SECURITIES AND EXCHANGE COMMISSION

Washington, D. C.  20549

FORM 10-Q

Quarterly Report Under Section 13 or 15(d) of

The Securities Exchange Act of 1934

For Quarter Ended

March 31, 2002

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 office)

04769

(Zip Code)

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

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     .

(APPLICABLE ONLY TO CORPORATE ISSUERS:)

Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the close of the period
covered by this report.

Common Stock, $7.00 par value - 1,573,638 shares

Form 10-Q

PART 1.  FINANCIAL INFORMATION



Item 1. Financial Statements



See the following exhibits - Maine Public Service Company and Subsidiaries Condensed Consolidated Financial
Statements, including a statement of consolidated income for the quarter ended March 31, 2002, and for the corresponding
period of the preceding year; a consolidated balance sheet as of March 31, 2002, and as of December 31, 2001, the end of
the Company's preceding fiscal year; and a statement of consolidated cash flows for the period January 1 (beginning of the
fiscal year) through March 31, 2002, and for the corresponding period of the preceding year.

In the opinion of management, the accompanying unaudited condensed consolidated financial statements present fairly the
financial position of the Companies at March 31, 2002 and December 31, 2001, and the results of their operations for the
three months ended March 31, 2002 and their cash flows for the three months ended March 31, 2002, and for the
corresponding period of the preceding year.





-2-

MAINE PUBLIC SERVICE COMPANY AND SUBSIDIARIES

STATEMENTS OF CONSOLIDATED OPERATIONS

(Unaudited)

(Dollars in Thousands Except Per Share Amounts)

|                                                     | Three Months Ended
|---------------------------------------------------- | ------------------
|                                                     | March 31,         
|                                                     | 2002              
|Operating Revenues                                   | $10,999           
|EA-Standard Offer Service Margin                     | 407               
|Total Revenues                                       | 11,406            
|Operating Expenses                                   |                   
|Energy Supply                                        | 1,201             
|T&D Operation and Maintenance                        | 3,089             
|Depreciation                                         | 655               
|Amortization of Stranded Costs                       | 2,461             
|Amortization                                         | 59                
|Taxes Other Than Income                              | 357               
|Provision for Income Taxes                           | 1,450             
|Total Operating Expenses                             | 9,272             
|Operating Income                                     | 2,134             
|Other Income (Deductions)                            |                   
|Equity in Income of Associated Companies             | 88                
|Allowance for Equity Funds Used During Construction  | 14                
|Provision for Income Taxes                           | (73)              
|Other - Net                                          | 86                
|Total                                                | 115               
|Income Before Interest Charges                       | 2,249             
|Interest Charges                                     |                   
|Long-Term Debt and Notes Payable                     | 394               
|Less Carrying Costs-Stranded Costs and Allowance     |                   
|for Borrowed Funds used During Construction          | (250)             
|Total                                                | 144               
|Net Income Available for Common Stock                | $2,105            
|Average Shares Outstanding (000's)                   | 1,574             
|Basic and Diluted Earnings Per Share of Common Stock | $1.34             
|Dividends Declared per Common Share                  | $0.35             

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

-3-

MAINE PUBLIC SERVICE COMPANY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Dollars in Thousands)



|                                                          | Mar. 31, 2002 | December 31,
|--------------------------------------------------------- | ------------- | ------------
|ASSETS                                                    | (Unaudited)   | 2001        
|Utility Plant                                            
|Electric Plant in Service                                 | $82,366       | $82,665     
|Less Accumulated Depreciation                             | 38,139        | 37,783      
|Net Electric Plant in Service                             | 44,227        | 44,882      
|Construction Work-in-Progress                             | 1,914         | 876         
|Total                                                     | 46,141        | 45,758      
|Investment in Associated Companies                       
|Maine Yankee Atomic Power Company                         | 3,104         | 3,154       
|Maine Electric Power Company, Inc.                        | 483           | 447         
|Total                                                     | 3,587         | 3,601       
|Net Utility Plant and Investments                         | 49,728        | 49,359      
|Current Assets                                           
|Cash and Cash Equivalents                                 | 5,431         | 5,496       
|Accounts Receivable - Net                                 | 5,432         | 5,544       
|Unbilled Base Revenue                                     | 1,177         | 1,094       
|Inventory                                                 | 668           | 623         
|Prepayments                                               | 310           | 426         
|Total                                                     | 13,018        | 13,183      
|Regulatory Assets                                        
|Uncollected Maine Yankee Decommissioning Costs            | 22,346        | 24,708      
|Recoverable Seabrook Costs                                | 15,831        | 16,109      
|Regulatory Assets - SFAS 109 & 106                        | 7,578         | 7,597       
|Deferred Fuel and Purchased Energy Costs                  | 11,428        | 12,107      
|Regulatory Asset - Power Purchase Agreement Restructuring | 6,892         | 7,255       
|Unamortized Debt Expense                                  | 2,672         | 2,798       
|Deferred Regulatory Costs, less accumulated amortization  | 1,506         | 1,428       
|Total                                                     | 68,253        | 72,002      
|Other Assets                                             
|Restricted Investments                                    | 7,502         | 8,104       
|Miscellaneous                                             | 549           | 643         
|Total                                                     | 8,051         | 8,747       
|Total Assets                                              | $139,050      | $143,291    
|CAPITALIZATION AND LIABILITIES                            |              
|Capitalization                                           
|Common Shareholders' Equity                              
|Common Stock                                              | $13,071       | $13,071     
|Paid-in Capital                                           | 44            | 43          
|Retained Earnings                                         | 37,781        | 36,226      
|Treasury Stock, at cost                                   | (6,606)       | (6,609)     
|Total                                                     | 44,290        | 42,731      
|Long-Term Debt (less current maturities)                  | 31,965        | 33,765      
|Current Liabilities                                      
|Long-Term Debt Due Within One Year                        | 2,950         | 1,175       
|Notes Payable                                             | 1,350         | 3,950       
|Accounts Payable                                          | 5,383         | 5,521       
|Accounts Payable - EA Escrow                              | 1,070         | 1,090       
|Dividends Declared                                        | 551           | 551         
|Customer Deposits                                         | 32            | 22          
|Interest and Taxes Accrued                                | 1,555         | 562         
|Total                                                     | 12,891        | 12,871      
|Deferred Credits                                         
|Uncollected Maine Yankee Decommissioning Costs            | 22,346        | 24,708      
|Deferred Income Tax                                       | 22,243        | 21,906      
|Investment Tax Credits                                    | 212           | 220         
|Deferred Gain & Related Accounts - Generating Asset Sale  | 2,415         | 3,593       
|Miscellaneous                                             | 2,688         | 3,497       
|Total                                                     | 49,904        | 53,924      
|Total Capitalization and Liabilities                      | $139,050      | $143,291    



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



-4-

MAINE PUBLIC SERVICE COMPANY AND SUBSIDIARIES

Statements of Consolidated Cash Flows

(Unaudited)

