966,523) |             
|Stock Repurchased:            
|Common Stock                   | (45,000)  |             |         |             | (921,763)   
|Treasury Stock Reissued        | 648       |             | 1,351   | (1,314)     | 13,960      
|Balance, December 31, 2000     | 1,572,898 | $13,070,750 | $39,668 | $33,097,712 | $(6,622,179)

*See Notes to Consolidated Financial Statements*

Maine Public Service 23

MAINE PUBLIC SERVICE COMPANY AND SUBSIDIARIES

Consolidated Statements of Capitalization

|                                                                              | December 31,                   
|----------------------------------------------------------------------------- | -------------------------------
|                                                                              | 2000                           
|Common Shareholders' Equity                                                  
|Common Stock, $7 Par Value-Authorized 3,000,000 Shares in 2000 and
1999;      |                                
|Issued 1,867,250 Shares in 2000 and 1999                                      | $13,070,750                    
|Paid-In-Capital                                                               | 39,668                         
|Retained Earnings                                                             | 33,097,712                     
|Total                                                                         | 46,208,130                     
|Treasury Stock - Total Shares of 294,352 in 2000 and 250,000 in 1999,
at cost | (6,622,179)                    
|Total                                                                         | $39,585,951                    
|Long-Term Debt                                                               
|First Mortgage and Collateral Trust Bonds:                                   
|7.95% Due Serially through 2003-Interest Payable, March 1 and
September 1*    | $1,850,000                     
|9.775% Due Serially through 2011-Interest Payable, March 1 and
September 1*   | -                              
|Maine Public Utility Financing Bank, Public Utility Revenue Bonds:           
|Refunding Series 1996: Due 2021 - Variable Interest Payable Monthly          
|                                                                              | (5.0% as of December 31, 2000) 
|Series 2000: Due 2025 - Variable Interest Payable Monthly                    
|                                                                              | (5.0% as of December 31, 2000) 
|Finance Authority of Maine:                                                  
|1998 Taxable Electric Rate Stabilization                                     
|Revenue Notes: Due 2008 - Variable Interest Payable Monthly                  
|                                                                              | (6.65% as of December 31, 2000)
|Total Outstanding                                                             | 35,990,000                     
|Less - Amount Due Within One Year                                             | 1,050,000                      
|Total                                                                         | $34,940,000                    

Current Maturities and Redemption Requirements for the Succeeding Five Years and Thereafter Are as Follows:

Long-Term Debt:

|2001       | $1,050,000 
|---------- | -----------
|2002       | $1,175,000 
|2003       | $3,085,000 
|2004       | $1,450,000 
|2005       | $1,625,000 
|Thereafter | $27,605,000

** Subject to early redemption premiums as defined in the bond indentures.*    **

*See Notes to Consolidated Financial Statements*

Maine Public Service  24

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1.  ACCOUNTING POLICIES

**Regulations**

Maine Public Service Company (the Company) is subject to the regulatory authority of the Maine Public Utilities Commission
(MPUC) and the Federal Energy Regulatory Commission (FERC).  As a result of the ratemaking process, the applications of
accounting principles by the Company differ in certain respects from applications by non-regulated businesses.

**Consolidation and Basis of Presentation**

The accompanying consolidated financial statements include the accounts of the Company, its wholly-owned Canadian
subsidiary, Maine and New Brunswick Electrical Power Company, Limited, (Maine and New Brunswick), and its wholly-owned
marketing subsidiary, Energy Atlantic, LLC, (EA).  All intercompany balances and transactions have been eliminated in
consolidation.

The preparation of financial statements in conformity with generally accepted accounting principles requires management to
make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and
liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period.
Actual results could differ from those estimates.

**Foreign Currency Translation**

The functional currency of Maine and New Brunswick is the U.S. dollar.  Accordingly, translation gains and losses are
included in other income.  Income and expenses of Maine and New Brunswick are translated at rates of exchange prevailing at the
time the income is earned or the expenses are incurred, except for depreciation which is translated at rates existing on the applicable
in-service dates.  Assets and liabilities are translated at year-end exchange rates, except for utility plant which is translated at rates
existing on the applicable in-service dates.

******Deferred Fuel and Purchased Energy Costs**

Certain Wheelabrator-Sherman fuel costs and the sharing provisions for Maine Yankee replacement power costs were deferred
for future recovery as defined in the Company's rate plan until March 1, 2000.  All other fuel and purchased power costs were
expensed as incurred.

******Revenue Recognition**

Operating revenues include sales billed on a cycle billing basis and estimated unbilled revenues for electric service rendered
prior to the normal billing cycle.  In October 1999, in preparation for retail competition, the Company converted all residential
customers to monthly meter reading while the majority had been previously read bi-monthly.

On May 31, 1995, the FERC approved a temporary wheeling tariff in the Company's open access transmission filing.  The
Company has not recognized the additional revenues from the temporary tariff, since the increase in the rates charged to our
transmission customers are subject to refund.  On December 22, 1998, the FERC issued an order on the rates in question.  The
Company issued a refund of approximately $1.2 million in 1999.

In July, 2000, the Company began recording the difference between the approved tariff rate for two large industrial customers
and their current special discount rates, under contracts approved by the MPUC, as accrued revenue.  The resulting deferred asset
will be subsequently collected as rates are approved by the MPUC.

On April 1, 1999, the Company began recognizing revenue from the foregone 3.66% rate increase, with an offset to the
available value from the sale of the generating assets in accordance with the rate stipulations approved by the MPUC.  During 2000
and 1999, $379,000 and $1.3 million, respectively, of revenue was recognized under these Stipulations, as discussed further in Note
11, "Commitments, Contingencies and Regulatory Matters -- Four-Year Rate Stabilization Program".  During 2000, $380,000 was
recognized as revenue as a flexible pricing adjustment, as described in Note 11, "Commitments, Contingencies and Regulatory
Matters -- MPUC Approves Elements of Rates Effective March 1, 2000".

**Utility Plant**

Utility plant is stated at original cost of contracted services, direct labor and materials, as well as related indirect construction
costs including general engineering, supervision, and similar overhead items and allowances for the cost of equity and borrowed
funds used during construction (AFUDC).  The cost of utility plant which is retired, including the cost of removal less salvage, is
charged to accumulated depreciation.  The cost of maintenance and repairs, including replacement of minor items of property, are
charged to maintenance expense as incurred.  The Company's property, with minor exceptions, is subject to first and second
mortgage liens.

Costs which are disallowed or are expected to be disallowed for recovery through rates are charged to income at the time such
disallowance is probable.

**Depreciation and Amortization**

Utility plant depreciation is provided on composite basis using the straight-line method.  The composite depreciation rate,
expressed as a percentage of average depreciable plant in service, was approximately 3.37%, 2.74%, and 2.99% for 2000, 1999,
and 1998, respectively.

Bond issuance costs and premiums paid upon early retirements are amortized over the terms of the related debt.  Recoverable
Seabrook costs and deferred regulatory expenses are amortized over the period allowed by regulatory authorities in the related rate
orders.  Recoverable Seabrook costs are being amortized principally over thirty years (Note 11).

**Income Taxes**

Statement of Financial Accounting Standards No. 109 (SFAS 109), "Accounting for Income Taxes", requires an asset and
liability approach to accounting and reporting income taxes.  SFAS No. 109 prohibits net-of-tax accounting and requires the
establishment of deferred taxes on all differences between the tax basis of assets or liabilities and their basis for financial reporting.

The Company has deferred investment tax credits and amortizes the credits over the remaining estimated useful life of the
related utility plant.

The Company records regulatory assets or liabilities related to certain deferred tax liabilities or assets, representing its
expectation that, consistent with current and expected ratemaking, those taxes will be recovered from or returned to customers
through future rates.

Investments in Associated Companies

The Company records its investments in Associated Companies (see Note 4) using the equity method.

*Maine Public Service  25*

**Pledged Assets**

The Common Stock of  Maine and New Brunswick is pledged as additional collateral for the first and second mortgage and
collateral trust bonds of the Company.  In December, 1999, a liquidating dividend in the amount of $14.8 million, representing
after-tax proceeds from the sale of the generating assets was paid by Maine and New Brunswick to the Company.  In accordance
with the mortgage indentures, the dividend net of withholding taxes was deposited with the first mortgage trustee.

**Inventory**

Inventory is stated at average cost.

**Cash and Cash Equivalents**

For purposes of the Statements of Consolidated Cash Flows, the Company considers all highly liquid securities with a maturity,
when purchased, of three months or less to be cash equivalents.

**Reclassifications**

Certain reclassifications have been made to the 1999 and 1998 financial statement amounts in order to conform to the 2000
presentation.

**Accounting Pronouncements**

In June 1998, the FASB issued SFAS No. 133 "Accounting for Derivative Instruments and Hedging Activities".  In accordance
with the pronouncement, the Company will adopt SFAS 133 effective January 1, 2001.  The Company is in the process of
reviewing its business activities, but does not expect this adoption to have any material impact to the Company's financial position
or results of operations.  The Company has also reviewed its revenue recognition policies and concluded they comply with the
provisions of Staff Accounting Bulletin 101, "Revenue Recognition in Financial Statements" and EITF No. 99-19, "Recording
Revenue Gross as a Principal versus Net as an Agent".

2.  INCOME TAXES

A summary of Federal, Canadian and State income taxes charged (credited) to income is presented below. Income tax
provisions included in "Operating Expenses" reflect taxes applicable to revenues and expenses allowable for ratemaking purposes,
as well as for the operations of EA, the Company's unregulated Subsidiary.  The tax effect of items not included in rate base or
normal operating activities are allocated as "Other Income (Deductions)".  Current income taxes recorded on the Company's  and
Maine and New Brunswick's deferred gain from the generating asset sale are offset by corresponding deferred income taxes.

|                                                                                | 2000       | 1999         | 1998      
|------------------------------------------------------------------------------- | ---------- | ------------ | ----------
|Current income taxes                                                            | $(853,466) | $13,305,318  | $539,204  
|Deferred income taxes                                                           | 4,379,061  | (9,857,507)  | 1,698,938 
|Investment credits, net                                                         | (35,539)   | (48,861)     | (70,200)  
|Total income taxes                                                              | $3,490,056 | $3,398,950   | $2,167,942
|Allocated to:                                                                  
|Operating income                                                                | $2,891,160 | $  3,529,542 | $2,118,095
|Other income                                                                    | 598,896    | (130,592)    | 49,847    
|Total                                                                           | $3,490,056 | $3,398,950   | $2,167,942
|The effective income tax rates differ from the U.S. statutory  rate as follows:
|                                                                                | 2000       | 1999         | 1998      
|Statutory rate                                                                  | 34.0%      | 34.0%        | 34.0%     
|Excess Canadian taxes                                                           | (1.7)      | .7           | 2.7       
|Amortization of recoverable Seabrook
costs                                      | 2.6        | 3.8          | 6.4       
|State income taxes                                                              | 5.9        | 10.1         | 5.9       
|Other                                                                           | (1.1)      | (2.7)        | --        
|Effective rate                                                                  | 39.7%      | 45.9%        | 49.0%     

The elements of deferred income tax expense (credit) are as follows:

|                                                  | 2000   | 1999      | 1998    
|------------------------------------------------- | ------ | --------- | --------
|Temporary Differences at Statutory Rates:        
|Seabrook - costs                                  | $(188) | $  (200)  | $  (200)
|Liberalized depreciation                          | 109    | 46        | 57      
|AFUDC-borrowed funds                              | (6)    | (38)      | (38)    
|Deferred fuel****                                 | 196    | 455       | 987     
|Deferred regulatory expense                       | (44)   | (113)     | (124)   
|Unbilled and deferred revenue****                 | **--** | --        | 360     
|Accrued pension and postretirement benefits       | 31     | 723       | (112)   
|Wheelabrator-Sherman power purchase restructuring | 1,344  | 1,344     | 784     
|Generating Asset Sale                             | 2,320  | (11,956)  | --      
|Reacquired debt                                   | 765    | --        | --      
|Other                                             | (148)  | (119)     | (15)    
|Total temporary differences - statutory rates     | $4,379 | $ (9,858) | $ 1,699 

Maine Public Service  26

The Company has not accrued U.S. income taxes on the undistributed earnings of Maine and New Brunswick (ME&NB),
as the withholding taxes due on the distribution of any remaining amount would be principally offset by foreign tax credits.
Dividends received from ME&NB were $16,281,664 in 1999 and $678,426 in 1998, while no dividends were received in 2000.  In
addition to $1,481,644 of regular dividends in 1999, ME&NB paid a liquidating dividend of $14,800,000.  The regular dividends
exceeded earnings by $932,304 in 1999.

The following summarizes accumulated deferred income taxes established on temporary differences under SFAS 109 as of
December 31, 2000 and 1999.

|                                       | *****(Dollars in Thousands)*
|-------------------------------------- | ----------------------------
|**                                     | ******2000**                
|****Seabrook                           | $9,511                      
|Property                               | 6,516                       
|Regulatory expenses                    | (13)                        
|Deferred fuel                          | 4,472                       
|Generating asset sale                  | (2,551)                     
|Wheelabrator-Sherman Up-front payment  | 3,473                       
|Pension and post-retirement benefits   | (175)                       
|Other                                  | 187                         
|Net accumulated deferred  income taxes | $21,420                     

3.  ENERGY ATLANTIC

In January, 1999, Energy Atlantic, the Company's wholly-owned unregulated marketing subsidiary, formally began operations.
This marketing subsidiary was  involved in wholesale energy transactions during 1999 and the first two months of 2000, and began
selling to retail customers on March 1, 2000, the commencement of retail competition in the State of Maine.  As evidenced by the
following table, EA's net income was $1,688,000 for 2000, compared to a loss of $354,000 for 1999.  The increase is primarily due
to its new retail business.