(Dollars in Thousands)



|                                                                                  | Three Months Ended
|--------------------------------------------------------------------------------- | ------------------
|                                                                                  | March 31,         
|                                                                                  | 2002              
|Cash Flow From Operating Activities                                               |                   
|Net Income                                                                        | $2,105            
|Adjustments to Reconcile Net Income to Net Cash Provided By (Used For)
Operations |                   
|Depreciation                                                                      | 655               
|Amortization                                                                      | 336               
|Amortization of Deferred Gain from Asset Sale                                     | (1,046)           
|Amortization of W/S Upfront Payment                                               | 363               
|Income on Tax Exempt Bonds-Restricted Funds                                       | (17)              
|Deferred Income Taxes - Net                                                       | 263               
|AFUDC                                                                             | (18)              
|Change in Deferred Fuel & Purchased Energy                                        | 679               
|Change in Deferred Regulatory and Debt Issuance Costs                             | (80)              
|Change in Deferred Regulatory Liability - Transition Costs                        | (4)               
|Change in Deferred Regulatory Liability - NEIL Refund                             | (1,005)           
|Change in Benefit Obligation                                                      | 176               
|Change in Current Assets and Liabilities                                          | 999               
|Other                                                                             | 251               
|Net Cash Flow Provided By Operating Activities                                    | 3,657             
|Cash Flow From Financing Activities                                               |                   
|Dividend Payments                                                                 | (551)             
|Retirements on Long-Term Debt                                                     | (25)              
|Short-Term Debt Repayments, Net                                                   | (2,600)           
|Net Cash Flow Used For Financing Activities                                       | (3,176)           
|Cash Flow From Investing Activities                                               |                   
|Drawdown of Tax Exempt Bonds Proceeds                                             | 620               
|Investment in Electric Plant                                                      | (1,166)           
|Net Cash Flow Used For Investment Activities                                      | (546)             
|Increase (Decrease) in Cash and Cash Equivalents                                  | (65)              
|Cash and Cash Equivalents at Beginning of Year                                    | 5,496             
|Cash and Cash Equivalents at End of Period                                        | $5,431            
|Change in Current Assets and Liabilities Providing (Utilizing)                    |                   
|Cash From Operating Activities                                                    |                   
|Accounts Receivable                                                               | $112              
|Unbilled Revenue                                                                  | (84)              
|Inventory                                                                         | (44)              
|Prepayments                                                                       | 117               
|Accounts Payable & Accrued Expenses                                               | 889               
|Other Current Liabilities                                                         | 9                 
|Total Change                                                                      | $999              
|Supplemental Disclosure of Cash Flow Information:                                 |                   
|Cash Paid During the Period For:                                                  |                   
|Interest                                                                          | $307              
|Income Taxes                                                                      | $328              

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



-5-

**NOTES TO CONSOLIDATED STATEMENTS**

1.         SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

The accompanying unaudited consolidated financial statements include the accounts of the Company, its wholly-owned
unregulated marketing subsidiary, Energy Atlantic, LLC (EA) and its wholly-owned Canadian subsidiary, Maine and New
Brunswick Electrical Power Company, Limited (ME&NB).

The Company is subject to the regulatory authority of the Maine Public Utilities Commission (MPUC) and, with respect to
wholesale rates, the Federal Energy Regulatory Commission (FERC).

The accompanying unaudited consolidated financial statements should be read in conjunction with the 2001 Annual
Report, an integral part of Form 10-K.  Certain financial statement disclosures have been condensed or omitted but are an
integral part of the 2001 Form 10-K.  These statements reflect all adjustments that are, in the opinion of management,
necessary to a fair statement of results for interim periods presented.  All such adjustments are of a normal recurring nature.
The Company's significant accounting policies are described in the Notes to Consolidated Financial Statements of the
Company's Annual Report filed with the Form 10-K.  For interim reporting purposes, these same accounting policies are followed.

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.

Certain reclassifications have been made to the 2001 financial statement amounts in order to conform to the 2002  presentation.

2.         ENERGY ATLANTIC (EA)

EA's net income for the first quarter of 2002 was $165,000 compared to $741,000 for the first quarter of last year.  The
decrease in net income reflects the expiration of several large competitive retail contracts in Central Maine Power's (CMP)
service territory, as well as the expiration of the standard offer service to customers in CMP's service territory on February
28, 2002 as described below.

During 2001, Energy Atlantic's sales fell into two general categories:  Standard Offer Service (SOS) in CMP's service
territory and competitive energy supply to individual retail customers (CES).  Except as stated below, the power for those
sales was provided entirely under a Wholesale Power Sales Agreement (the "Agreement") with Engage Energy America,
LLC ("Engage").  The Agreement expired on February 28, 2002.

Under this Agreement, all revenues from both SOS and CES sales were paid directly to an Escrow Agent that disbursed
them in accordance with instructions from Engage.  For SOS sales, EA received reimbursement for certain expenses and a
portion of the net profit that was reported as SOS margin.  During the first quarter of 2002, EA received $407,000 from
SOS margin compared to $983,000 for the first quarter of 2001.  This decrease is due primarily to the expiration of SOS on
February 28, 2002 and an increase in associated run-out expenses.

Although EA's rights to SOS sales in CMP's service territory expired on February 28, 2002, final distribution of the SOS
margin under the Agreement will not be made until various power authorities have finalized the power costs for those sales.
EA expects this process to be completed during the third quarter of 2002.

During the first quarter of 2001, EA also made several CES sales to individual commercial and industrial customers under
contracts that expired during 2001.

-6-

As part of the settlement with Engage, EA was permitted to obtain power from other wholesale suppliers beginning in
June, 2001.  As a result, EA has been able to secure one other source of supply in order to support new CES sales.  In
addition, EA has entered into a contract for  40% of the output of the Wheelabrator-Sherman energy facility for the two
years beginning March 1, 2002.

The output from this take-or-pay contract  amounts to approximately 55,000 MWH annually and will be used to provide
additional CES sales in the Company's service territory.  This is EA's first take-or-pay contract, which carries more
counterparty risk than others entered into to date.  To mitigate this risk, EA has entered into a contract with NB Power,
whereby  NB Power will buy W-S output in excess of load requirements in the Company's service territory at a rate indexed
to 3% Sulphur Max No. 6 residential oil into New York Harbor, which is intended to reflect NB Power's avoided cost,
subject to a floor and ceiling.  In addition, NB Power will sell power to EA when load exceeds W-S output at a fixed on and
off-peak rate.  In addition to the risks discussed above, EA, in conjunction with these contracts for supply and sales, is also
subject to the following risks:

-     Market liquidity - Ability to buy or sell energy on the open market

-     Forecasting - Accuracy of estimated supply requirements

-     Deliverability - Energy supply availability

-     Transmission - Reliance on third-parties for energy delivery from sources to customers

-     Volumetric - Changes in customer load requirements

-     Market-based cost - Market index pricing per NB Power contract discussed above

-     Credit risks - Customers ability to pay



EA's CES sales to retail customers during 2002 will produce far less revenue than EA earned from SOS in CMP's territory.
EA continues to pursue additional supply to support new sales.

The Company operates in two segments, with Maine Public Service Company (MPS) providing regulated transmission and
distribution services and EA performing power marketing activity as described above.  The segments' activity for the three
months ended March 31, 2002 and 2001 is summarized in the table below.

Three Months Ended

(Dollars in Thousands)

|                                 |        | 3/31/02  |          |         | 3/31/01  |         
|-------------------------------- | ------ | -------- | -------- | ------- | -------- | --------
|                                 |        |          | Total    |         |          | Total   
|                                 | EA     | MPS      | Company  | EA      | MPS      | Company 
|Operating Revenues               | $1,400 | $9,599   | $10,999  | $11,223 | $9,863   | $21,086 
|EA Standard Offer Service Margin | 407    | -        | 407      | 983     | -        | 983     
|Total Revenues                   | 1,807  | 9,599    | 11,406   | 12,206  | 9,863    | 22,069  
|Operations & Maintenance Expense | 1,558  | 6,264    | 7,822    | 11,028  | 5,752    | 16,780  
|Taxes                            | 105    | 1,345    | 1,450    | 490     | 1,443    | 1,933   
|Total Operating Expenses         | 1,663  | 7,609    | 9,272    | 11,518  | 7,195    | 18,713  
|Operating Income (Loss)          | 144    | 1,990    | 2,134    | 688     | 2,668    | 3,356   
|Other Income & Deductions        | 21     | 94       | 115      | 53      | 59       | 112     
|Income Before Interest Charges   | 165    | 2,084    | 2,249    | 741     | 2,727    | 3,468   
|Interest Charges                 | -      | 144      | 144      | -       | 429      | 429     
|Net Income                       | $165   | $1,940   | $2,105   | $741    | $2,298   | $3,039  
|Total Assets                     | $5,970 | $133,080 | $139,050 | $6,782  | $143,096 | $149,878

-7-

3.         RESTRUCTURING AND IMPLEMENTATION OF MULTI-YEAR RATE PLAN

Restructuring

As previously reported, 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 described in the
Company's 2001 Form 10-K.



Under EITF 97-4, the Company is permitted to continue to defer certain costs as regulatory assets in instances where
recovery through future regulatory cash flows is anticipated.  At March 31, 2002, $68.3 million of regulatory assets
remained on the Company's books.  These regulatory assets are being amortized over various periods, up to 15 years,  in
accordance with the MPUC approved Phase II filing on stranded cost recovery.  The major components include the
remaining investment in Seabrook, the  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.  As approved by the MPUC, a portion of the amortization of these regulatory assets is
offset by the recognition of the deferred gain from the sale of the generating assets (see Note 6. "Generating Asset
Divestiture").  As of March 31, 2002, $2.4 million of deferred gain remains to be utilized.

Rate Stipulation  Effective March 1, 2000

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 included 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, representing an amount equal to 35% of the available value from the sale of the generating 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 originally approved contracts for two large industrial customers and their
current special discount rates, designed for customer retention, as revenue and a regulatory asset.  This flexible pricing
adjustment resulted in recognition of $313,000, $961,000 and $380,000 of revenues and a corresponding regulatory asset
for the first quarter of 2002 and for the years 2001 and 2000, respectively.  These regulatory assets will be recovered in
future rates.  The annual revenue requirement associated with the recovery of stranded costs will be reviewed at least every
three years, and was reviewed in late 2001.  See "MPUC Approves Stranded Cost Revenue Requirements Effective March
1, 2002" for additional information.

MPUC Approves Stranded Cost Revenue Requirements Effective March 1, 2002

On May 8, 2001, the MPUC issued a notice of investigation to determine whether the Company's annual recovery of $12.5
million in stranded investment must be changed, effective March 1, 2002, to reflect any changes in its stranded costs.  On
July 12, 2001, the Company filed its proposal in which it advocated continuing the $12.5 million annual recovery of
stranded costs and also proposed to begin the recovery of deferred amounts associated with the discounted rates it had made
available to certain industrial customers.  Also at issue in the proceeding was an insurance refund associated with Maine
Yankee, of which the Company's share is $1,005,000. As of December 31, 2001, the Company reflected the refund as a
miscellaneous deferred credit.  A stipulation approved by the MPUC on January 7, 2002,  with the appropriate order issued
on February 27, 2002, includes annual stranded cost recovery of $11,540,000 and a 15% sharing of the Maine Yankee
insurance refund with the Company's shareholders, thereby leaving the rates charged to core retail customers the same.

-8-

MPUC Conducts Investigation of Rate Design

On May 8, 2001, the MPUC issued a Notice of Investigation into certain common fundamental issues regarding the rates
for the State's three major electric utilities - the Company, Central Maine Power Company (CMP) and Bangor
Hydro-Electric Company (BHE).  These issues have been defined by the MPUC as follows:



(i) The extent to which stranded cost recovery should be shifted from variable KWH and kw charges to a fixed charge;

(ii) The redefinition of time of use periods for rate design; and

(iii) The elimination or reduction of seasonal rates.

The Company believes its stranded costs should be recovered through fixed charges that its customers cannot avoid by
reducing or eliminating their usage.  Such a fixed charge would reduce the risk of the Company's ability to recover its
stranded costs from customers.  The Company, together with CMP and BHE,  filed testimony in support of its position on
April 16, 2002.  The Company has recommended that 50% of the stranded costs allocable to residential and small to
medium commercial and industrial customers and 25% of the stranded cost allocable to large industrial customers be
immediately collected through a fixed charge, with all remaining stranded costs to be phased in during the Company's next
rate case.  The Company also recommended immediate elimination of its seasonal rates.

The Company cannot predict the nature or the outcome of any decision in this proceeding.

4.           INCOME TAXES

A summary of Federal and State income taxes charged to income is presented below.  For accounting and ratemaking
purposes, income tax provisions included in "Operating Expenses" reflect taxes applicable to

revenues and expenses allowable for rate making purposes, with the exception of Energy Atlantic activity, which is above
the line and not allowable for ratemaking purposes.  The tax effect of items not included in rate base is allocated as "Other
Income (Deductions)".

|                     | (Dollars in Thousands)
|-------------------- | ----------------------
|                     | Three Months Ended    
|                     | March 31,             
|                     | 2002                  
|Current income taxes | $1,205                
|Deferred income tax  | 325                   
|Investment credits   | (7)                   
|Total income taxes   | $1,523                
|Allocated to:        |                       
|Operating Income     | $1,450                
|Other income         | 73                    
|Total                | $1,523                

For the three months ended March 31, 2002 and 2001, the effective income tax rates were 41.9% and 39.4%, respectively.
The increase in the effective tax rate from 2001 to 2002 is a result of fluctuations in the foreign exchange adjustment from
the Canadian subsidiary. The principal reasons  for the effective tax rates differing from the US federal income tax rate are
the contribution to net income of the Company's Canadian subsidiary and  flow through items, principally Seabrook
amortization,  required by regulation and state income taxes.

-9-

The following summarizes accumulated deferred income taxes established on temporary differences under SFAS 109 as of
March 31, 2002 and December 31, 2001.



|                                      | (Dollars in Thousands)
|------------------------------------- | ----------------------
|                                      | March 31,             
|                                      | 2002                  
|Seabrook                              | $8,852                
|Property                              | 6,680                 
|Flexible pricing revenue              | 651                   
|Deferred fuel                         | 3,775                 
|Generating asset sale                 | (542)                 
|W/S up-front payment                  | 2,750                 
|Pension and post-retirement benefits  | (127)                 
|Other                                 | 204                   
|Net accumulated deferred income taxes | $22,243               



5.           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 October11, 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 incurred no liability for 2001.
Pursuant to the Company's filing in early 2002, on January 24, 2002, the MPUC issued a notice of settlement for the
remaining years 2002, 2003 and 2004.  Since the replacement power benchmark prices for the three-year period were set
below the Maine Yankee-assumed prices for these three years, the Commission concurred with the Company's assertion
that, in effect, the calculations would result in no additional liability.



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.

-10-

From April, 1999 until February, 2000, the Company amortized an additional $150,000 per month as part of a stipulation
as described in Note 3, above.  From March 1, 2001 until February 28, 2002, the Company amortized $1.0 million of the
Maine Yankee replacement power cost balance and other deferred fuel.  The MPUC, on January 27, 2002, approved a
Stipulation providing for the recovery of stranded investment, for a two-year period March 1, 2002 until February 29, 2004,
which includes the Company's share of Maine Yankee decommissioning expenses, Maine Yankee replacement power costs,
Maine Yankee deferred fuel and the remaining Maine Yankee investment.  Accordingly, the Company began deferring
$107,700 per month in March, 2002.  As of March 31, 2002, deferred fuel of  $11.4 million is reflected as a regulatory
asset, which includes the Maine Yankee deferral, as well as deferred Wheelabrator-Sherman fuel costs.



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,  September 2000, February 2001, December
2001, and again in March 2002, 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 March 31, 2002 is carrying on its consolidated
balance sheet a regulatory asset and a corresponding liability in the amount of $22.3 million, which reflects the Company's
5% share of Maine Yankee's March 2002 estimate of decommissioning costs.



In May 2000, Maine Yankee terminated its decommissioning operations contract with Stone & Webster Engineering
Corporation (Stone & Webster) pursuant to terms of the contract.  Stone & Webster disputed Maine Yankee's grounds for
the termination.  In June 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.



Upon the contract termination, Maine Yankee temporarily assumed the general contractor role and entered into interim
agreements with Stone & Webster and obtained assignments of several subcontracts in order to allow decommissioning
work to continue and to avoid the adverse consequences of an abrupt or inefficient demobilization from the Plant site.
Decommissioning of the Plant site continued  with major emphasis directed to maintaining the schedule on critical-path
projects such as construction of an independent spent fuel storage installation (ISFSI) and preparation of the Plant's reactor
vessel for eventual shipment to an off-site disposal facility.  After assessing its long-term alternatives for safely and
efficiently completing the decommissioning, including evaluating proposals from prospective successor general contractors,
on January 26, 2001, Maine Yankee announced that it would continue to manage the project itself.



In June 2000, Federal Insurance Company (Federal), which had provided performance and payment bonds in the amount
of approximately $38.5 million each in connection with the decommissioning operations contract, filed a
declaratory-judgement complaint against Maine Yankee in the Bankruptcy Court in Delaware, which was subsequently
transferred to the United States District Court in Maine.  The complaint alleged that Maine Yankee had improperly
terminated the decommissioning operations contract with Stone & Webster and had failed to give proper notice of the
termination to Federal under the contract, and that Federal had no further obligations under the bonds.