Energy Atlantic provides standard offer service (SOS) and competitive energy supply (CES) to retail customers, both of which
utilize power provided via a contract with Engage Energy America, LLC, (Engage).  Revenues are received and expenses are paid
directly by an escrow agent which is controlled by Engage.  EA receives a percentage of the net profit from the sale of energy.  EA
is the SOS provider for approximately 525,000 residential and commercial customer accounts in the Central Maine Power (CMP)
service territory and was awarded 20% of the medium non-residential customer base in the Company's service territory.  The
utilities bear SOS account collection risk, as they are required to remit the amounts billed 26 days after the billing date to the
escrow account mentioned above and maintain the billing and customer service relationship.  EA records the accrued net margin of
the SOS activity as revenue in the financial statements.  EA's CES activity is principally two large industrial customers in CMP's
service territory, as well as residential and small non-residential customer accounts throughout Maine.  For CES sales, EA
negotiates the price directly with the customer, maintains customer service responsibility and has collection risk.  CES activity is
recorded on a gross basis to include the related revenues and purchased power expenses.

The contract between EA and Engage has recently been the subject of negotiations between the parties.  On December 5, 2000,
the Federal Energy Regulatory Commission (FERC) issued an order that would increase the Installed Capacity (ICAP) Deficiency
Charge in the New England market from $0.17 to $8.75 per kw/month.  On January 9, 2001, FERC stayed this order subject to a
rehearing.  Engage informed EA that the proposed ICAP increase would dramatically increase Engage's cost of meeting
commitments to EA's customers, who are generally entitled to electrical power through a designated period at a fixed price.  In
December 2000, Engage sent EA a letter giving notice that it was invoking certain contract renegotiation rights and setting forth its
position that an increase of this magnitude would give it grounds to cancel its contract with EA.  EA responded by stating its view
that the contract requires Engage to sustain the market risks of increases in the cost of supplying power and that the notice was in
breach of the contract.  Without agreeing with EA's position, Engage did withdraw its notice.  Engage has subsequently expressed
the view that it has multiple grounds to terminate the contract.  The parties have attempted to negotiate some resolution of these
matters with no success to date.  On March 7, 2001, FERC issued its order reinstating the $8.75 per kw/month ICAP charge
effective April 1, 2001.  As of this date, the Company is unable to predict the effect of this order on the relationship between EA
and Engage.

If Engage were to cease providing power at the previously-negotiated prices, EA would likely be unable to find alternative
sources of supply at those prices.  It is unclear whether and to what extent EA would be required to absorb the increased costs
associated with its customer contracts.  The Coastal Corporation, a former affiliate of Engage, has provided a $35 million guaranty
of performance by Engage.  Whether the guaranty would be available would depend on whether Engage were determined to have
breached the contract, a question that likely would not be resolved except by litigation.  Moreover, the aggregate cost of supplying
power to EA's customers at the prices set forth in existing retail contracts could well exceed the amount of the guaranty, in which
case EA may not be able to meet its financial obligations.

EA's management is actively involved in seeking a resolution of this situation, but is unable to assess the effect of these
uncertainties on EA.  Resolution of these matters may depend on numerous factors beyond EA's control, such as possible
challenges to FERC's order, future actions of FERC in setting the ICAP rates, future actions of the Maine Public Utilities
Commission in reforming the SOS or providing some other remedy, changes in the market price of electrical power, and future
actions of Engage.  Nonperformance by Engage under the contract could have a material adverse impact on the financial position
and results of operations of EA.  Management believes the risk of loss for MPS as parent would be the after-tax impact of its
investment in EA and accumulated earnings, which amounted to $.9 million and $.8 million, respectively, as of December 31, 2000.
To date, Engage has continued to meet its prior commitments to supply power to EA customers and make all required payments
and the parties are continuing their discussion of this matter.

Until November 2000, EA was subject to risk in scheduling electric load in the New England retail market in accordance with
its contract with Engage.  A letter of agreement, dated December 1, 2000, to amend the contract at that time, removed the penalties
and benefits to EA resulting from under- and over-forecasts of load and volatile market price changes.

*Maine Public Service  27*

The Company has determined that EA's activity and related energy contracts are considered non-trading in accordance with
EITF 98-10 "Accounting for Companies Involved in Energy Trading and Risk Management Activities".

The Company adopted Statement of Financial Accounting Standards (FAS) No. 133, "Accounting for Derivative Investments
and Hedging Activities" on January 1, 2001.  The Company has reviewed EA contracts and does not expect there will be material
impact to financial results as a result of this adoption.  During the quarter ended March 31, 1999, the Company adopted FAS No.
131, "Disclosure about Segments of an Enterprise and Related Information", which became applicable as a result of the start-up of
Energy Atlantic.  The accounting policies of the segments are the same as those described in Note. 1 of the Notes to Consolidated
Financial Statements, "Summary of Significant Accounting Policies".  The Company provides certain administrative support
services to Energy Atlantic, which are billed to that entity at cost, based on a combination of direct charges and allocations.  The
Company is organized on the basis of products and services.  The Company's reportable segments include the electric utility
portion of the business, consisting of Maine Public Service Company (MPS) and Maine and New Brunswick Electrical Power
Company, Limited, (ME&NB), and the energy marketing portion of the business, consisting of Energy Atlantic.  In June, 1999,
ME&NB sold its generating assets and ceased operations.

|                                      | Twelve Months Ended December 31,
|------------------------------------- | --------------------------------
|                                      |                                 
|(Dollars in Thousands)                |                                 
|                                      | EA                              
|Operating Revenues                    | $38,021                         
|EA Standard Offer Service
Margin      | 2,774                           
|Total Revenues                        | 40,795                          
|Operations & Maintenance
Expense      | 38,167                          
|Taxes                                 | 1,113                           
|Total Operating Expenses              | 39,280                          
|Operating Income (Loss)               | 1,515                           
|Other Income & Deductions             | 247                             
|Income (Loss) Before Interest
Charges | 1,762                           
|Interest Charges                      | 74                              
|Net Income (Loss)                     | $1,688                          
|Total Assets as of December
31, 2000  | $6,385                          

**4.  INVESTMENTS IN ASSOCIATED COMPANIES**

The Company owns 5% of the Common Stock of Maine Yankee Atomic Power Company (Maine Yankee), a jointly-owned
nuclear electric power company, and 7.49% of the Common Stock of the Maine Electric Power Company (MEPCO), a jointly-owned electric transmission company.  For additional information, see Note 11, "Commitments, Contingencies, and Regulatory
Matters -- Capacity Arrangements" regarding the closing and decommissioning of Maine Yankee.

Dividends received during 2000, 1999, and 1998 from Maine Yankee were $470,000, $453,750, and $108,750, respectively,
and from MEPCO $9,061, $207,974, and $7,249, respectively.  Substantially all earnings of Maine Yankee and MEPCO are
distributed to investor companies.  Condensed financial information (unaudited) for Maine Yankee and MEPCO is as follows:

(Dollars in Thousands)

|                                       | Maine Yankee | MEPCO   
|-------------------------------------- | ------------ | --------
|                                       | 2000         | 1999    
|**Earnings**                          
|Operating revenues                     | $43,813      | $69,439 
|Earnings applicable to Common
Stock    | $4,640       | $4,863  
|Company's equity share of net
earnings | $232         | $243    
|**Investment**                        
|****Total assets                       | $915,097     | $998,308
|Less:                                 
|Preferred stock                        | 15,000       | 15,000  
|Long-term debt                         | 40,800       | 48,000  
|Other liabilities and deferred
credits | 788,703      | 860,330 
|Net assets                             | $70,594      | $74,978 
|Company's equity in net assets         | $3,530       | $3,749  

Maine Public Service 28

**5.  INVESTMENT IN JOINTLY-OWNED UTILITY PLANT**

As more fully explained in Note 11, "Commitments, Contingencies, and Regulatory Matters -- Capacity Arrangements",
the Company sold its 3.3455% ownership interest in a jointly-owned utility plant, W. F. Wyman Unit No. 4 (Wyman), an oil-fired
generation plant on June 8, 1999, as required by the Maine utility industry restructuring legislation.  The Company's proportionate
share of the direct expenses of Wyman are included in the corresponding operating expenses in the statements of consolidated
operations.  The Company's share in the plant at December 31, 1998 was $6,987,000, less accumulated depreciation of $4,654,000.

**6.  SHORT-TERM CREDIT ARRANGEMENTS**

The Company has a revolving credit arrangement with two banks for borrowings up to $6 million.  The revolving credit
agreement is subject to extension with the consent of the participating banks and has been extended through May 24, 2002.  As part
of amendments to the Company's revolving credit agreement and line of credit agreement, it was decreased from $10 million to $6
million at the Company's request as of October 8, 1999.  These agreements contain certain restrictive covenants including interest
coverage tests and debt to equity ratios.  As of December 31, 2000, the Company was in compliance with those covenants.  The
Company can utilize, at its discretion, two types of loan options:  A Loans, which are provided on a pro rata basis in accordance
with each participating bank's share of the commitment amount, and B Loans, which are provided as arranged between the
Company and each of the participating banks.  The A Loans, at the Company's option, bear interest equal to either the agent bank's
prime rate or LIBOR-based pricing.  The Company also pays a quarterly commitment fee of .50% of the unused portion of the A
Loans.  The B Loans bear interest as arranged between the Company and the participating bank.  On September 15, 2000, the
Company entered a temporary line of credit arrangement for $2.5 million with one of the banks which will terminate on March 15,
2001.  This temporary line was required for working capital needs during this period.  As of December 31, 2000, an A Loan for
$2.4 million at 8.125% and temporary credit line loans of $1.3 million and $1.2 million at 7.8125% and 8.0%, respectively, were
outstanding under these arrangements.  As of December 31, 1999, an A Loan for $3 million and a B Loan for $600,000 were
outstanding under the revolving credit arrangement at 7.5% and 6.51%, respectively.

The Canadian subsidiary, Maine and New Brunswick, cancelled their long-standing $200,000 (Canadian) bank line of
credit in April, 2000.  This line, which provided for interest at the bank's prime rate, was not used during 2000 and is no longer
necessary because of the sale of the generating assets in June 1999.

**7.  COMMON SHAREHOLDERS' EQUITY**

On November 17, 1999, the Maine Public Utilities Commission (MPUC) authorized the repurchase of up to 500,000
shares of the Company's Common Stock in order to maintain the Company's capital structure at levels in accordance with the
Stipulation approved by the MPUC on December 1, 1999.  The Stipulation limits common equity to 51% of the capital structure.
The shares will be repurchased through an open-market program.  Previously, over a five-year period from September, 1989 to
September, 1994, under a similar program, the Company purchased 250,000 shares at a cost of $5.7 million.  During 2000, the
Company purchased 45,000 shares at a cost of $922,000.  Subtracting 648 shares issued to Company Directors during 2000 as a
component of their compensation, 294,352 shares are held as treasury shares with a cost of $6.6 million as of December 31, 2000.

Under the most restrictive provisions of the Company's long-term debt indentures and short-term credit arrangements,
retained earnings (plus dividends declared on Common Stock) available for the distribution of cash dividends on Common Stock
were $33,097,712 at December 31, 2000.

**8.  BENEFIT PLANS**

U. S. Defined Benefit Pension Plan

The Company has an insured non-contributory defined benefit pension plan covering substantially all employees.  Benefits
under the plan are based on employees' years of service and compensation prior to retirement.

The Company's policy has been to fund pension costs accrued.  No contribution was necessary for the 2000 and 1999 plan
years.  For the 1998 plan year, the Company made a contribution of $330,000 in 1999.

Health Care Benefits

In addition to providing pension benefits, the Company provides certain health care benefits to eligible employees and
retirees.  All employees share in the cost of their medical benefits, in addition to plan deductibles and coinsurance payments,
approximately 11.3% in 2000.  Effective with retirements after January 1, 1995, only retirees with at least twenty years of service
will be eligible for these benefits.  In addition, eligible retirees will contribute to the cost of their coverage starting at 60% for
retirees with twenty years of service with the contribution phasing out over the next ten years of service so that retirees with thirty
or more years of service do not contribute toward their coverage.

Based on prior Maine Public Utilities Commission (MPUC) accounting orders, the Company established a regulatory asset
of approximately $1,061,000, representing deferred postretirement benefits.  As an element of its four-year rate plan, the Company
began recovering these deferred expenses over a ten-year period, along with the annual expenses in excess of pay-as-you-go
expenses, starting in 1996.  As required by the MPUC, the Company made a payment of $354,017 to fund the 401(h) subaccount of
the Pension Trust for non-union retiree medical payments on September 14, 2000.  On December 28, 1999, the Company made a
payment of $2.1 million to a Voluntary Employee Benefit Association (VEBA) trust fund, an independent external trust fund for
union retiree medical payments.  These payments provide funding for future postretirement health care

Maine Public Service  29

costs at such time as customers are paying for these costs in their rates.  For purposes of determining the accrued postretirement
benefit cost as of December 31, 2000, the health care cost trend rate used was 8% in 2001 and graded down to 4.0% in 2009,
remaining at that level thereafter.  These rates have a significant effect on the amounts reported for the health care plan.  A one-percentage-point change in the trend rates would have the following effects:

|(Dollars in Thousands)                                           | One-Percentage-Point
|---------------------------------------------------------------- | --------------------
|                                                                 | **Increase**        
|****Effect on total cost of service and interest cost components | $  70               
|Effect on postretirement benefit obligation                      | $708                

The following table sets forth the plans' change in benefit obligation, change in plan assets, funded status and assumptions
as of December 31, 2000 and 1999:

|                                               | Pension  | Health Care
|---------------------------------------------- | -------- | -----------
|(Dollars in Thousands)                         | Benefits | Benefits   
|                                               | 2000     | 1999       
|Changes in benefit obligation                 
|Benefit obligation at beginning of year        | $14,302  | $15,746    
|Service cost                                   | 350      | 377        
|Interest cost                                  | 1,072    | 1,033      
|Special Termination Benefits                   | --       | 54         
|Amendments                                     | 303      | --         
|Curtailment gain ***(1)*****                   | --       | (167)      
|Actuarial (gain) loss                          | 100      | (1,819)    
|Benefits paid                                  | (957)    | (922)      
|Administrative Expenses                        | (55)     | --         
|Benefit obligation at end of year              | 15,115   | 14,302     
|Change in plan assets                         
|Fair value of plan assets at beginning of year | 17,861   | 16,883     
|Actual return on plan assets                   | (124)    | 1,570      
|Employer contribution                          | --       | 330        
|Benefits paid                                  | (957)    | (922)      
|Administrative Expenses                        | (55)     | --         
|Fair value of plan assets at end of year       | 16,725   | 17,861     
|Funded Status                                  | 1,610    | 3,559      
|Unrecognized transition (asset) obligation     | (171)    | (248)      
|Unrecognized prior service cost                | 839      | 626        
|Unrecognized net actuarial (gain)/loss         | (3,885)  | (5,423)    
|Accrued benefit cost                           | $(1,607) | $(1,486)   

Weighted-average assumptions as of December 31 (measurement date)

|Discount rate                  | 7.50% | 7.75% | 7.50% | 7.75%
|------------------------------ | ----- | ----- | ----- | -----
|Expected return on plan assets | 8.50% | 8.50% | 8.50% | 7.50%
|Rate of compensation increase  | 4.50% | 4.50% | N/A   | N/A  



***(1)*  Curtailment**

In 1999, the termination of employees at the U.S. generating facilities due to the generating asset sale on June 8, 1999,
qualified as a curtailment for purposes of calculating the pension benefit obligation.  As a result, the net curtailment gain reduced
the accrued transition costs related to the asset sale.  These benefits have been deferred and, according to the treatment approved by
the MPUC, are being amortized over four years beginning March 1, 2000.

******Retirement Savings Plan**

The Company has adopted a defined contribution plan (under Section 401(k) of the Internal Revenue Code) covering
substantially all of the Company's employees.  Participants may elect to defer from 1% to 15% of current compensation, and the
Company contributes such amounts to the plan.  The Company also matches contributions, with a maximum matching contribution
of 1% of current compensation.  Participants are 100% vested at all times in contributions made on their behalf.  The Company's
matching contributions to the plan were approximately $59,000, $58,000, and $56,000, in 2000, 1999, and 1998, respectively.

**Amendments to Benefits**

Effective January 1, 2001, the Company's maximum matching contribution to the 401(k) plan increased to 2% of current
compensation.  Effective January 1, 2000, several amendments were made to the Company's health care benefits and were
considered in the calculations above.  These amendments were designed to mitigate the impact on the Company of rising medical
coverage premiums and include the raising of deductibles, employee/retiree contributions, and prescription drug co-pay amounts.

*********Maine Public Service  30*****

The following table sets forth the plans' net periodic benefit cost for 2000, 1999, and 1998:

|***(Dollars in Thousands)*            | Pension Benefits | Health Care Benefits
|------------------------------------- | ---------------- | --------------------
|                                      | 2000             | 1999                
|Service cost                          | $350             | $377                
|Interest cost                         | 1,072            | 1,033               
|Expected return on plan assets        | (1,229)          | (1,136)             
|Amortization of transition obligation | (77)             | (77)                
|Amortization of prior service cost    | 90               | 73                  
|Curtailment  ***(1)*****              | --               | --                  
|Recognized net actuarial (gain)       | (85)             | --                  
|Net periodic benefit cost             | $121             | $270                



**9.  LONG-TERM DEBT**

The sale of the Company's generating assets in 1999 significantly impacted long-term debt.  Proceeds from the sale were
deposited with the first mortgage trustee and subsequently withdrawn to redeem the remaining $2.5 million of 9.6% second
mortgage bonds and $1.4 million of the variable rate 1996 Public Utility Refunding Revenue Bonds.  On June 14, 2000, the
Company redeemed the  9.775% first mortgage bonds in the amount of $15.0 million and paid a related premium on the retirement
of $2.1 million.

On October 19, 2000, the Maine Public Utilities Financing Bank (MPUFB) issued $9 million of its tax-exempt bonds due
October 1, 2025 (the 2000 Series) on behalf of the Company.  The proceeds have been placed in trust  to be drawn down for the
reimbursement of  issuance costs and for the construction  of qualifying distribution property.  Pursuant to the long-term note issued
under a loan agreement between the Company and the MPUFB, the Company has agreed to make payments to the MPUFB for the
principal and interest on the bonds.  Concurrently, pursuant to a letter of credit and reimbursement agreement, the Company caused
a Direct Pay Letter of Credit for an initial term of nineteen months  to be issued by The Bank of New York for the benefit of the
holders of such bonds.  To secure the Company's obligations under the letter of credit and reimbursement agreement, the Company
issued first and second mortgage bonds, in the amounts of $5 million and $4.525 million, respectively.  The Company has the
option of selecting weekly, monthly, annual or term interest rate periods for the 2000 Series, and, at issuance, selected the weekly
interest period, with an initial interest rate of 4.35%.  On November 20, 2000, the Company purchased an interest rate cap of 6% at
a cost of $36,000, to expire November 2003, that applies to the 2000 and 1996 Series.  At the end of 2000, the cumulative effective
interest rate of the 2000 Series, including issuance costs and credit enhancement fees since issuance was 7.05%.

On May 29, 1998, FAME issued $11,540,000 of its Taxable Electric Rate Stabilization Revenue Notes, Series 1998A (Maine
Public Service Company) (the Notes) on behalf of the Company.  The Notes were issued pursuant to, and are secured under, a Trust
Indenture by and between FAME and Peoples Heritage Bank, Portland, Maine, as Trustee (the Trustee), for the purpose of:  (i)
financing the buy-down payment to Wheelabrator-Sherman of approximately $8.7 million, as required under an amended purchase
power agreement; (ii) for the Capital Reserve Fund, as required by FAME under their Electric Rate Stabilization Program; and (iii)
for issuance costs.  The Notes are limited obligations of FAME, payable solely out of the trust estate available under the Indenture,
principally the Loan Note and Loan Agreement with the Company and the Capital Reserve Fund held by the Trustee.  The
Company has issued $4 million of its first mortgage bonds and $7.54 million of its second mortgage bonds as collateral for its
performance under the Loan Note issue pursuant to the Loan Agreement.  The Notes will bear interest at a Floating Interest Rate,
initially at 5.7% per annum, and will be adjusted weekly.  On June 1, 1998, the Company purchased an interest rate cap of 7% at a
cost of $172,000, to expire June, 2008, to limit its interest rate exposure to quarterly U.S. LIBOR rates.  At the end of 2000, the
cumulative effective interest rate was 6.78%.

Certain long-term debt is subject to restrictive covenants consistent with those discussed in Note 6.

*Maine Public Service  31*

**10.  	FAIR VALUE OF FINANCIAL INSTRUMENTS**

The Company's financial instruments consist primarily of cash in banks, receivables, and debt.  The carrying amounts for cash,
receivables, and short-term debt approximate their fair value due to the short-term nature of these items.  At December 31, 2000,
the Company's long-term debt had a carrying value and a fair value of approximately $36.0 million.

**11. 	COMMITMENTS, CONTINGENCIES, AND REGULATORY MATTERS**

**Industry Restructuring**

On May 29, 1997, legislation titled "An Act to Restructure the State's Electric Industry" was signed into law by the Governor
of Maine.  The principal provisions with accounting impact on the Company are as follows:

1.	Beginning on March 1, 2000, all consumers of electricity have the right to purchase generation services directly from
competitive electricity suppliers who will not be subject to rate regulation.

2.	By March 1, 2000, the Company, Central Maine Power Company (CMP), and Bangor Hydro-Electric Company (BHE)
must divest themselves of all generation related assets and business functions except for:

a)	contracts with qualifying facilities, such as the Company's power contract with Wheelabrator-Sherman (W-S), and
conservation providers;

b)	nuclear assets, namely, the Company's investment in the Maine Yankee Atomic Power Company;

c)	facilities located outside the United States, i.e., the Company's hydro facility in New Brunswick, Canada; and

d)	assets that the MPUC determines necessary for the operation of the transmission and distribution services.  The
MPUC can grant an extension of the divestiture deadline if the extension will improve the selling price.  For assets not
divested, the utilities are required to sell the rights to the energy and capacity from these assets.  For more information
about the Company's sale of its generating assets, see "Capacity Arrangements", below.

3.	The Company will continue to provide transmission and distribution services which will be subject to continued rate
regulation by the MPUC.

4.	Maine electric utilities will be permitted a reasonable opportunity to recover legitimate, verifiable and unmitigable costs
that are otherwise unrecoverable as a result of retail competition in the electric utility industry (so-called "stranded costs").
The MPUC shall determine these stranded costs by considering:

a)	the utility's regulatory assets related to generation, i.e., the Company's unrecovered Seabrook investment;

b)	the difference between net plant investment in generation assets compared to the market value for those assets; and

c)	the difference between future contract payments and the market value of the purchased power contracts, i.e., the W-S
contract.

5.	The MPUC shall include in the rates to be charged by the transmission and distribution utility decommissioning expenses
for Maine Yankee.  In 2003, and every three years  thereafter until the stranded costs are recovered, the MPUC shall
review and adjust the stranded cost recovery amounts and related transition charges.  However, the MPUC may adjust the
amounts at any point in time that they deem appropriate.  Since the legislation provides for our recovery of stranded costs
by the transmission and distribution company, the Company will continue to recognize existing regulatory assets and plant
costs as provided by Emerging Issues Task Force 97-4 "Deregulation of the Pricing of Electricity" (EITF 97-4).

6.	Billing and metering services will be subject to competition beginning March 1, 2002, but permits the MPUC to establish
an earlier date, no sooner than March 1, 2000.  The implementation of this provision was subsequently delayed, and the
Company cannot predict when or if it will begin.

7.	All competitive providers of retail electricity must be licensed and registered with the MPUC and meet certain financial
standards, comply with customer notification requirements, adhere to customer solicitation requirements and are subject to
unfair trade practice laws.  Competitive electricity providers must have at least 30% renewable resources in their energy
portfolios, including hydro-electric generation.

8.	A standard offer service will be available, ensuring access for all customers to reasonably priced electric power.
Unregulated affiliates of CMP and BHE providing retail electric power are prohibited from providing more than 20% of
the load within their respective service territories under the standard offer service, while any unregulated affiliate of the
Company does not have a similar restriction.

9. 	Employees other than officers, displaced as a result of retail competition will be entitled to certain severance benefits and
retraining programs.  These costs will be recovered through charges collected by the regulated transmission and
distribution company.

According to EITF 97-4, entities should cease to apply Statement of Financial Accounting Standards No. 71 (SFAS 71),
"Accounting for the Effects of Certain Types of Regulations" when a deregulation plan is in place and the terms are known.  With
respect to the generation portion of the Company's business, this occurred in the fourth quarter of 1999, when the terms where
substantially agreed upon by stipulations in the MPUC's proceeding on revenue requirements, rate design and stranded costs in
Docket 98-577.  This stipulation was approved by the MPUC on January 27, 2000.  As more fully discussed in "Capacity
Arrangements", the Company sold all generating assets on June 8, 1999.  Correspondingly, the Company adopted SFAS 101
"Regulated Enterprises - Accounting for the Discontinuation of  Application of FASB Statement No. 71" for the generation
segment of

*Maine Public Service  32*

its business in the fourth quarter of 1999.  SFAS 101 requires a determination of impairment of plant assets under SFAS 121
"Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of" and the elimination of all
effects of rate regulation that have been recognized as assets and liabilities under SFAS 71.  The Company has determined no such
impairment exists.

The Company believes that its electric transmission and distribution operations continue to meet the requirements of SFAS 71
and that regulatory assets associated with those operations, as well as any generation-related costs that the MPUC has determined to
be recoverable from ratepayers, also meet the criteria.  At December 31, 2000, $77.5 million of regulatory assets remain on the
Company's books.  These assets will be amortized over various periods in accordance with the MPUC approved Phase II filing.

For further discussion of the specific impacts of the industry restructuring on the Company and related ratemaking activity, see
"MPUC Approves Elements of Rates Effective March 1, 2000", below.

**MPUC Approves Elements of Rates Effective March 1, 2000**

On October 14, 1998, and subsequently amended on February 9, 1999, August 11, 1999, and December 15, 1999, the
Company filed its determination of stranded costs, transmission and distribution costs, and rate design with the MPUC.  The
Company's amended testimony supported its $95.7 million estimate of stranded costs, net of available value from the sale of the
generating assets, when deregulation occurred on March 1, 2000.  The major components include the remaining investment in
Seabrook, the above-market costs of the amended power purchase agreement and recovery of fuel expense deferrals related to
Wheelabrator-Sherman, the obligation for remaining operating expenses and recovery of the Company's remaining investment in
Maine Yankee, and the recovery of several other regulatory assets.