After extensive discovery and resolution of certain preliminary issues by the court, in December 2001, Maine Yankee and
Federal entered into a settlement agreement pursuant to which Federal paid Maine Yankee $44 million on January 18, 2002.
The settlement was reflected on Maine Yankee's 2001 financial statements.

-11-

That amount represents full payment under the performance bond, plus an additional amount under the payment bond
reflecting certain payments made by Maine Yankee to subcontractors and suppliers who had not been fully paid by Stone &
Webster.  Maine Yankee deposited the payment in its decommissioning trust fund to offset past and future expenses
resulting from the failures of Stone & Webster.

Maine Yankee is continuing to pursue its claim for damages that was originally filed against Stone & Webster and its
parent corporations in August 2000 in the Bankruptcy Court in Delaware.  After recognizing the payment from Federal,
Maine Yankee has asserted a right to recover an additional $21 million in that court from the bankrupt estate.  The hearing
on the claim was held in late 2001, and Maine Yankee expects a decision from the court later in 2002.  On February 27,
2002, Stone & Webster filed a claim for approximately $6.9 million against Maine Yankee in the Bankruptcy Court in
Delaware for alleged breaches of contract and to subordinate Maine Yankee's claims.  Recovery by Maine Yankee of any
additional amount in the Bankruptcy Court is contingent on a number of factors beyond Maine Yankee's control, including
the extent to which the bankrupt estate has assets available to pay any amount determined to be recoverable and any
recognition of Stone & Webster's February 27, 2002 claim by the Court.  Maine Yankee therefore cannot predict the
outcome of the Bankruptcy Court proceeding.

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 reported it as a regulatory liability as of December 31, 2001 and 2000.  In
January 2002, the MPUC approved a stipulation on stranded costs which included an allocation of 15% of the refund to
shareholders and the remainder to offset the recognition of stranded costs.   On September 27, 2001, Maine Yankee's Board
of Directors voted to redeem 75,200 shares, 15% of the shares outstanding, of Maine Yankee's Common Stock in
accordance with a plan approved by the Securities and Exchange Commission on September 10, 2001.  The plan calls for
the redemption of Common Stock periodically through 2008.  On October 4, 2001, the Company received approximately
$500,000 for 15% of its Common Stock in Maine Yankee according to the first step of the plan.

6.      GENERATING ASSET DIVESTITURE

On July 7, 1998, the Company and WPS Power Development, Inc. (WPD-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 is required by the State's electric
industry restructuring law and required the approvals of the MPUC and the FERC.



On June 8, 1999, after receiving all of the major regulatory approvals, the Company completed the sale to WPD-PDI for
$37.4 million.  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 will be  used to reduce
the Company's debt.  The gain from the sale is currently deferred, and is being recognized  according to the Maine Public
Utilities Commission's (MPUC) decision on the Company's determination of stranded costs, transmission and distribution
costs and rate design.

-12-

The components of the deferred gain  are as follows:

|                                               | (Dollars in Millions)
|---------------------------------------------- | ---------------------
|Gross proceeds                                 | $38.6                
|Settlement adjustment                          | (.1)                 
|Net proceeds                                   | 38.5                 
|Net book value                                 | (11.5)               
|Excess taxes on sale of Canadian assets        | (3.4)                
|Transition costs, net                          | (1.9)                
|Other                                          | .7                   
|Available deferred gain                        | 22.4                 
|Utilization of available value per MPUC orders | (20.0)               
|Remaining deferred gain, net of tax*           | $2.4                 

* Gross proceeds were increased by $1.05 million before tax in September, 2001 due to a  MPUC approved
settlement between CMP and other former owners of Wyman Unit No.   4, including the Company.  The proceeds increased
the deferred gain and further reduced stranded costs.

As part of the generating assets 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 warranted 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.

7.           WPS COMPLAINT

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 against the Company as well as a Petition to Alter or
Amend the MPUC's September 2, 1998 Order in Docket No. 98-138, which authorized the formation of Energy Atlantic, LLC.

The Complaint alleged that the Company 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 engaged in conduct that either
awards EA a competitive advantage over other CEPs or 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 did not believe it in any way violated any provisions
of Chapter 304 and 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,
particularly

-13-

Maine Public Services Company's General Counsel, 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. In its response, the Company
strongly denied the allegations in the WPS Complaint and asked the Commission to dismiss the Complaint and for
Summary Judgement in its favor.

On May 1, 2001, the Commission issued its Order in this matter, finding that some counts in the WPS Complaint should
be dismissed but that others raised factual issues that could be resolved only through a more formal hearing process.  The
Commission declined, however, to take initial jurisdiction over the Complaint. Instead the Commission ordered the parties
to submit their dispute to the informal dispute resolution process set forth in MPS's Chapter 304 Implementation Plan.
Under this Plan, the dispute must be submitted to an independent law firm which must issue its decision within 30 days.
Only if the matter is not resolved to both parties' satisfaction would the Commission then take jurisdiction over the dispute.
The Commission also stated that it would open an investigation into the issue of whether MPS's General Counsel's dual role
with MPS and EA is inherently problematic and the standards that should govern any  MPS employees who also provide
services to EA.  A schedule for this investigation has not yet been announced.

The parties submitted the dispute to an independent arbitrator who issued his proposed findings on June 29, 2001.  The
arbitrator found that MPS did not violate any provisions of Chapter 304, except for the Company's unintentional failure to
identify WPS as a Standard Offer Service provider on its March and April 2000 bills to customers.  The arbitrator
recommended that MPS refund to WPS its billing fees for these two months, approximately $18,000.  On July 5, 2001,  the
Company and WPS informed the Commission of their acceptance of the arbitrator's findings.  As a result, the Commission,
in its  July 13, 2001 Order, stated  that it would not be necessary for it to further address the allegations in the WPS
complaint, even though it would continue its investigation into the sharing of employee services.

On March 6, 2002, the Company, WPS and the Public Advocate filed with the MPUC a Stipulation resolving all
remaining issues in the investigation.  The Stipulation contained several provisions that clarified the extent to which the
Company's senior management could become involved in the affairs of EA and included a prohibition on direct contact
between the Company's senior management and EA personnel for all but one designated executive.  The Stipulation also
prohibited this designated executive from being involved in certain types of Company activities, knowledge of which could
gain EA a competitive advantage in the retail market. Finally, the Stipulation gave the MPUC the right to conduct an annual
audit to determine whether EA and the Company are complying with Chapter 304.  The costs of this audit, up to $10,000,
shall be paid for by the Company.  This Stipulation was approved by the MPUC in an Order dated April 29, 2002.

8.           NEW ACCOUNTING PRONOUNCEMENTS

The Company has adopted Statement of Financial Accounting Standards No. 144  (SFAS144), "Accounting for the
Impairment or Disposal of Long Lived Assets", effective January 1, 2002.  This Statement addresses financial accounting
and reporting for the impairment or disposal of long-lived assets.  SFAS 144 establishes a single accounting model, based
on the framework established in Statement 121, for long-lived assets to be disposed of by sale and also resolves significant
implementation issues related to Statement 121.  The adoption of this statement had no material impact on its financial
position or results of operations.

In July 2001, the FASB issued SFAS No. 142, "Goodwill and Other Intangible Assets," which addresses financial
accounting and reporting for acquired goodwill and other intangible assets.  Under the provisions of SFAS No. 142, there is
no amortization of goodwill or intangible assets with indefinite lives.  Impairment of these assets will need to be assessed
annually.  The provisions of SFAS No. 142 are required to be applied starting with fiscal years beginning after December
15, 2001, and must be applied at the beginning





-14-

of a fiscal year and to all goodwill and other intangible assets recognized in the financial statements at that date. The
adoption of this statement on January 1, 2002 had no material impact on the Company's financial position or results of operations.