On October 15, 1999, the Company filed with the MPUC a Stipulation resolving the revenue requirement and rate design
issues for the Company's Transmission and Distribution (T&D) utility.  This Stipulation was signed by the Public Advocate and
approval was recommended by the MPUC Staff.  Under the Stipulation, the Company's total annual T&D revenue requirement of
$16,640,000 went into effect on March 1, 2000.  This revenue requirement includes a 10.7% return on equity with a capital
structure based on 51% common equity.  The Stipulation further provided that the precise level of stranded cost recovery could not
be determined until final determination of all costs associated with the sale of the Company's generating assets, but did set forth
some general principles concerning the Company's ultimate stranded costs recovery, including agreement that the major
components of the Company's stranded costs are legitimate, verifiable and unmitigable, and therefore subject to recovery in rates.
Furthermore, the Stipulation allowed the 3.66% foregone revenue increase as a result of a rate plan Stipulation approved by the
MPUC in its April 6, 1999 Order in Docket 98-865 to be recovered through a reduction in the deferred gain on the asset sale.  The
Stipulation also provided that the Company's recovery of unamortized investment tax credits and excess deferred income taxes
associated with the Company's generating assets must await a final determination ruling from the IRS, which ruling was sought by
Central Maine Power Company (CMP).  On December 1, 1999, the MPUC approved the October 15, 1999 Stipulation, as
described above.  In early January, 2000, CMP received its ruling from the IRS which concluded that the unamortized investment
tax credits and excess deferred income taxes associated with the sale of the generating assets could not be used to reduce customer
rates without violating the tax normalization rules for public utilities.  Therefore, in 1999, the Company recognized these excess
deferred taxes in income, which amounted to an increase in net income of approximately $389,000.

On January 27, 2000, the MPUC approved a Stipulation in Phase II of Docket No. 98-577 that provided for the recovery in
rates of the Company's stranded investment.  The major element of the Phase II Stipulation was the $12.5 million of stranded
investment recoverable annually beginning March 1, 2000.  This revenue requirement includes a return on unrecovered stranded
investment based on the capital structure approved by the MPUC in its December 1, 1999 Order.  The approved capital structure
consists of 51% common equity with an authorized return on equity of 10.7%.  The Phase II Stipulation also allowed the Company
to offset its unrecovered stranded investment in Seabrook by approximately $7 million, (details provided in chart in "Capacity
Arrangements -- Generating Asset Sale", below) representing an amount equal to 35% of the available value from the sale of the
generation assets.  The parties to the Phase II Stipulation also resolved several rate design issues, principally the elimination of the
inclining block rate for residential customers.  In addition, the Company was granted several accounting orders incorporating
certain accounting methodologies used in determining the elements of stranded costs.  On August 4, 2000, the MPUC authorized
the Company to record the difference between the approved contracts for two large industrial customers and their current special
discount rates, designed for customer retention, as revenue and a regulatory asset.  During 2000, this flexible pricing adjustment
resulted in recognition of $380,000 of revenues and a corresponding regulatory asset.  The annual revenue requirement associated
with the recovery of stranded costs will be reviewed at least every three years.  The Company expects to file annual revenue
requirements with the MPUC in the Fall of 2001 to determine rates for the next rate period.

**MPUC Approves Common Stock Repurchase Program**

After paying off debt with proceeds from the sale of the Company's generating assets, as required under the Company's
mortgage indentures, the Company projected that the percentage of common equity as a component in its capital structure would
exceed 51%.  In order to manage its capital structure to limit common equity to 51%, the MPUC, on November 17, 1999, approved
the Company's request to repurchase up to 500,000 shares of its Common Stock over a period of five years.  The shares will be
repurchased through an open-market program.  During 2000, the Company purchased 45,000 shares for $922,000. Previously over
a five-year period from September, 1989 to September, 1994, the Company purchased 250,000 shares at a cost of $5.7 million.
Reflecting the reissuance of 648 shares to the Company's directors as a component of their compensation during 2000, 294,352
shares are held as Treasury stock as of December 31, 2000.



**Four-Year Rate Stabilization Plan**

On November 13, 1995, the Maine Public Utilities Commission (MPUC) approved a stipulation signed by the Company, the
Commission Staff, and the Office of the Public Advocate (OPA).  This stipulation, effective January 1, 1996, established a multi-year rate plan for the Company that provided our customers with predictable rates until March 1, 2000, and shares operating
risks
and benefits between the Company's shareholders and customers.  As described in

*Maine Public Service  33*

the "Industry Restructuring" and "MPUC Approves Elements of Rates Effective March 1, 2000", above, March 1, 2000 was the
beginning of industry restructuring and new rates.

Under the terms of the rate plan, as amended in January, 1998, which applies cost of service principles, the Company's retail
rates were increased by 4.4%, 2.9%, and 3.9% on January 1, 1996, February 1, 1997 and February 1, 1998, respectively.  The
Company agreed that it would seek no other increases, for either base or fuel rates, except as provided under the terms of the plan.
There were no fuel clause adjustments for the duration of the plan.  The rate plan also provided for adjustments resulting from the
operation of a profit-sharing mechanism, as well as provisions for mandated costs and plant outage provisions, particularly the
shutdown of Maine Yankee, as further explained in the "Capacity Arrangements -- Maine Yankee", below.

The Company was also permitted to defer $1,500,000 annually of the costs of its purchases from Wheelabrator-Sherman
during each of the four years of the rate plan.  The plan permitted the Company to recover this deferred amount, up to a total of
$6,000,000, in rates beginning in the year 2001.  The rate plan provided for the deferral until the year 2000, of approximately $1.3
million, net of income taxes, of uncollected retail fuel at the beginning of the rate plan, while an additional $300,000, net of income
taxes, will be collected in rates over the rate plan period.

For the final year of the rate plan beginning February 1, 1999, the Company filed on November 13, 1998, with the MPUC for a
6.4% increase.  The Company also stated that it would forego part or all of this 1999 increase if the sale of its generating assets was
allowed to go forward.  On December 15, 1998, the MPUC granted the Company's request to defer the increase to April 1, 1999,
as well as extend the rate plan by one month to February 29, 2000, to coincide with the start of retail competition in Maine.



In its April 6, 1999 Order, the MPUC approved a March 25, 1999 Stipulation between the Office of the Public Advocate
(OPA) and the Company.  Under this Stipulation, customer rates would not increase on April 1, 1999, if the MPUC approved the
sale of the Company's generation assets.  The approval of the Stipulation also resolved certain issues  associated with the treatment
of capacity cost savings from the closure of Maine Yankee under the Company's rate stabilization plan.

The principal provisions are as follows:

1. 	The Company is entitled to a 3.66% specified rate increase as of April 1, 1999.  Rather than increase customer rates, the
Company will recognize the revenues that this increase would have generated and, correspondingly, record a deferred
asset on the Company's books of account.  The parties to the Stipulation also agreed to recommend the use in rates of
available value from the asset sale corresponding with the specified rate increase once the MPUC determines the
Company's allowed stranded cost recovery in Docket No. 98-577, Public Utilities Commission, Investigation of Stranded
Costs, Transmission and Distribution Utility, Revenue Requirements and Rate Design of Maine Public Service Company.

2.	The Stipulation also resolves a dispute over the determination of Maine Yankee replacement power costs.  The Stipulation
allows the Company to continue to recognize and defer Maine Yankee replacement power costs on an energy-only basis,
offset by Wheelabrator-Sherman contract restructuring savings, through the end of the rate plan.  The Company agreed to
begin amortizing on April 1, 1999, Maine Yankee replacement power costs in the amount of $150,000 per month or a total
of $1,650,000 for the remaining eleven months of the rate plan.

3.	With the Commission's approval of the generation asset sale, the parties agreed that the Company would not increase
retail rates on April 1, 1999, to reflect any increase under the Maine Yankee replacement power provision of the rate plan.
Any Maine Yankee deferred replacement costs will be deferred, and, beginning on March 1, 2000, will be offset by a
corresponding amount of available value as allowed in Docket No. 98-577.

**	As described in "MPUC Approves Elements of Rates Effective March 1, 2000", above, the MPUC approved a Stipulation
providing for the recovery in rates of stranded investment, which includes the deferrals allowed under the rate plan.

******Seabrook Nuclear Power Project**

In 1986, the Company sold its 1.46% ownership interest in the Seabrook Nuclear Power Project with a cost of approximately
$92.1 million for $21.4 million.  Both the MPUC and the FERC allowed recovery of the Company's remaining investment in
Seabrook Units 1 and 2, adjusted by disallowed costs and sale proceeds, with the costs being amortized over thirty years.

Recoverable Seabrook costs at December 31, 2000 and 1999 are as follows:

|*(Dollars in Thousands)*    |             
|--------------------------- | ------------
|                            | ******2000**
|****Retail                  | $43,136     
|Accumulated Amortization    | (25,917)    
|Retail, Net of Amortization | $17,219     

In March 2000, the Company was allowed to offset $5.1 million of the recoverable Seabrook costs with the available value
from its deferred asset sale gain, as detailed in "Capacity Arrangements-Generating Asset Sale", below.  The remainder of the $6.2
million decrease in recoverable Seabrook costs represents monthly amortization, recorded as amortization expense in January and
February, 2000, and then as stranded costs applied to the deferred asset sale gain beginning in March, 2000, as described in
"MPUC Approves Elements of Rates Effective March 1, 2000", above.



**Nuclear Insurance**

In 1988, Congress extended the Price-Anderson Act for fifteen years and increased the maximum liability for a nuclear-related
accident.  In the event of a nuclear accident, coverage for the higher liability now provided for by commercial insurance coverage
will be provided by a retrospective premium of up to $88.1 million for each reactor owned, with a maximum assessment of $10
million per reactor for any year.  Maine Yankee is not liable for "events" or "accidents" occurring after January 7, 1999, when
exemption was received from the Nuclear Regulatory Commission.  These limits are also subject to inflation indexing at five-year
intervals as well as an additional 5% surcharge, should total claims exceed funds available to pay such claims.  Based on the
Company's 5% equity ownership in Maine Yankee (see Note 4), the Company's share of any retrospective premium would not
exceed approximately $3.5 million or $.5 million annually, without considering inflation indexing.

Maine Public Service  34

**Capacity Arrangements**

Generating Asset Sale

On July 7, 1998, the Company and WPS Power Development, Inc., (WPS-PDI) signed a purchase and sale agreement for the
Company's electric generating assets.  WPS-PDI agreed to purchase 91.8 megawatts of generating capacity for $37.4 million,
which is 3.2 times higher than the net book value of the assets.  This sale of assets was required by the State's electric industry
restructuring law.  The gain from the asset sale will reduce stranded cost revenue requirements, as discussed in "MPUC Approves
Elements of Rates Effective March 1, 2000", above.

The Company consummated the sale to WPS-PDI on June 8, 1999 after receiving all of the major regulatory approvals.  The
Company's 5% ownership in Maine Yankee was not part of the sale, since the plant is being decommissioned.  After paying
Canadian, Federal and State income taxes, the remaining proceeds, along with interest in the trust account, were used to reduce the
Company's debt.  The gain from the sale has been deferred, as required by the MPUC.  The components of the deferred gain are as
follows:



|*(Dollars in Millions)*                       
|----------------------------------------------
|**Gross proceeds                              
|Settlement adjustments                        
|Net proceeds                                  
|Net book value                                
|Excess taxes on sale of Canadian Assets       
|Transition costs, net                         
|Other                                         
|Available deferred gain                       
|Utilization of available value per MPUC orders
|Remaining deferred gain, net of tax *         

*   The $7.2 million deferred gain above is the $7.4 million "Deferred Gain and Related Accounts -- Generating Asset Sale" as of
December 31, 2000 reduced by the remaining deferral of transition costs allowed by the MPUC.

The Company offset a portion of its Recoverable Seabrook costs with available value from its deferred asset sale gain as
follows:

|                                                                               |              | **********Deferred**
|------------------------------------------------------------------------------ | ------------ | --------------------
|****                                                                           | **Seabrook** | **Gain**            
|****Write-off of recoverable Seabrook Costs                                    | $5,060       | --                  
|Write-off of deferred tax liability associated with recoverable Seabrook costs | (3,644)      | --                  
|Recognition of deferred asset sale gain                                        | --           | $7,006              
|Recognition of deferred tax associated with deferred asset sale gain           | --           | (2,795)             
|Write-off of SFAS 109 Regulatory Asset associated with Seabrook                | 2,795        | --                  
|Net Change                                                                     | $4,211       | $4,211              

With the partial liquidation of the subsidiary in December, 1999, approximately $18.0 million of the proceeds were
transferred to the first mortgage trustee for paydown of long-term debt.  Using these asset sale proceeds and accumulated interest,
in 1999, the Company reduced long-term debt by $3.9 million, and, in 2000, the Company used $1.9 million to reduce short-term
borrowings and reduced long-term debt by $15.0 million.  In addition, the Company paid an early retirement premium of  $2.1
million.  Consistent with past treatment, the Company has deferred this premium and will amortize the balance over the remaining
life of the original debt issue.

With the sale of the Company's generating assets in June, 1999, the Company purchased energy from the new owners
under an agreement that expired February 29, 2000, and these purchases are classified as purchased energy.

As part of the generating asset sale on June 8, 1999, the Company has entered into two indemnity obligations with the
purchaser, WPS-PDI.  First, the Company will be liable, with certain limitations, for certain Aroostook River flowage damage.
This liability will continue for ten years after the sale and shall not exceed $2,000,000 in the aggregate.  Second, the Company has
warranteed the condition of the sites sold to WPS-PDI, with an aggregate limit of $3,000,000 for two years after the date of sale,
and five years after the sale for environmental claims.  The Company is unaware of any pending claims under either of these
indemnity obligations.

Maine Yankee

The Company owns 5% of the Common Stock of Maine Yankee, which operated an 860 MW nuclear power plant (the
"Plant") in Wiscasset, Maine.  On August 6, 1997, the Board of Directors of Maine Yankee voted to permanently cease power
operations and to begin decommissioning the Plant.  The Plant experienced a number of operational and regulatory problems and
did not operate after December 6, 1996.  The decision to close the Plant permanently was based on an economic analysis of the
costs, risks and uncertainties associated with operating the Plant compared to those associated with closing and decommissioning it.
The Plant's operating license from the Nuclear Regulatory Commission (NRC) was due to expire on October 21, 2008.

The Maine Agreement for the decommissioning of Maine Yankee requires the Maine owners, (Central Maine Power,
Bangor Hydro-Electric Company and the Company) for the period from March 1, 2000 through December 1, 2004, to hold their
Maine retail ratepayers harmless from the amounts by which the replacement power costs for Maine Yankee exceed the
replacement power costs assumed in the report to the Maine Yankee Board of Directors that served as a basis for the Plant
shutdown decision, up to a maximum cumulative amount of $41 million.  The Company's share of the maximum amount would be
$4.1 million for the period.  For the year ended December 31, 2000, the Company selected the price based on the two year
entitlement auction which was allowed under the agreement.  Since this price was below the assumed replacement power price,
there was no liability for this period.  The Company again selected the two year entitlement auction price for the year ended
December 31, 2001, but on October 11, 2000, the Maine Agencies, (the MPUC and the Office of the Public Advocate) rejected the
Maine Owners' selection of the sales auction price as the benchmark for calendar year 2001.  On December 11, 2000, in separate
negotiations, the Company reached an agreement in principal with the Maine Agencies.  Under this Agreement, the Company will
incur no liability for calendar year 2001.  For the calendar years 2002 through 2004, the Company will be required to use the
auction price as the appropriate proxy.  At this time, the Company cannot predict the auction price for 2002 to 2004 and, if it were
to exceed the assumed replacement power price, how much, if any, of the maximum $4.1 million will be required to be recognized
during these three years.

Maine Public Service  35

With the closing of Maine Yankee, a provision of the Company's rate plan allowing the deferral of 50% of the Maine
Yankee replacement power costs went into effect on June 6, 1997.  Beginning in May, 1998, Maine Yankee replacement power
costs have been offset by net savings from the restructured Purchase Power Agreement with Wheelabrator-Sherman, in accordance
with the rate plan stipulation.

Beginning in April, 1999, the Company began amortizing an additional $150,000 per month as part of a stipulation
described in "Four-Year Rate Stabilization Plan", above.  As of December 31, 2000, the Company has a deferred Maine Yankee
replacement power cost balance of approximately $3.0 million, in accordance with the rate plan.

On September 1, 1997, Maine Yankee estimated the sum of the future payments for the closing, decommissioning and
recovery of the remaining investment in Maine Yankee to be approximately $930 million, of which the Company's 5% share would
be approximately $46.5 million.  In December, 1998, June, 1999 and again in September 2000, Maine Yankee updated its estimate
of decommissioning costs based on the Settlement.  Legislation enacted in Maine in 1997 calls for restructuring the electric utility
industry and provides for recovery of decommissioning costs, to the extent allowed by federal regulation, through the rates charged
by the transmission and distribution companies.  Based on the Maine legislation and regulation precedent established by the FERC
in its opinion relating to the decommissioning of the Yankee Atomic nuclear plant, the Company believes that it is entitled to
recover substantially all of its share of such costs from its customers and, as of December 31, 2000, is carrying on its consolidated
balance sheet a regulatory asset and a corresponding liability in the amount of $28.1 million, which is the September, 1997 cost
estimate of $46.5 million, discussed above, reduced by the Company's post-September 1, 1997 cost-of-service payments to Maine
Yankee and reflects the cost adjustments agreed to in the settlement.

The MPUC, on January 27, 2000, approved a Stipulation providing for the recovery of stranded investment, which
includes the Company's share of Maine Yankee decommissioning expenses, Maine Yankee replacement costs, and the remaining
Maine Yankee investment.

On May 4, 2000, Maine Yankee notified its decommissioning operations contractor, Stone & Webster Engineering
Corporation (Stone & Webster), that it was terminating its decommissioning operations contract pursuant to the terms of the
contract.  Subsequently, Stone & Webster notified Maine Yankee that it was disputing Maine Yankee's grounds for terminating the
contract.  On May 8, 2000, Stone & Webster announced a proposed transaction in which it would transfer substantially all of its
assets in exchange for an immediate credit facility and other consideration, including cash and stock.  Stone & Webster said the
credit facility was intended to enable it to address its liquidity difficulties and continue to operate its businesses until the asset sale
was completed.  Stone & Webster also announced that it intended to seek bankruptcy court approval of the asset sale and credit
agreement.

On June 2, 2000, Stone & Webster filed a voluntary petition under Chapter 11 of the United States Bankruptcy Code with
the United States Bankruptcy Court for the District of Delaware.  By Sale Order dated July 13, 2000, the Bankruptcy Court
approved the sale of substantially all of Stone & Webster's assets to the successful bidder in the Chapter 11 sale, The Shaw Group,
Inc., (Shaw), for cash, stock, and the assumption of certain liabilities of Stone & Webster, and the proposed transaction announced
earlier by Stone & Webster was terminated.  Stone & Webster reported that the Shaw transaction was effectively closed on July 14,
2000, and that it would continue to operate as a Debtor-in-Possession subject to the supervision and orders of the Bankruptcy
Court.

Commencing in May, 2000, Maine Yankee entered into interim agreements with Stone & Webster in order to allow
decommissioning work to continue and avoid the adverse consequences of an abrupt or inefficient demobilization from the Plant
site.  After obtaining assignments of several subcontracts from Stone & Webster, Maine Yankee at least temporarily assumed the
general contractor role.  The decommissioning of the Plant site continued throughout the year 2000, with major emphasis directed
to maintaining the schedule on critical-path projects such as construction of the ISFSI and preparation of the Plant's reactor vessel
for eventual shipment to an off-site disposal facility.  During this period, Maine Yankee evaluated its long-term alternatives for
safely and efficiently completing the decommissioning, including detailed proposals from prospective successor general
contractors.  On January 26, 2001, Maine Yankee announced its decision to reject the proposals and continue to manage the
decommissioning project itself without an external general contractor.

On June 30, 2000, Federal Insurance Company (Federal), which provided performance and payment bonds in the amount
of $37.6 million each in connection with the decommissioning operations contract, filed a Complaint for Declaratory Judgement
against Maine Yankee in the United States Bankruptcy Court for the District of Delaware, which was subsequently transferred to
the United States District Court in Maine.  The Complaint, which seeks a declaration that Federal has no obligation to pay Maine
Yankee under the bonds, alleges that Maine Yankee improperly terminated the decommissioning operations contract with Stone &
Webster and failed to give proper notice of the termination to Federal under the contract, and that Federal, therefore, had no further
obligations under the bonds.

On August 24, 2000, Maine Yankee also filed a $78.2 million claim (later increased to $86.0 million) in the Stone &
Webster Bankruptcy Court proceeding in Delaware seeking to recover its additional costs caused by Stone & Webster's contract
default.  Maine Yankee expects the court hearings in both proceedings to take place later in 2001.  Maine Yankee believes that its
termination of the Stone & Webster contract was proper and that it is entitled to recover such additional costs in the bankruptcy
proceeding or under the bonds, but cannot predict the outcome of the litigation.

In December 2000, Maine Yankee distributed approximately $20 million to its owners from proceeds received as a result
of the termination of Maine Yankee's membership in a nuclear industry mutual insurance company.  The Company received its 5%
ownership share, or $1.0 million, and recorded a regulatory liability, awaiting rate treatment.

**MEPCO**

The Company also owns 7.49% of the Common Stock of Maine Electric Power Company, Inc., (MEPCO).  MEPCO owns and
operates a 345-KV (kilovolt) transmission line about 180 miles long which connects the NB Power system with the New England
Power Pool.

Maine Public Service  36

**Wheelabrator-Sherman**

The Company was ordered into a Power Purchase Agreement (PPA) with Wheelabrator-Sherman (W-S) in 1986, which
required the purchase of the entire output (up to 126,582 MWH per year) of a 17.6 MW biomass plant through December 31, 2000.
The PPA was subsequently amended in 1997, with W-S agreeing to price reductions of $10 million through the end of the original
term in exchange for an up-front payment of $8.7 million in May, 1998 following the completion of the  FAME financing, as
described in Note 9, "Long-Term Debt".  The MPUC's December, 1997 approval of the amended PPA included a determination
that the up-front payment would be treated as stranded cost and, therefore, recovered in rates of the transmission and distribution
company, as discussed in "MPUC Approves Elements of Rates Effective March 1, 2000", above.

The Company and W-S also agreed to renew the PPA for an additional six years at agreed-upon prices and an increase of
output to 136,982 MW beginning in 2001.  The amended PPA has helped relieve the financial pressure caused by the closure of
Maine Yankee as well as the need for substantial increases in its retail rates, and is, therefore, in the best interests of the Company,
its customers and shareholders.  Purchases under this contract during 2000, 1999 and 1998 were $13.3 million, $14.2 million and
$13.8 million, respectively.  The reduced expenses in 2000 reflect purchases from W-S through February 29, 2000 only, as they
were treated as stranded cost as described in "MPUC Approves Elements of Rates Effective March 1, 2000", above.

The Company estimates its remaining commitment to purchase power under this contract to be $69.4 million from January 1,
2001 through 2006.  The Company has entered a contract whereby WPS-PDI takes delivery of the power through February 28,
2002 at market prices.  The Company estimates that the remaining stranded costs will be $47.1 million through 2006, assuming
arrangements similar to the one with WPS-PDI will be in place for that period.

**Northeast Empire**

On December 19, 1997, the Company announced the signing of an agreement for the purchase of power for approximately 3.4
cents per KWH until March 1, 2000 from Northeast Empire, a 38 MW biomass plant in Ashland, Maine, as a replacement for
Maine Yankee energy.  Expenses under this agreement during 2000, 1999 and 1998 were $1.5 million, $7.8 million and $7.2
million, respectively.

**WPS Complaint**

On October 30, 2000, WPS Energy Services (WPS), a Competitive Electricity Provider (CEP) offering retail sales of
electricity in the Company's service territory, filed a Complaint (Docket No. 00-894) against the Company as well as a Petition to
Alter or Amend the MPUC's September 2, 1998 Order in Docket No. 98-138.

The Complaint alleges that the Company has violated various provisions of Chapter 304 of the MPUC's Regulation governing
relations between the Company and all CEPs, including the Company's own marketing subsidiary, Energy Atlantic, LLC, (EA).
According to the Complaint, various of the Company's employees have engaged in conduct that either awards EA a competitive
advantage over other CEPs or has burdened WPS with an unfair disadvantage relative to EA.  These allegations include such
practices as denying WPS information made available to EA, or providing EA with information about WPS's customers that is not
available publicly.  The Company does not believe it has in any way violated any provisions of Chapter 304 and has so argued to
the MPUC.

In its September 2, 1998 Order in Docket No. 98-138 authorizing the formation of EA, the Commission allowed the Company
and EA to share the services of certain employees under certain conditions on the grounds that such sharing was in the public
interest and would not have any anti-competitive effect on the retail market for electricity.  WPS claims that the sharing does not
conform to the conditions set forth in the Order and that, in any event, the Commission should now find such sharing not in the
public interest, thereby amending its original September 2, 1998 Order.

The Complaint and Petition to Amend the September 2, 1998 Order, in addition to requesting a prohibition on the sharing of
certain employees, also seeks a formal investigation of the Complaint, penalties for any violations of the Commission's rules and
certain specific relief for violations of Chapter 304.

The Company believes the Complaint and Petition are completely without merit and are motivated by EA's recent competitive
successes against WPS in the local retail electricity market.  The Company intends to vigorously contest the matter at the MPUC,
but cannot predict the outcome of this proceeding.

Construction Program

Expenditures on additions, replacements and equipment for the years ended December 31, 2000, 1999, and 1998, along with
2001 estimated expenditures, are as follows:

******
**2001**
**2000**
**1999**
**1998******
(Unaudited
Estimates)Parent CompanyGeneration
$     --
$     --
$ 12
$4Transmission
1,003
1,162
1,277
803Distribution
2,993
2,660
2,342
2,226General
932
914
1,072
712Total Parent
4,928
4,736
4,703
3,745Energy Atlantic
--
10
61
--Total
$ 4,928
$ 4,746
$4,764
$ 3,745**

Maine Public Service  37

12.  QUARTERLY INFORMATION (unaudited)

Quarterly financial data for the two years ended December 31, 2000 is as follows:

(Dollars in Thousands Except Per Share Amounts)

|                                 | **********2000 by Quarter**
|-------------------------------- | ---------------------------
|****                             | 1st                        
|Operating revenues               | $17,567                    
|EA-SOS margin                    | 312                        
|Total Revenues                   | 17,879                     
|Operating expenses               | 15,418                     
|Operating income                 | 2,461                      
|Interest charges                 | 942                        
|Other income-net                 | 372                        
|Net income                       | $1,891                     
|Earnings per common share        | $1.17                      
|                                 | ******1999 by Quarter**    
|****		****                       | **1st**                    
|****Operating revenues           | $17,469                    
|Operating expenses               | (14,980)                   
|Operating income                 | 2,489                      
|Interest charges                 | (972)                      
|Other income-net                 | 242                        
|Net income (loss)                | $ 1,759                    
|Earnings (Loss) per common share | $   1.09                   

*Maine Public Service  38*

MAINE PUBLIC SERVICE COMPANY and Subsidiaries (Unaudited)

|                                                    | Consolidated Financial Statistics          
|--------------------------------------------------- | -------------------------------------------
|                                                    | 2000                                       
|Capitalization Including Bank Borrowings (year-end)
|                                                    | Debt (including amount due within
one year)
|                                                    | Common Shareholders' Equity                
|Times Interest Earned -                            
|                                                    | Before Income Taxes                        
|                                                    | After Income Taxes                         
|Times Interest and Preferred Dividends Earned -    
|                                                    | After Income Taxes                         
|Embedded Cost of Long-Term Debt
(year-end)          | 6.80%                                      
|Common Shares Outstanding (year-end)                | 1,572,898                                  
|Earnings (Loss) Per Share of Common Stock          
|                                                    | (average shares)                           
|Dividends Per Share of Common Stock                
|                                                    | Declared Basis                             
|                                                    | Paid Basis                                 
|Common Stock Dividend Payout Ratio -
*              | 37.13%                                     
|Book Value Per Share of Common
Stock (year-end)     | $25.17                                     
|Market Price Per Share of Common Stock             
|                                                    | High                                       
|                                                    | Low                                        
|                                                    | Close                                      
|Price Earnings Ratio (year-end) +                   | 7.90                                       
|Number of Common Shareholders
(year-end)            | 1,075                                      

*1997 net loss produces a ratio which is not meaningful.  Before regulatory write-offs in 1995.