For all business combinations subsequent to June 30, 2001, the Company is required to apply the provisions of Statement
of Financial Accounting Standards No. 141, "Business Combinations."  SFAS 141 requires the use of the purchase method
of accounting for all business combinations.  Goodwill will initially be recognized as an asset and measured as the excess of
the costs of the acquired entity over the net amounts assigned to the assets acquired and liabilities assumed.  Intangible
assets other than goodwill will be recognized as an asset apart from goodwill if that asset arises from contractual or legal
rights.  The adoption of this pronouncement had no material impact on the Company's financial position or results of
operation.



In June of 2001, the Financial Accounting Standards Board (FASB) issued Statement of Financial Accounting Standards
No. 143 "Accounting for Asset Retirement Obligations."  This Statement addresses financial accounting and reporting for
obligations associated with the retirement of  tangible long-lived assets and associated asset retirement costs.  This
Statement is effective for financial statements issued for fiscal years beginning after June 15, 2002.  The Company does not
expect the adoption of this statement to have a material impact on its financial position or results of operations.



-15-

Form 10-Q

PART 1.  FINANCIAL INFORMATION



Item 2. Management's Analysis of Quarterly Income Statements

Forward-Looking Statements

The discussion below 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, such as expected future revenues from
Energy Atlantic.  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; developments in our
legislative, regulatory, and competitive environment; and the decommissioning cost of Maine Yankee.

Results of Operations

Net income and earnings per share for the three months ended March 31, 2002 along with the corresponding information
for the previous year are as follows:



|                   | 2002   | 2001  
|------------------ | ------ | ------
|Net Income         |        |       
|Core T&D           | $1,940 | $2,298
|EA                 | 165    | 741   
|Total Company      | $2,105 | $3,039
|Earnings Per Share |        |       
|Core T&D           | $1.24  | $1.46 
|EA                 | .10    | .47   
|Total Company      | $1.34  | $ 1.93

For the first quarter of 2002 compared to the same quarter last year, the decrease in consolidated earnings per share (EPS)
of $.59 is attributable to the following:

Change in EPS - First Quarter of 2002

Compared to First Quarter of 2001

|                                                                                                                   | EPS

Increase (Decrease)
|------------------------------------------------------------------------------------------------------------------ | ------------------------
|Decrease in Energy Atlantic net income                                                                             | $(.37)                  
|Increase in amortization of stranded costs and decrease in flexible pricing revenue due to
regulatory stipulations | (.17)                   
|Decrease in wheeling and retail revenues                                                                           | (.10)                   
|Reduction in net interest costs due to lower rates                                                                 | .08                     
|Other                                                                                                              | (.03)                   
|Total                                                                                                              | $(.59)                  



-16-

Form 10-Q

PART 1.  FINANCIAL INFORMATION

Item 2. Management's Analysis of Quarterly Income Statements



Results of Operations (Continued)

Consolidated operating revenues for the quarters ended March 31, 2002 and 2001, are as follows:

|                            | 2002   | 2001   
|--------------------------- | ------ | -------
|(Dollars in Thousands)      | $      | MWH    
|Maine Public Service (MPS)  |        |        
|- Retail                    | 8,938  | 138,564
|- Other Revenues            | 661    |        
|Energy Atlantic, LLC (EA)   |        |        
|- Competitive Energy Supply | 1,400  | 46,322 
|- Standard Offer Margin     | 407    | 627,503
|Totals                      | 11,406 | 812,389



MPS retail sales decreased by 1.9% (2,624 MWH), reflecting decreases in sales to medium commercial customers of 8.0%
(2,230 MWH).  The $139,000 decrease in Other Revenues represents a decrease in flexible pricing revenue according to the
regulatory stipulation in Docket 2001-240, as discussed below in Part II, Item 1, "Legal Proceedings".

Competitive Energy Supply revenues of the Company's wholly-owned marketing subsidiary, Energy Atlantic, LLC (EA)
decreased by $9,823,000 due to the expiration of several large retail customer contracts during 2001.  The Standard Offer
Service (SOS) margin decreased $576,000, due to expired SOS and associated run-out expenses.  See discussion below in
"Energy Atlantic Operations".

For the quarters ended March 31, 2002 and 2001, total operating expenses were $9,272,000 and $18,713,000, respectively.
Energy supply expenses for EA were as follows:

|                             | 2002   | 2001   
|---------------------------- | ------ | -------
|                             | $      | MWH    
|Energy Supply                |        |        
|EA Competitive Energy Supply | $1,201 | 46,322 
|EA Standard Offer Service    | -      | 627,503
|Total Energy Supply          | $1,201 | 673,825

With the start of retail competition on March 1, 2000, EA began selling to retail customers, and MPS itself now provides
transmission and distribution (T&D or delivery) services only, no longer purchasing or generating energy supply for its
customers.  Compared to the first quarter of 2001, CES purchases by EA decreased by 192,293 MWH, or $9,526,000, and
SOS purchases by EA decreased by 298,368 MWH due to the expired contracts discussed above.

-17-

Form 10-Q

PART 1.  FINANCIAL INFORMATION

Item 2. Management's Analysis of Quarterly Income Statements

Results of Operations (Continued)

T&D operation and maintenance expenses, as well as stranded costs, are as follows:

|                                               | 2002    | 2001    | Increase (Decrease)
|---------------------------------------------- | ------- | ------- | -------------------
|T&D Operation and Maintenance                  |         |         |                    
|Transmission and Distribution                  | $775    | $787    | $(12)              
|Customer Accounting and General Administrative | 2,000   | 1,840   | 160                
|Energy Atlantic                                | 314     | 233     | 81                 
|Total T&D Operation and Maintenance            | $3,089  | $2,860  | $229               
|                                               |         |         |                    
|Stranded Costs                                 |         |         |                    
|Wheelabrator-Sherman                           | $2,378  | $2,178  | $200               
|Maine Yankee                                   | 768     | 834     | (66)               
|Seabrook                                       | 278     | 278     | -                  
|Deferred Fuel                                  | 59      | 225     | (166)              
|Special Discounts                              | 23      | -       | 23                 
|Amortization of Gain from Asset Sale           | (1,045) | (1,341) | 296                
|Total Stranded Costs                           | $2,461  | $2,174  | $287               

Customer accounting and general administrative expenses increased by $160,000, reflecting increases in customer records
expense and in the provision for uncollectible accounts.  Energy Atlantic expenses increased by $81,000, due primarily to a
favorable adjustment to the provision for uncollectible accounts in 2001.

The Company recognized $2,461,000 of stranded costs in the first quarter of 2002, compared to $2,174,000 in the first
quarter of 2001.  MPS continues to purchase power from Wheelabrator-Sherman (W-S) under an agreement that expires in
2006, at prices above current market conditions.  Beginning on March 1, 2000, as a result of competitive bidding, the output
from W-S is sold to the successful bidder, and the above-market amount is included in stranded cost amortization rather
than energy supply.  The increase in amortization of stranded costs of $287,000 reflects a $296,000 decrease in the asset
sale gain recognition and an increase in net W-S costs of $200,000, offset by a $166,000 decrease in deferred fuel
recognition and a $66,000 decrease in Maine Yankee expenses.  Stranded costs include the W-S above-market costs
discussed above, less amortization of the deferred gain from the 1999 sale of the Company's generating assets, in
accordance with a Stipulation approved by the MPUC.





-18-

Form 10-Q

PART 1.  FINANCIAL INFORMATION

Item 2. Management's Analysis of Quarterly Income Statements

Results of Operations (Continued)

Energy Atlantic Operations

EA's  net income for the first quarter of 2002 was $165,000 compared to  $741,000 for the first quarter of last year.  The
decrease in net income reflects the expiration of several large competitive retail contracts in Central Maine Power's (CMP)
service territory, as well as the expiration of  the standard offer service to customers in CMP's service territory on February
28, 2002 as described below.

During 2001, Energy Atlantic's sales fell into two general categories:  Standard Offer Service (SOS) in CMP's service
territory and competitive energy supply to individual retail customers (CES).  Except as stated below, the power for those
sales was provided entirely under a Wholesale Power Sales Agreement (the "Agreement") with Engage Energy America,
LLC ("Engage").  The Agreement expired on February 28, 2002.