+1997 net losses produce ratios which are not meaningful.

2000 Sources of Income

Millions of Dollars (Total $79.3)

and Percent of Total

Energy Atlantic

$40.7 Million [51.3%]

Other Electric Sales

$1.6 Million [2.0%]

Other Income

$3.3 Million [4.2%]

Residential

$14.6 Million

[18.4%]

Commercial

$19.1 Million

[24.1%]

2000 Distribution of Income

Millions of Dollars (Total $79.3)

and Percent of Total

Wages and Employee Benefits

$7.2 Million [9.1%]

Taxes

$3.8 Million [4.8%]

Other Operating Expenses

$16.3 Million [20.6%]

Interest

$2.5 Million [3.1%]

Common Dividends

$2.0 Million [2.5%]

Retained Earnings

$3.9 Million [4.9%]

Fuel & Purchased Power

$43.6 Million [55.0%]

***Maine Public Service  39*

MAINE PUBLIC SERVICE COMPANY and Subsidiaries  (Unaudited)

|                                              | Consolidated Operating Statistics
|--------------------------------------------- | ---------------------------------
|                                              | 2000 (2)                         
|Operating Revenues                           
|Residential                                   | $14,604,703                      
|Small Commercial *(1)*                        | 7,075,414                        
|Medium Commercial *(1)*                       | 5,907,941                        
|Large Commercial                              | 6,110,979                        
|Street & Area Lighting                        | 782,715                          
|Sales for Resale (until
3/1/00)               | 1,797,924                        
|Other Operating
Revenues                      | 2,130,646                        
|Energy Atlantic
Competitive Energy
Supply     | 37,054,108                       
|Total Operating
Revenues                      | 75,464,430                       
|Energy Atlantic
Standard Offer Service
Margin | 2,773,849                        
|Total Revenues                                | $ 78,238,279                     
|Number of Customers (average)                
|Residential                                   | 28,791                           
|Small Commercial *(1)*                        | 5,299                            
|Medium Commercial *(1)*                       | 194                              
|Large Commercial                              | 15                               
|Street & Area Lighting                        | 1,126                            
|Sales for Resale (until
3/1/00)               | 3                                
|Energy Atlantic
Competitive Energy
Supply     | 822                              
|Total Customers                               | 36,250                           
|Energy Deliveries (MWH)                      
|Residential                                   | 166,049                          
|Small Commercial *(1)*                        | 87,867                           
|Medium Commercial*(1)*                        | 103,914                          
|Large Commercial                              | 171,023                          
|Street & Area Lighting                        | 3,259                            
|Sales for Resale (until
3/1/00)               | 38,010                           
|Energy Atlantic
Competitive Energy
Supply     | 754,189                          
|Total Deliveries                              | 1,324,311                        

Notes:

*(1)  Rate class grouping changed to reflect those in effect beginning March 1, 2000.*

*(2)  Revenues beginning March 1, 2000, the beginning of retail competition, reflect the transmission and delivery charges
only, and are not comparable to previous years, while the number of customers and energy deliveries in 2000 are
comparable with prior years.*

**YEAR-END   CAPITALIZATION**

**(Percent)**

|******Year** | **Total Debt** | **Common Equity**
|------------ | -------------- | -----------------
|**2000**     | **50.81**      | **49.19**        
|**1999**     | **55.11**      | **44.89**        
|**1998**     | **61.28**      | **38.72**        
|**1997**     | **57.82**      | **42.18**        
|**1996**     | ****52.75      | 47.25            



Maine Public Service  40

Board of  Directors

Maine Public Service Company's ten-member Board of Directors is

composed of nine outside directors and one inside director, Paul R. Cariani.

Their diverse business, educational, professional, and civic backgrounds are

valuable assets that provide a broad perspective to the issues concerning the Company.

G. Melvin Hovey

Chairman of the Board

and Retired President

Maine Public Service Company

Presque Isle, Maine

Pension Investment Committee

Budget and Finance Committee

Robert E. Anderson

Chairman of the Board,

Chief Financial Officer and

Former President

F. A. Peabody Company

Houlton, Maine

Pension Investment Committee

Budget and Finance Committee

Paul R. Cariani

President and CEO

Maine Public Service Company

Presque Isle, Maine

Donald F. Collins

Director and Retired President

S. W. Collins Co.

Caribou, Maine

Audit Committee

Nominating Committee

D. James Daigle

President

D & D Management Co.

Orlando, Florida

Executive Compensation Committee

Richard G. Daigle

President and CEO

Daigle Oil Company

Cold Brook Energy, Inc., President

Fort Kent, Maine

Audit Committee

Executive Compensation Committee

J. Gregory Freeman

President and CEO

Pepsi-Cola Bottling Company

of Aroostook, Inc.

Presque Isle, Maine

Budget and Finance Committee

Nominating Committee

Deborah L. Gallant

President and CEO

D. Gallant Management Associates

Portland, Maine

Executive Compensation Committee

Nominating Committee

Nathan L. Grass

President

Grassland  Equipment, Inc.

Presque Isle, Maine

Executive Compensation Committee

J. Paul Levesque

President and CEO

J. Paul Levesque & Sons, Inc.

(Lumber Mill) and

Antonio Levesque & Sons, Inc.

(Logging Operation)

Ashland, Maine

Audit Committee

Pension Investment Committee

*Maine Public Service  --  Back Inside Cover*

Executive  Officers

**Paul R. Cariani**

President & Chief Executive Officer

**William L. Cyr**

Vice President

Power Delivery

**Larry E. LaPlante**

Vice President, Treasurer and

Chief Financial Officer

**Stephen A. Johnson**

Vice President & General Counsel

**Michael A. Thibodeau**

Vice President

Human Resources

**Kurt A. Tornquist**

Controller, Assistant Treasurer

& Assistant Secretary

**Walter J. Elish**

Director of Economic Development

**Officer Changes**

**Frederick C. Bustard**, Vice President of Power Delivery at Maine Public Service, stepped down June 1, 2000, after
completing nearly 41 years of employment.  He joined MPS on June 15, 1959, as a Cadet Engineer.  A native of Fort Fairfield,
Maine, Bustard attended the University of Maine at Orono where, in 1959, he received a BS Degree in Electrical Engineering.
Upon graduation, he joined MPS and throughout his career was employed in the engineering, planning, construction, operations,
and customer service areas of the Company.

**William L. Cyr** was elected by the Directors of Maine Public Service to replace Frederick C. Bustard as Vice President of
Power Delivery, effective June 1, 2000.  A native of Van Buren, Maine, Cyr graduated from the University of Maine at Orono with
a Bachelor of Science degree in Electrical Engineering Technology and was employed by MPS as an Electrical Engineer on June 1,
1982.  In 1989, he was promoted to Supervisor of Electrical Engineering, became Assistant Manager of Engineering in 1993,
advanced to Manager of Engineering and Technical Services in 1996, and was promoted June 1, 1999 to Assistant Vice President
of Power Delivery.

**Michael A. Thibodeau** was promoted to Vice President of Human Resources at Maine Public Service, effective
December 1, 2000.  A native of Presque Isle, Maine, Thibodeau graduated from Husson College with a Bachelor of Science degree
in Accounting.  Employed by MPS since 1981, Thibodeau advanced from Staff Accountant to Rate Analyst in 1983, to Manager of
Rate and Financial Planning in 1985, Assistant Treasurer in 1986, and most recently to Assistant Vice President of Human
Resources in 1991.

**Peter C. Louridas**, Assistant to the President at Maine Public Service, retired January 1, 2001, after completing nearly 37
years of employment.  Born and raised in Tripolis, Greece, Louridas attended Avon Old Farms Preparatory School in Avon,
Connecticut, graduated with distinction in 1961 from the University of Maine at Orono where he received a BS Degree in Electrical
Engineering.  He began employment at MPS as a student engineer the summer of 1961 and joined the Company full-time on June
15, 1964.  He advanced through several electrical and planning engineer positions and was promoted to Manager of Power Supply
and Planning in 1979.  He became Assistant Vice President of Power Supply and Planning in 1984, and advanced to Assistant to
the President in 1991.

Transfer Agent

The Bank of New York

Shareholder Relations Dept. - 11E

P. O. Box 11258, Church Street Station

New York, NY  10286

Tel. No. 1-800-524-4458

E-Mail: Shareowner-svcs@bankofny.com****

**Stock Registrar**

The Bank of New York****

**Annual Meeting**

Tuesday, May 8, 2001

Form 10-K

The Company will provide shareholders

with copies of the Form 10-K upon request.

*Maine Public Service  --  Back Outside Cover*

**Maine Public Service Company**

**209 State Street**

**P. O. Box 1209**

**Presque Isle, Maine  04769-1209**

**Tel. No. (207) 768-5811    -    FAX No. (207) 764-6586**

**Home Page:  http://www.mainepublicservice.com      -     E-Mail:  mainepub@ mfx.net**

Exhibit 99(ac)

92 FERC paragraph 63,012

UNITED STATES OF AMERICA

FEDERAL ENERGY REGULATORY COMMISSION

Maine Public Service CompanyDocket Nos. ER00-1053-00

And ER00-1053-002

CERTIFICATION OF UNCONTESTED OFFER OF SETTLEMENT

(Issued August 14, 2000)

TO THE COMMISSION:

On June 30, 2000, as amended July 28, 2000, Maine Public Service Company (MPS ) filed an offer of settlement in this case
proposing to resolve all issues set for hearing.  Joining MPS as parties to the proposed settlement agreement are Houlton Water
Company and, in alphabetical order, Eastern Maine Electric Cooperative; FPL Energy Maine, Inc. and FPL Energy Aroostook
Valley Company (AVEC), L.L.C.; Northern Maine Independent System Administrator, Inc.; and WPS Energy Services, Inc.  Also
supporting the proposed settlement, albeit not parties to the agreement, are the Maine Public Utilities Commission and the staff of
the Federal Energy Regulatory Commission.  The settlement is, therefore, uncontested.

In January 2000, MPS filed with this Commission proposed changes to its open access transmission tariff, which includes a formula
to adjust transmission rates automatically each year without Commission review.  The proposals, among other matters, would alter
parts of the formula but not others.  In addition, the proposed changes would modify certain terms and conditions of service.

The changes also would enable MPS, for the first time, to offer to retail electric customers transmission service that is priced
separately from other services such as the sale of power - in keeping with the State of Maine's legislative retail access program
compelling public utilities like MPS to unbundle retail transmission service commencing March 1, 2000.  As to wholesale
customers, MPS has been offering such unbundled transmission service to them for a number of years prior to March 1, in
compliance with Order 888.

Houlton Water Company challenged various features of the proposed tariff changes, including the formula used to set rates.  By
order issued March 10, 2000, the

Docket No ER00-1053-000, et al.- 2 -

Commission summarily accepted most of the proposed changes to the terms and conditions of service; rejected another such
proposal dealing with retail stranded costs; while it scheduled hearings to determine whether the rate formula, including the
proposed changes, would produce just and reasonable charges.  Finding that MPS had not shown the formula would work in a
reasonable matter, the order suspended the proposed wholesale rates for the statutory maximum 5-month period, allowing them to
become effective August 11, 2000, subject to refund.  As for the proposed retail rates, because they would apply to new services
with no pre-existing rates in effect, the order suspended them for a "nominal period," allowing them to become effective March 1,
2000 (the starting date of the State of Maine's retail access program), subject to refund.

The proposed settlement appears to resolve matters to the satisfaction of MPS and Houlton as well as the rest of the participants in
the case.  Different aspects of the settlement will be described below.

1.  One significant part deals with the unavoidable loss of some power as it is transmitted.  This matter is handled through a "loss
factor" contained in the rate formula.  The factor represents the amount of power assumed to be lost during transmission which the
transmission customer has the cost-responsibility to replace by purchasing such power either from those with whom it has power
supply contracts or from MPS, the transmission provider.

When MPS initiated this case, proposing in part to modify some of the formula, it made no attempt to change the loss factor which
was set at 3.72% (Tr. 31; 38).  The settlement, however, substantially reduces this number to 1.99% - which will lower the costs of
transmission customers.