Under this Agreement, all revenues from both SOS and CES sales were paid directly to an Escrow Agent that disbursed
them in accordance with instructions from Engage.  For SOS sales, EA received reimbursement for certain expenses and a
portion of the net profit that was reported as SOS margin. During the first quarter of 2002, EA received $407,000 from SOS
margin compared to $983,000 for the first quarter of 2001.  This decrease is due primarily to the expiration of SOS on
February 28, 2002 and an increase in associated run-out expenses.

Although EA's rights to SOS sales in CMP's service territory expired on February 28, 2002, final distribution of the SOS
margin under the Agreement will not be made until various power authorities have finalized the power costs for those sales.
EA expects this process to be completed during the third quarter of 2002.

During the first quarter of 2001, EA also made several CES sales to individual commercial and industrial customers under
contracts that expired during 2001.

As part of the settlement with Engage, EA was permitted to obtain power from other wholesale suppliers beginning in
June, 2001.  As a result, EA has been able to secure one other source of supply in order to support new CES sales.  In
addition, EA has entered into a contract for  40% of the output of the Wheelabrator-Sherman energy facility for the two
years beginning March 1, 2002.

The output from this take-or-pay contract  amounts to approximately 55,000 MWH annually and will be used to provide
additional CES sales in the Company's service territory.  This is EA's first take-or-pay contract, which carries more
counterparty risk than others entered into to date.  To mitigate this risk, EA has entered into a contract with NB Power,
whereby  NB Power will buy W-S output in excess of load requirements in the Company's service territory at a rate indexed
to 3% Sulphur Max No. 6 residential oil into New York Harbor, which is intended to reflect NB Power's avoided cost,
subject to a floor and ceiling.  In addition, NB Power will sell power to EA when load exceeds W-S output at a fixed on and
off-peak rate.  In addition to the risks discussed above, EA, in conjunction with these contracts for supply and sales, is also
subject to the following risks:

-     Market liquidity - Ability to buy or sell energy on the open market

-     Forecasting - Accuracy of estimated supply requirements

-     Deliverability - Energy supply availability

-     Transmission - Reliance on third-parties for energy delivery from sources to customers

-     Volumetric - Changes in customer load requirements

-     Market-based cost - Market index pricing per NB Power contract discussed above

-     Credit risks - Customers ability to pay

EA's CES sales to retail customers during 2002 will produce far less revenue than EA earned from SOS in CMP's territory.
 EA continues to pursue additional supply to support new sales.

-19-

Form 10-Q

PART 1.  FINANCIAL INFORMATION

Item 2. Management's Analysis of Quarterly Income Statements

Results of Operations (Continued)

Liquidity

Net cash flows from operating activities were $3,657,000 for the first three months of 2002.  For the period, the Company
paid $551,000 in dividends and drew down $620,000 of proceeds from the tax-exempt revenue bonds, based on qualifying
property additions.  The Company also paid a scheduled sinking fund payment of $25,000 on long-term debt and decreased
short-term borrowings by $2,600,000.

For the period, the Company invested $1,166,000 in electric plant.



Net cash flows from operating activities were $4,631,000 for the first three months of 2001.  For the period, the Company
paid $503,000 in dividends and drew down $344,000 of proceeds from the tax-exempt revenue bonds, based on qualifying
property additions.  The Company also paid a scheduled sinking fund payment of $25,000 on long-term debt and decreased
short-term borrowings by $1,900,000. For the period, the Company invested $890,000 in electric plant.

Item 3. 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 March 31, 2002
for purposes other than trading.  These issues are discussed in detail in the Company's 2001 Annual Report, which is
Exhibit 13 of the Company's 2001 Form 10-K.  The discussion occurs in Note 10, "SFAS No. 133", of the Notes to
Consolidated Financial Statements. See Note 3, "Adoption of SFAS 133" of this Form 10-Q for required disclosure of
interest rate caps that qualify as derivative instruments.

(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 counterparty,
market liquidity, forecasting, deliverability, transmission, volumetric, market-based cost and credit risk as noted above.  EA
seeks to assure that risks are identified, evaluated and actively managed.

PART II.  OTHER INFORMATION

Item 1. 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, which authorizes the formation of
Energy Atlantic, LLC.

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.



-20-

Form 10-Q

PART II.  OTHER INFORMATION

Item 1. Legal Proceedings (continued)

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, particularly Maine Public Service Company's General Counsel, 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.

In its response, the Company strongly denied the allegations in the WPS Complaint and asked the Commission to dismiss
the Complaint and for Summary Judgment in its favor.



On May 1, 2001, the Commission issued its Order in this matter, finding that some counts in the WPS Complaint should
be dismissed but that others raised factual issues that could be resolved only through a more formal hearing process.  The
Commission declined, however, to take initial    jurisdiction over the Complaint.  Instead, the Commission ordered the
parties to submit their dispute to the informal dispute resolution process set forth in MPS's Chapter 304 Implementation
Plan.  Under this Plan, the dispute must be submitted to an independent law firm which must issue its decision within 30
days.  Only if the matter is not resolved to both parties' satisfaction would the Commission then take jurisdiction over the
dispute.  The Commission also stated that it would open an investigation into the issues of whether MPS's General
Counsel's dual role with MPS and EA is inherently problematic and the standards that should govern any MPS employees
who also provide services to EA.  A schedule for this investigation has not yet been announced.

The parties submitted the dispute to an independent arbitrator who issued his proposed findings on June 29, 2001.  The
arbitrator found that MPS did not violate any provisions of Chapter 304, except for the Company's unintentional failure to
identify WPS as a Standard Offer Service provider on its March and April 2000 bills to customers.  The arbitrator
recommended that MPS refund to WPS its billing fees for these two months, approximately $18,000.  On July 5, 2001, the
Company and WPS informed the Commission of their acceptance of the arbitrator's findings.  As a result, the Commission,
in its July 13, 2001 Order, stated that it would not be necessary for it to further address the allegations in the WPS
complaint, even though it would continue its investigation into the sharing of employee services.  This investigation
continues and the Company is unable to predict the timing or nature of the MPUC's ultimate decision.

On March 6, 2002, the Company, WPS and the Public Advocate filed with the MPUC a Stipulation resolving all
remaining issues in the investigation.  The Stipulation contained several provisions that clarified the extent to which the
Company's senior management could become involved in the affairs of EA and included a prohibition on direct contact
between the Company's senior management and EA personnel for all but one designated executive.  The Stipulation also
prohibited this designated executive from being involved in certain types of Company activities, knowledge of which could
gain EA a competitive advantage in the retail market.  Finally, the Stipulation gave the MPUC the right to conduct an
annual audit to determine whether EA and the Company are complying with Chapter 304.  The costs of this audit, up to
$10,000, shall be paid for by the Company.  This Stipulation was approved by the MPUC in an Order dated April 29, 2002.

-21-

Form 10-Q

PART II.  OTHER INFORMATION

Item 1. Legal Proceedings (continued)

(b) Maine Public Utilities Commission Investigation of Maine Public Service Company's Stranded Cost Revenue
Requirement in MPUC Docket No. 0l-240

On May 8, 2001, the MPUC issued a notice of investigation to determine whether the Company's annual recovery of
$12.5 million in stranded investment must be changed, effective March 1, 2002, to reflect any changes in its stranded costs.
On July 12, 2001, the Company filed its proposal in which it advocated continuing the $12.5 million annual recovery of
stranded costs and also proposed to begin the recovery of deferred amounts associated with the discounted rates it had made
available to certain industrial customers.  Also at issue in the proceeding was an insurance refund associated with Maine
Yankee, of which the Company's share is $1,005,000. As of December31, 2001, the Company reflected the refund as a
miscellaneous deferred credit.  A stipulation approved by the MPUC on January 7, 2002, with the appropriate order issued
on February 27, 2002, includes annual stranded cost recovery of $11,540,000 and a 15% sharing of the Maine Yankee
insurance refund with the Company's shareholders, thereby leaving the rates charged to core retail customers the same.

(c) Maine Public Utilities Commission, Investigation of Rate Design of Transmission and Distribution Utilities, MPUC
Docket No. 01-245.

On May 8, 2001, the MPUC issued a Notice of Investigation into certain common fundamental issues regarding the rates
for the State's three major electric utilities - the Company, Central Maine Power Company (CMP) and Bangor
Hydro-Electric Company (BHE).  These issues have been defined by the MPUC as follows:

(i)     The extent to which stranded cost recovery should be shifted from variable kwh and kw
                     charges to a fixed charge;

(ii)    The redefinition of time of use periods for rate design; and

(iii)   The elimination or reduction of seasonal rates.



The Company believes its stranded costs should be recovered through fixed charges that its customers cannot avoid by
reducing or eliminating their usage.  Such a fixed charge would reduce the risk of the Company's ability to recover its
stranded costs from customers.  The Company, together with CMP and BHE, filed testimony in support of its position on
April 16, 2002.  The Company has recommended that 50% of the stranded costs allocable to residential and small to
medium commercial and industrial customers and 25% of the stranded costs allocable to large industrial customers be
immediately collected through a fixed charge, with all remaining stranded costs to be phased in during the Company's next
rate case.  The Company also recommended immediate elimination of its seasonal rates.

The Company cannot predict the nature or the outcome of any decision in this proceeding.

Item 2.  Changes in Securities

None

Item 3.  Defaults upon Senior Securities

None

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



None

-22-

Form 10-Q

PART II.  OTHER INFORMATION

Item 5. Other Information

None

Item 6. Exhibits and Reports on Form 8-K

Exhibit 99.1 - Order of Maine Public Utilities Commission dated April 29, 2002 in Docket No. 2000-894 approving
revised stipulation of WPS Complaint Settlement.



SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed
on its behalf by the undersigned thereunto duly authorized.

MAINE PUBLIC SERVICE COMPANY

(Registrant)



Date: May 13, 2002  By: /s/ Kurt A. Tornquist

Kurt A. Tornquist

Controller, Assistant Secretary and Assistant Treasurer

-23-

Exhibit 99.1

|STATE OF MAINE                                 |                    
|---------------------------------------------- | -------------------
|PUBLIC UTILITIES COMMISSION                    | Docket No. 2000-894
|                                               | April 29, 2002     
|WPS ENERGY SERVICE, INC.                       | ORDER APPROVING    
|Complaint Requesting Commission Action to      | REVISED STIPULATION
|Amend or Alter Commission Order of             |                    
|September 2, 1998 in Docket No. 1998-138       |                    
|and Determine Whether Maine Public Service Co. |                    
|and/or Energy Atlantic Has Violated The        |                    
|Requirement  of the Order or the Provisions of |                    
|Chapters 301, 304, or 322                      |                    



WELCH, Chairman; NUGENT and DIAMOND, Commissioners

**I.          SUMMARY**

In this Order, we approve a Revised Stipulation (Stipulation) submitted to us by Maine Public Service Company (MPS),
WPS Energy Services, Inc. (WPS), the Office of Public Advocate (OPA) and the Industrial Energy Consumers Group
(IECG).  The Revised Stipulation resolves all issues in this matter and revises and refines the standards governing
employees shared by MPS, a regulated transmission and distribution (T&D) utility, and Energy Atlantic (EA), its
unregulated energy marketing affiliate.

**II.         BACKGROUND**



A.        Procedural History



See Appendix A.



B.        Factual and Legal Background



Section 3206 of Title 35-A allows affiliated interests of small investor-owned utilities to sell retail generation services to
retail customers within and outside their service territories.[1]  Section 3206 directs the Commission to promulgate rules to
govern the extent of separation necessary between a small investor-owned transmission and distribution utility and its
affiliated competitive electricity provider to avoid cross-subsidization and market power abuses.  Pursuant to this legislative
directive, the Commission has adopted Chapter 304 governing the standards of conduct between T&D utilities (including
small investor-owned utilities) and their affiliated competitive providers.



[1] Small investor-owned utilities are defined as those investor-owned transmission and distribution utilities serving
50,000 or fewer retail customers.  In its most recent annual report filed with the Commission, MPS reported that it was
serving approximately 35,000 customers and thus qualifies

as a small investor-owned utility.

**Order Approving...                                             -2-                                                  Docket No. 2000-894**

Chapter 304, s.3(A) provides that a distribution utility may not, through a tariff provision or otherwise, give its affiliated
competitive provider preference over non-affiliated competitive electricity providers.  In addition, Chapter 304, s. 3(F) and
3(G) provide that a distribution utility shall process all similar requests for information in the same manner and within the
same time period and prohibits the utility from sharing with any competitive electricity provider any market information
developed by the utility in the course of responding to requests for distribution service.  For an affiliated provider to offer
competitive services, the distribution utility must have filed with the Commission an implementation plan which among
other things contains a dispute resolution mechanism.  Under Chapter 304, s. 3(K), employees may not be shared between a
distribution utility and its affiliated competitive provider, unless the Commission explicitly allows an exemption upon
specified findings.



In Maine Public Service Company, Request for Approval of Reorganization Approvals and Exemptions and for Affiliated
Interest Transaction Approvals, Docket No. 98-138, Order (Sept. 2, 1998), we approved a management service agreement
between MPS and Energy Atlantic (EA), an affiliated interest of MPS engaged in competitive electricity provider activities,
which allowed MPS to perform overall management oversight through the sharing of the MPS president and one member of
MPS's senior management.  In approving the contract, the

Commission noted:



Our approval is premised on the nature of the management

oversight being similar to that of a board of directors, rather

than that of executive management.  As part of our conditions

for approval, MPS is required to notify the Commission in

writing as to the information provided to EA and the means by

which the information was disclosed to non-affiliated providers.



Order, Docket No. 98-138 at 11.



In its complaint of October 31, 2000, WPS alleged that Stephen Johnson, by acting as General Counsel for MPS and the
Vice-President of MPS's unregulated activities, including EA, is in a position to have access to competitive confidential
information to the disadvantage of EA's competitors; that in two contract unbundling cases, Mr. Johnson received
confidential WPS price

**Order Approving...                                             -3-                                                  Docket No. 2000-894**

information in his capacity as general counsel for MPS, and that Mr. Johnson's dual role could be used to undermine the
Chapter 307 auction process.[2]



In addition to the problems associated with Mr. Johnson's dual role, WPS alleged that shortly after it acquired a retail
aggregate customer group and enrolled it with MPS, EA contacted the customer group and asked if there was anything it
could do to keep the customers from signing with WPS; that MPS violated Chapter 301 of the Commission's Rules by
failing to provide WPS's name as the standard offer provider on its bills; that MPS has refused to include WPS's logo as
part of its standard offer identification on MPS's consolidated bills in violation of section 3(D) of Chapter 322; and that
MPS has routinely provided large customer usage data to EA but refused initially to provide such information to WPS.



WPS concluded that the sharing of MPS employees with EA and the dual role of Mr. Johnson are not in the public interest
and create an unreasonable risk of causing an "anti-competitive" effect within the meaning of Chapter 304(K).



On November 17, 2000, MPS filed its response to WPS's complaint along with motions to dismiss and for
summary judgment.  On May 1, 2001, the Commission issued its Order Denying in Part and Granting in Part Motions to
Dismiss and for Summary Judgment.  In that Order, the Commission referred back to the parties, for processing under
MPS's dispute resolution procedure, the following claims of violations made by WPS in its complaint:



1.       disclosure of confidential WPS generation price information provided in contract unbundling proceedings;



2.       disclosure of customer enrollment information to EA;



3.       disparate treatment concerning provision of large customer usage

data; and

4.       failure to include its name as the standard offer provider on

consolidated utility bills.



On June 29, 2001, William Devoe, the investigator selected to handle this dispute pursuant to MPS's Chapter 304
Implementation Plan, issued his proposed findings and decision on these issues.  Under Section II(M)(iii) of

[2] Chapter 307 of our Rules sets out the procedure which utilities are to follow to sell capacity and energy from their
generation assets which have not been divested pursuant to 35-A M.R.S.A. s. 3204(1).