The settlement calls for the decreased 1.99% loss factor to be made effective March 1, 2000 for all customers - wholesale and
retail - "in determining the amount of losses a customer must supply . . ." (Article 2.2).  But it also provides that the "impact of the
loss factor change [from 3.72% to 1.99%] on MPS's transmission charges" is not to be reflected until June 1, 2000 (id.).  This 3-month difference is not adequately spelled out in the settlement agreement, the explanatory statement accompanying the
agreement,
or in any of the comments filed. Perhaps it is intended to allow a customer to enjoy the reduced 1.99% loss factor starting March 1
as long as the customer restores the loss from a supplier other than MPS.  On the other hand, perhaps a customer is not permitted to
reap the benefits of the 1.99% loss factor until June 1 if the customer has to use MPS itself to replace the loss.

Docket No ER00-1053-002,- 3 -

Once the 1.99% loss factor kicks in, either March 2 or June 1, the settlement also states that it is to remain in effect for at least two
years: through the end of February 2002 ( if it actually started March 1, 2000) or the end of May 2002 (if it actually started June 1,
2000).  This 3-month difference, both at the beginning and the conceivable end, may give greater flexibility to transmission
customers as well as MPS to make whatever power supply arrangements are needed to cope with losses.

The settlement also recognizes the possibility that the loss factor may change again, although not before March 1 or June 1, 2002.
To prepare for this contingency, MPS is to begin soon (no later than October 1, 2000) making an analysis to determine if a charge
is needed -

with all participants in this case then having an opportunity to contribute in a timely manner to the development of a new loss study
so that a proposed change, if necessary, to the loss factor can be filed with this Commission and the Maine Pubic Utilities
Commission no later than the end of February 2001 (about one year before the 1.99% loss factor may end).

2.  Article 2.3 of the settlement deals with a number of other cost elements that are integral parts of the rate formula.  While a few
will remain as they have been, "permanent" (fixed) without alteration from year-to-year, others are changes from what MPS
initially proposed in this case, thereby making the costs subject to annual adjustment.

(a.)The rate of return on common-equity capital is to remain fixed at 11%, the same rate that the formula used prior to this case.
However, other capital costs, preferred equity and long-term debt, will now use actual figures - based on an average of the start and
end of year actual values.  Of equal importance, MPS's capital structure (needed to calculate the weighted overall return) will now
use actual debt-equity ratios based, again, on an average of the start and end of year actual values.

(b.)As for depreciation rates, they too apparently are to remain fixed.  However, for the first time the rates will be stated in the
formula (explanatory statement, p. 4).  Yet when the depreciation expenses are listed for the 12-month period beginning June 1,
2000, the depreciation rates are omitted (compare Attachment A, Statement AJ with Attachment B, Statement AJ, appended to the
settlement agreement).  Presumably, the omission was not intended.

(c.)With regard to deferred taxes, MPS did not propose to make any changes to these costs when the case began.  Now, through the
settlement, insofar

Docket No ER00-1053-002,- 4 -

as these costs are related to transmission, they will be based on actual end-of-year amounts, including those set forth in FERC
accounts 281, 282, 283, and 190 together with FASB 87 and 106 amounts.

(d.)In connection with load dispatching costs (i.e., scheduling, system control, and dispatch service), which are reflected in account
561, MPS was planning to continue to include these costs in its base transmission rates when this case began.  Now, through the
settlement, the costs for this compulsory ancillary service (which MPS must provide and its transmission customers must take) will
be recovered under the rate portion of Schedule 1 of the ancillary-services segment of the open access transmission tariff.  To
ensure that retail as well as wholesale customers bear their fair share of these costs, including the dispatching costs of the Northern
Maine Independent System Administrator (TR. 8-13), the settlement calls for actual yearly costs to be used - i.e., monthly estimates
that are later reconciled ("trued up") with actual figures.

Under the settlement, it appears that MPS's load dispatching costs that previously were recorded in account 556 have now been
merged into account 561, making account 556 obsolete for purposes here.  Other ancillary services, besides account 561, are now
set forth in schedules apart from the rate portion of Schedule 1.

(e.)Under its formula rates, MPS has been lumping together payroll-related taxes with the rest of its taxes, other than income taxes,
and then allocating these various items on the basis of total transmission plant.  Now, through the settlement, payroll-related taxes
other than income taxes have been separated from the rest of the taxes, and then allocated on the basis of a labor-related factor
which is lower than the total-transmission plant factor still used for the rest of the taxes (compare Attachment A, Statement AK with
Attachment B, Statement AK, appended to the settlement agreement).

(f.)Previously, under its formula rates, to record MPS's customer accounting costs, the generic term "Transmission Customer" was
used. Now, through the settlement, to deal with these costs the terms "Wholesale Transmission Customers" and "Retail
Transmission Customers" are used to assure that the costs are properly allocated.  In addition, the settlement makes sure that any
retail distribution customer accounting costs are not somehow included with the retail transmission customer accounting costs
(explanatory statement, p.5;

Docket No ER00-1053-002,- 5 -

compare Attachment A, Schedule 1a with Attachment B,  Schedule 1a and MPS OATT Attachment J, Schedule 1.1.2, appended to
the settlement agreement).

3.  There are terms and conditions of Schedule 1 ("Scheduling, System Control and Dispatch Service") of the open access
transmission tariff. When the settlement agreement was filed on June 30, 2000, there was a potential policy dispute concerning
these terms and conditions (see Article 2.1, now largely defunct, of the June 30 agreement). However, on July 28, 2000 the dispute
was eliminated when the Schedule 1 terms and conditions were revised to the satisfaction of all parties, particularly Houlton and
MPS.

Pursuant to 18 C.F.R. paragraph 385.602(g), I hereby certify for the Commission's consideration:

(1)The offer of settlement filed June 30, 2000, as amended July 28, 2000 (Maine Public Service Company's motion to substitute
revised tariff sheets in settlement agreement, filed July 28, 2000), together with various documents appended to the offer;

(2)Initial comments filed by Houlton Water Company, Maine Public Utilities Commission, and this Commission's staff;

(3)Reply comments filed by Maine Public Service Company on July 31, 2000;

(4)The official stenographer's report of the conference held March 24, 2000, Volume 1, pages 1 through 63;

(5)All pleadings, orders and other documents of record relating to this case; and

(6)A draft letter order prepared by the parties, as revised, for the Commission to issue.

/s/Raymond M. Zimmet

Administrative Law Judge

D R A F T

FEDERAL ENERGY REGULATORY COMMISSION

Washington, D.C. 20426

In Reply Refer To:

Docket No. ER00-1053-002

Wright & Talisman, P. C.

Attn: Michael E. Small

Counsel for Maine Public Service Company

1200 G Street, N.W.

Suite 600

Washington, D.C. 20005

Dear Mr. Small:

On June 30, 2000, you filed on behalf of Maine Public Service Company, Eastern Maine Electric Cooperative, FPL, Energy Maine,
Inc., FPL Energy AVEC, L. L.C., Houlton Water Company, Northern Maine Independent System Administrator, Inc., and WPS
Energy Services, Inc., a settlement in the above-referenced docket.  On July 18, 2000, staff submitted comments in support of the
settlement.  On July 20, 2000, the Maine Public Utilities Commission and Houlton Water Company also submitted comments in
support of the settlement.  On July 28, 2000, Maine Public Service Company filed a motion to substitute revised tariff sheets in
settlement agreement.  On July 31, 2000, Maine Public Service Company filed reply comments.  On August 14, 2000, the presiding
administrative law judge certified the uncontested settlement to the Commission.

The subject settlement is in the Public interest and is hereby approved.  The Commission's approval of the settlement does not
constitute approval of, or precedent regarding, any principle or issue in this proceeding.  The Commission retains the right to
investigate the rates, terms, and conditions under the just and reasonable and not unduly discriminatory or preferential standard of
section 206 of the Federal Power Act, 16 U.S.C. paragraph 824e.

While Maine Public Service Company has filed tariff sheets to implement the settlement, its proposed designations do not comport
with Order No. 614.  Therefore,

Docket No ER00-1053-002- 2 -

Maine Public Service Company is directed to file tariff sheets, in conformance with Order No. 614, within 30 days of the date of
the order approving the settlement.

The letter order terminates Docket No. ER00-1053-000 and ER00-1053-002.

By direction of the Commission.

Secretary

cc:All Parties

Mr. Mitchell Tannenbaum

Maine Public Utilities Commission

242 State Street

18 State House Station

Augusta, ME 04333 -0018

Exhibit 99(ad)

STATE OF MAINE Docket No. 99-610

PUBLIC UTILITIES COMMISSION November 17, 1999

MAINE PUBLIC SERVICE COMPANY

Application for Approval of a Decrease ORDER APPROVING

in Capital (section 910) (500,000 shares of REDUCTION IN CAPITAL

Common Stock)

WELCH, Chairman; NUGENT & DIAMOND, Commissioners

On August 31, 1999, Maine Public Service Company (MPS or Company) filed with the Commission its request for approval to
decrease its common equity capital by up to 500,000 common shares over a period of five years. This Order approves the
Company's request.

In the aftermath of the divestiture of its generation asset portfolio, MPS seeks to achieve a "more just and reasonable" capital
structure by repurchasing common shares over time. In the absence of doing so, MPS projects that it would have a capital structure
with a common equity component in excess of 55%.1 MPS also notes that approval will allow it to meet the provisions of the
proposed Stipulation in its *Maine Public Service Company, Investigation of Stranded Costs, Transmission And Distribution Utility
Revenue Requirements, And Rate Design of Maine Public Service Compan*y, Docket No. 98-577, where the parties have agreed
that MPS be allowed a capital structure that includes a 51% common equity ratio. MPS acknowledged that repurchasing 500,000
common shares at current prices (roughly $17.50 per share recently) would reduce the Company's common equity ratio to roughly
46% of total capital, but that it does not intend to go below a 51% common equity ratio in the foreseeable future.  Finally, the
Company requests that it be allowed five years to complete its share repurchase program.

We find MPS's request to be appropriate for several reasons. Most importantly, since common equity is the most costly source of
investment capital for a business, rebalancing the Company's post-divestiture capital structure is consistent with the interests of its
ratepayers believe it will reduce MPS's weighted average cost of capital. Whether or not the Stipulation in Docket No. 98-577 is
ultimately approved, we view a 51% common equity ratio more favorably than a 55% common equity ratio for ratemaking purposes
based on our knowledge of capital structures that are customary in the electric utility industry. It is also reasonable to allow MPS
the 5-year window it seeks, because it would permit MPS flexibility in choosing the most opportune times to reacquire its shares.
We note, however, that open market purchases are but one

1

*See*LaPlante Direct Testimony in Docket No. 98-577.

******Order Approving . . . -2- Docket No. 99-610**

avenue open to MPS for the reduction of its common equity ratio. During periods of relatively high stock prices, other mechanisms
may be more attractive from a cost standpoint.

In approving this request, the Commission does not imply approval of the Company's current or projected capital structure or its
current or projected cost of capital for ratemaking purposes.  Furthermore, this Order does not limit or restrict the powers of the
Commission in determining a capital structure or cost rate in future proceedings (although this will be settled for the near term
either through the approval of the proposed Stipulation or a litigated conclusion in Docket No. 98-577). Finally, we intend to
review MPS's specific stock repurchases, particularly in any instances where the purchase price substantially exceeds book value.

Accordingly, we:

O R D E R

1. That Maine Public Service Company is authorized to repurchase up to 500,000 of its common shares over a period of five years
from the date of this Order.

2. That Maine Public Service Company report its doings pursuant to this Order to this Commission not less than annually.

3. That a copy of this Order be mailed to interested parties and this Docket be closed.

Dated at Augusta, Maine, this 17th day of November, 1999.

BY ORDER OF THE COMMISSION

/s/ Dennis L. Keschl

Dennis L. Keschl

Administrative Director

COMMISSIONERS VOTING FOR: Welch

Nugent

Diamond

**Order Approving . . . -3- Docket No. 99-610**

NOTICE OF RIGHTS TO REVIEW OR APPEAL

5 M.R.S.A. section 9061 requires the Public Utilities Commission to give each party to an adjudicatory proceeding written notice
of the party's rights to review or appeal of its decision made at the conclusion of the adjudicatory proceeding. The methods of
review or appeal of PUC decisions at the conclusion of an adjudicatory proceeding are as follows:

1.Reconsideration of the Commission's Order may be requested under Section 1004 of the Commission's Rules of Practice and
Procedure (65-407 C.M.R.110) within 20 days of the date of the Order by filing a petition with the Commission stating the grounds
upon which reconsideration is sought.

2.      Appeal of a final decision of the Commission may be taken to the Law Court by filing, within 30 days of the date of the
Order, a Notice of Appeal with the Administrative Director of the Commission, pursuant to 35-A M.R.S.A. section 1320(1)-( 4)
and the Maine Rules of Civil Procedure, Rule 73, et seq.

3.Additional court review of constitutional issues or issues involving the justness or reasonableness of rates may be had by the
filing of an appeal with the Law Court, pursuant to 35-A M.R.S.A. section 1320(5).

Note: The attachment of this Notice to a document does not indicate the Commission's view that the particular document may be
subject to review or appeal. Similarly, the failure of the Commission to attach a copy of this Notice to a document does not indicate
the Commission's view that the document is not subject to review or appeal.

Exhibit 99(ae)

STATE OF MAINE

PUBLIC UTILITIES COMMISSION Docket No. 99-185

August 11, 2000

MAINE PUBLIC UTILITIES COMMISSION ORDER APPROVING

Investigation of Retail Electric Transmission STIPULATION

Services and Jurisdictional Issue (MAINE PUBLIC

SERVICE COMPANY)

WELCH, Chairman; NUGENT and DIAMOND, Commissioners

I. SUMMARY

In this Order we approve a Stipulation submitted to us by Maine Public Service Company (MPS or Company) and the Office of the
Public Advocate (OPA) which resolves all transmission-related issues as they pertain to MPS as a result of Maine's implementation
of retail access to generation services. Specifically, the Stipulation separates MPS's overall T&D revenue requirement of
$16,640,000 into a transmission component of $2,380,000 and a distribution component of $14,260,000 which includes stranded
costs. The Stipulation also provides that any increase to retail transmission rates resulting from the Company's filing at the Federal
Energy Regulatory Commission (FERC) for new transmission rates effective June 1, 2000 will be offset by a decrease in
distribution rates accomplished by accelerating the amortization or the value in the Company's Asset Sale Gain Account.

II. PROCEDURAL BACKGROUND

Effective March 1, 2000 , through its enactment of the Electric Restructuring Act, 35-A M.R.S.A. sections 3201 - 3214, the Maine
Legislature, deregulated generation services and provided Maine consumers with direct access to generation services. Prior to the
onset of retail access and pursuant to the requirements of 35-A M.R.S.A. section 3208, the Commission concluded an investigation
of the Transmission and Distribution (T&D) utility revenue requirements and the stranded costs for MPS. *See Maine Public
Utilities Commission, Investigation of Stranded Costs, Transmission and Distribution Utility Revenue Requirements and Rate
Design of Maine Public Service Compan*y, Docket No. 98-577, Order Approving Stipulation (Dec. 1, 1999). In that Order, we
established an overall T&D revenue requirement for MPS, including stranded costs, of $16,640,000.

After careful review, we have concluded that FERC has, through its Order No. 888, clearly asserted jurisdiction over retail
transmission services when a state elected to unbundle electric supply and allow retail customers access to generation services on a
competitive basis. *Public Utilities Commission, Investigation of Central Maine Power Company's Stranded Costs, Transmission
and Distribution Utility Revenue Requirement and Rate Design,*Docket No. 97-580, Order at 133 (March 19, 1999). Therefore,
on.

**Order Approving Stipulation - 2 - Docket No. 99-185**

March 30, 1999, we initiated this docket to investigate issues involving the jurisdictional split between FERC-regulated
transmission facilities and state-regulated distribution facilities.1

In a Procedural Order dated December 7, 1999, the Examiner in this case noted

that:

[T]here appears to be general agreement that we should move to completely separate transmission costs from the state-jurisdictional
revenue requirements. However, there is also agreement that sufficient time does not exist for this to occur by March 1, 2000.
Accordingly, the Commission will use this investigation to determine the costs appropriately considered distribution-related. 2

On February 8, 2000, MPS made its cost separations filing with the Commission. The Company's filing was the subject of both
formal and informal discovery. On May 22, 2000, we received a Stipulation (attached and incorporated into this Order as
Attachment 1) signed by the Company and the OPA which resolved all issues in this case as they pertain to MPS. All other
intervenors who expressed an interest in the issues in this case as they pertained to MPS (the Industrial Energy Consumers Group,
and the Independent Energy Producers of Maine) have not objected to the proposed Stipulation.

III. DESCRIPTION OF THE STIPULATION

MPS and OPA agree that the total T&D revenue requirement of $16,640,000 should be separated into a distribution, or "D,"
revenue requirement of $14,260,000 and a transmission revenue requirement of $2,380,000. Based upon the rate formula filed at
the FERC by the Company, and which took effect on June 1, 2000, the Company has estimated that the effective retail transmission
rate increase compared to the amount of transmission costs separated from the combined T&D rate would be $591,000.  The parties
to the Stipulation agree that given rate stability concerns, such an increase to retail rates so shortly after the onset of electric
restructuring would be inappropriate. The parties thus agreed to accelerate the amortization of the Company's Asset Sale Gain
Account by a sufficient amount to offset the $591,000 increase filed by

1 This investigation was initiated as a generic investigation and subsequently developed into an investigation of the transmission
costs and issues for each of the state's investor-owned utilities, including MPS.

2 While MPS filed transmission tariffs with FERC to be effective on March 1, 2000, the distribution rates were calculated on a
residual basis so that total T&D rates equaled the rates set by this Commission in Docket No. 98-577.

**Order Approving Stipulation - 3 - Docket No. 99-185**

the Company. In addition, once the actual increase for this year is agreed to, including the return of any under- or over-collections,
the amortization will be adjusted appropriately to retain total rates and total revenue requirements at the level approved by the
Commission in Docket No. 98-577.

IV. DECISION

As stated in past cases, in deciding whether to approve a stipulation we apply the following criteria:

1. whether the parties joining the stipulation represent a sufficiently broad spectrum of interests that the Commission can be sure
that there is no appearance or reality of disenfranchisement; and

2. whether the process that led to the stipulation was fair to all parties; and

3. whether the stipulated result is reasonable and is not contrary to legislative mandate.

*See Central Maine Power Company, Proposed Increase in Rates,*Docket No. 92-345

(II), Detailed Opinion and Subsidiary Findings (Me. P.U.C.) Jan. 10, 1995, and *Maine Public Service Company, Proposed
Increase in Rates (Rate Design),*Docket No. 95- 52, Order (Me. P.U.C. June 26, 1996). We have also recognized that we have an
obligation to ensure that the overall stipulated result is in the public interest. *See Northern Utilities, Inc., Proposed Environmental
Response Cost Recovery,*Docket No. 96-678, Order Approving Stipulation (Me. P.U.C. April 28, 1997). We find that the proposed
Stipulation in this case meets all of the above criteria.

The Stipulation was entered into by the Company and the OPA after numerous technical and settlement conferences. The non-signing parties to this matter had a full opportunity to participate in these conferences and do not object to the
Stipulation. We,
therefore, find that both criteria 1 and 2, set forth above, have been satisfied.

We also  find that the stipulated result is reasonable and is both consistent with the public interest and legislative mandates. By
accelerating the amortization of the Asset Sale Gain Account, the Stipulation provides rate stability to customers and avoids rate
increases immediately following the onset of retail access. We believe this result as well as all other provisions of the Stipulation
are wholly consistent with our restructuring objectives enunciated in past cases. *See Docket No. 97-580, supra.*at 116-119.

Accordingly, it is

O R D E R E D

**Order Approving Stipulation  - 4 - Docket No. 99-185**

1. That the Stipulation submitted by Maine Public Service Company and the Public Advocate, submitted May 24, 2000 and dated
May 22, 2000 is approved;

2. That MPS is authorized to accelerate the amortization of its Asset Sale Gain Account by an amount sufficient to offset any
increase in   transmission rates approved by FERC in Docket No. ER00-1053-000.

Dated at Augusta, Maine, this 11 th day of August, 2000.

BY ORDER OF THE COMMISSION

Dennis L. Keschl

Administrative Director

COMMISSIONERS VOTING FOR: Welch

Nugent

Diamond

**Order Approving Stipulation - 5 - Docket No. 99-185**

NOTICE OF RIGHTS TO REVIEW OR APPEAL

5 M.R.S.A. section 9061 requires the Public Utilities Commission to give each party to an adjudicatory proceeding written notice
of the party's rights to review or appeal of its decision made at the conclusion of the adjudicatory proceeding. The methods of
review or appeal of PUC decisions at the conclusion of an adjudicatory proceeding are as follows:

1. Reconsideration of the Commission's Order may be requested under Section 1004 of the Commission's Rules of Practice and
Procedure (65- 07 C.M.R.110) within 20 days of the date of the Order by filing a petition with the Commission stating the grounds
upon which reconsideration is sought.

2. Appeal of a final decision of the Commission may be taken to the Law Court by filing, within 30 days of the date of the Order, a
Notice of Appeal with the Administrative Director of the Commission, pursuant to 35-A M.R.S.A. section 1320(1)-(4) and the
Maine Rules of Civil Procedure, Rule 73, et seq.

3. Additional court review of constitutional issues or issues involving the justness or reasonableness of rates may be had by the
filing of an appeal with the Law Court, pursuant to 35-A M.R.S.A. section 1320(5).

Note: The attachment of this Notice to a document does not indicate the Commission's view that the particular document may be
subject to review or appeal. Similarly, the failure of the Commission to attach a copy of this Notice to a document does not indicate
the Commission's view that the document is not subject to review or appeal.

Exhibit 99(af)

January 10, 2001

Dennis L. Keschl

Administrative Director

Public Utilities Commission

18 State House Station

Augusta, ME 04333

Stephen G. Ward

Public Advocate

Office of the Public Advocate

112 State House Station

Augusta, ME 04333-0112

RE: Further Settlement Agreement with Maine Parties.

Dear Dennis and Stephen:

This letter sets forth the terms of an agreement by and among Central Maine Power Company ("CMP"), Bangor Hydro-Electric
Company ("BHE") and Maine Public Service Company ("MPS") (collectively the "Maine Owners") and the Maine Public Utilities
Commission ("MPUC") and the Maine Office of Public Advocate (collectively the "Maine Agencies") to resolve all matters related
to the Maine Owners' and Maine Agencies' obligations to determine the Maine Yankee Power Costs under Article 4 of the Further
Settlement Agreement with Maine Parties, FERC Docket Nos. ER98-570-000 and EL98-14-000 (the "Settlement Agreement").

Background

Pursuant to the Settlement Agreement, the Maine Owners agreed to hold Maine retail ratepayers harmless from any increase in the
actual replacement power costs incurred from 2000 - 2004 over the replacement power costs assumed by the Maine Owners in
reaching their decision to support the shut down of the Maine Yankee nuclear power plant.  For each year, the Maine Owners are
required by the Settlement Agreement to designate a "benchmark" price to represent the market price to be used in calculating the
Market Replacement Power Costs for the year.  The Maine Owners selected a benchmark for 2001 to which Maine Agencies have
objected.  This Letter Agreement is the result of discussions among the Maine Owners and the Maine Agencies to resolve all the
issues related to the selection of the benchmark for 2001 and in the case of CMP and BHE, all of the potential issues related to the
selection of future benchmarks for the remaining years -- 2002, 2003, and 2004.

-1-

January 10, 2001

Agreement

The Maine Owners and the Maine Agencies agree as follows.

1. CMP agrees that, in full satisfaction of all of its duties and obligations under Article 4 of the Settlement Agreement,
CMP stranded costs, as defined in 35-A M.R.S.A. sec 3208, will be reduced by $12,030,800.  The reduction shall be effective on
March 1, 2002.

2. BHE agrees that, in full satisfaction of all of its duties and obligations under Article 4 of the Settlement Agreement,
BHE stranded costs , as defined in 35-A M.R.S.A. sec 3208, will be reduced by $2,216,200.  The reduction shall be effective on
March 1, 2002.

3. MPS agrees that:

(a) For the calendar year 2001, the benchmark price for determining Maine Public Service Company's Market
Replacement Power Costs, as defined in Article 4 Settlement, shall be 4.0 cents per kwh.

(b) Maine Public Service Company hereby finally and irrevocably designates as the benchmark for determining its
Market Power Replacement Costs in each of the years 2002, 2003, and 2004, the Section 3204 (4) sales auction price as determined
in each year in the manner set forth in Article 4.

(c) For the purpose of implementing subparagraph (b) above, the provisions of Article 4 shall, except as expressly
varied by this paragraph 3, remain in full force and effect with respect to Maine Public Service.

4. The Maine Agencies agree that they will not assert any rights they may have under Article 4 of the Settlement
Agreement, except as may be preserved with respect to MPS in accordance with the terms of Paragraph 3 above.  Furthermore, the
Maine Agencies agree that they will not seek any other ratemaking adjustment or disallowance of costs related to the Maine
Owners' decision to support the shutdown of Maine Yankee, other than those already agreed to by the Maine Owners pursuant to
the Separate Settlement between the Maine Public Utilities Commission, the Maine Public Advocate, Maine Yankee and the Maine
Owners on the prudency of the shutdown as approved by FERC under Docket Nos. ER98-570-00 (Maine Yankee Rate Case) and
EL98-14-00 (Compliant Case, Maine Office of Public Advocate v. Maine Yankee).

5. The parties agree that the calculation of the return on the Maine Owners' Maine Yankee equity investments shall not be
affected by this Letter Agreement.  The Maine Owners further agree that amounts agreed to as reductions in stranded costs will not
impact the computation of earnings for any earnings sharing computation under any Performance-based Ratemaking Plan adopted
for any of the Maine Owners.

-2-

January 10, 2001

6. This Letter Agreement constitutes the entire Agreement between the Maine Owners and the Maine Agencies relating to
Maine Yankee Replacement Power Costs and supersedes any and all other agreements, negotiations, arrangements and
understandings, oral or written, relating to the matters provided for herein.  This Letter Agreement may not be modified except by
written  agreement executed by each of the parties hereto.

7. This Letter Agreement shall be governed by and construed and enforced in accordance with the laws of the State of
Maine.

8. This Letter Agreement shall be effective when duly executed by the parties named below and shall be binding upon and
inure to the benefit of the successors and assigns of the parties hereto.

Sincerely,

/s/ Kevin Gordon

Kevin Gordon, Counsel to

Central Maine Power Company

/s/William S. Harwood

William S. Harwood, Counsel to

Bangor Hydro-Electric Company

/s/ Steven A. Johnson

Steven A. Johnson, General Counsel

Maine Public Service Company

**ACCEPTED:**

**Maine Agencies**

Maine Public Utilities Commission

/s/ James A. Buckley

By:

Its:

Maine Office of the Public Advocate

/s/Steven Ward

Steven Ward

Public Advocate

-3-