**Order Approving...                                             -4-                                                  Docket No. 2000-894**

MPS's Implementation Plan, MPS and the complainant may mutually agree to accept the investigator's findings as the full
and final resolution of the dispute, but are not obligated to do so.  At a July 5, 2001 case conference, counsel for MPS and
counsel for WPS indicated that they had agreed to accept the findings and recommendations of the investigator as the full
and final resolution of the matters referred back for informal dispute resolution.  In light of the Commission's May 1, 2001
Order and the parties' acceptance of the investigator's report, the sole remaining issues in this case then were:



1)      whether Mr. Johnson's involvement at Energy Atlantic exceeded the "manage like a board of directors" standard set
forth in Docket No. 98-138;



2)      whether experience suggests that Mr. Johnson's dual role is inherently problematic;



3)      whether the conditions that supported employee sharing have materially changed since the issuance of the
Commission's Order in Docket No. 98-138; and



4)      if MPS and EA are to continue to share employees, whether a clarification of the "manage like a board of directors"
standard is warranted.



On March 8, 2002, we received a Revised Stipulation signed by all parties to the case and also supported by our Advisory
Staff, which resolves all of the above-referenced outstanding issues.



**III.        DESCRIPTION OF THE STIPULATION**



The Stipulation proposes to amend the Order in Docket No. 98-138 to allow for the sharing of one MPS employee (MPS
Designated Executive).  This individual would be someone other than the MPS General Counsel and could provide
oversight and management guidance, including strategic planning to EA.  The Designated MPS Executive is authorized to
discuss the management of EA with MPS senior management on a limited basis within the expertise and/or responsibility of
such MPS senior managers.  The Designated MPS Executive, however, may not be involved in certain activities (Restricted
Activities) at MPS.



The Restricted Activities include participation in the standard offer process, participation in the Chapter 307 sale of MPS
generation entitlements, negotiating or drafting any special rate contract with MPS customers or actively participating in the
approval of such special rate contracts, and participating in any communications between MPS and a competitive electric
provider (CEP) or an MPS customer regarding the terms of a CEP's service to any retail customer in the MPS service area.
No outside attorney retained by MPS to represent the

**Order Approving...                                             -5-                                                  Docket No. 2000-894**

Company in any of the Restricted Activities may also represent EA in any of the Restricted Activities.  MPS's General
Counsel may provide legal services to EA but may not provide representation to EA in any of the Restricted Activities nor
can such individual provide representation in the negotiation, execution or enforcement of specific supply contracts between
EA and its retail customers.



Under the terms of the Stipulation, the Designated MPS Executive is to maintain a detailed log of all contacts with EA
employees.  The Commission shall have the right, not more frequently than once a year, to conduct a compliance audit to
determine whether MPS or EA has engaged in any violations of Chapter 304 of the Commission's Rules or MPS's
Implementation Plan.  The Stipulation further provides that no further Commission action shall be taken against MPS or EA
as a result of any allegation raised in this proceeding or a result of any fact brought out during the discovery process in this
case.



**IV.       DECISION**



As we have stated on numerous occasions, to approve a stipulation the Commission must find that:



1.     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;



2.     the process that led to the stipulation was fair to all parties; and



3.     the stipulated result is reasonable and 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. 95-052, 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.



In this case, the Stipulation was entered into by all parties to this matter (MPS, WPS, the OPA and the IECG).  The
stipulating parties represent a sufficiently broad spectrum of interests to ensure that there is no appearance or reality of
disenfranchisement.



**Order Approving...                                             -6-                                                  Docket No. 2000-894**

There has not been any indication given by any party to this matter that the process that ultimately lead up to the
Stipulation was anything but fair.  We thus find that our second criterion has also been satisfied.



In deciding whether a stipulation is fair and consistent with the public interest, the entire stipulation must be
considered as a package.  Whether we disagree with a particular stipulation provision or would have come up with a
different resolution were we deciding the case after litigation is not the question.  Central Maine Power Company, Request
for Approval of Alternative Rate Plan (Post-merger) "ARP 2000," Docket No. 99-666, Order Approving Stipulation at 13
(Nov. 16, 2000).  The question is whether the particular proposal before us is reasonable and consistent with the public
interest.  See Docket No. 92-345 (Phase II), supra., Order at 3.  In deciding this question, any detriments which have been
raised must be weighed against the benefits of the stipulation.



On an overall basis, we believe the Stipulation fairly and reasonably resolves all outstanding issues in this case and
appropriately balances the competing interests of the parties.  The Stipulation helps ensure that EA will not unfairly benefit
from its relationship with its regulated T&D affiliate, MPS, while at the same time the provisions do not unfairly restrict
EA's ability to conduct its business.  Thus, we find that the Stipulation furthers our goal of maintaining a level playing field
for the participants in the northern Maine retail generation market.



The one provision of the Stipulation which causes us with some concern is paragraph 12 which provides:



The Commission shall have the right, not more frequently

than once a year, to conduct a full compliance audit to

determine whether either EA or MPS have engaged in any

violations of Chapter 304 or MPS's Implementation Plan.

This audit may be conducted at a time and by a law firm or

other third party investigator of the Commission's choosing

and shall be paid for by MPS, up to a total amount of $10,000

annually, which amount may not be recovered from MPS's

ratepayers....The audit agreed to in this paragraph is not

intended to limit the Commission's authority to otherwise

investigate or audit MPS pursuant to the Commission's

express statutory authority.  (emphasis added)



On its face this language appears to limit our ability to audit MPS's relationship with EA.  However, given the extremely
broad powers given to us by 35-A M.R.S.A. s.112, 113, 707 and 1303, we do not believe, as a practical matter, that the
language in the Stipulation in any way restricts our ability to further investigate or audit the relationship between MPS and
EA should we find that such a

**Order Approving...                                             -7-                                                  Docket No. 2000-894**

further investigation or audit is warranted.  With this understanding, we find the Stipulation to be in the public interest and
consistent with statutory requirements.



Accordingly, it is



O R D E R E D



1.         That the Revised Stipulation entered into between the parties in this case and filed with the Commission on
March 8, 2002 is approved.  A copy of the Revised Stipulation is attached hereto and incorporated by reference.

2.         That our Order of September 2, 1998 in Docket No. 98-138 is hereby modified in accordance with the terms
of the Revised Stipulation approved herein.

Dated at Augusta, Maine, this 29th day of April, 2002.



BY ORDER OF THE COMMISSION



/s/ Dennis L. Keschl

Dennis L. Keschl

Administrative Director







COMMISSIONERS VOTING FOR: Welch

Nugent

Diamond

**Order Approving...                                             -8-                                                  Docket No. 2000-894**

**APPENDIX A**



On October 31, 2000, WPS Energy Services, Inc. filed a complaint with the Commission against Maine Public Service
Company pursuant to 35-A M.R.S.A. s. 1306, 3206 and 3206-A.  In addition, as a part of this pleading, WPS petitioned the
Commission, pursuant to the provisions of 35-A M.R.S.A. s. 1321, to alter or amend the Commission's decision in Docket
No. 98-138.



On November 17, 2000, MPS filed its response to the complaint along with motions to dismiss and for summary
judgment.  In support of its motion for summary judgment, MPS filed affidavits from Stephen Johnson and Brent M.
Boyles.  On December 18, 2000, WPS filed its Opposition to Maine Public Service Company's Motion to Dismiss and for
Summary Judgment, a Statement of Material Facts and Supporting Affidavits of Edward Howard, Tim Charette and
Dwayne Conley.  On January 5, 2001, MPS filed its Reply to the WPS Opposition along with its Statement of Material
Facts As To Which There Is No Issue.



On May 1, 2001, the Commission issued its Order Denying in Part and Granting in Part Motions to Dismiss and For
Summary Judgment in Docket No. 2000-894.  In that Order, the Commission initiated this investigation and reopened its
decision in Docket No. 98-138.[3]



A Procedural Order which provided interested persons with an opportunity to intervene in this matter was issued on
May 23, 2001.  Under the Procedural Order, WPS Energy Service, Inc. and Maine Public Service Company were
considered parties at the outset.  In addition, the Office of the Public Advocate, an intervenor in Docket No. 98-138, was
also considered a party at the

outset.



Timely petitions to intervene were filed by Central Maine Power Company and the Industrial Energy Consumers
Group.  In its petition, CMP claimed that as a transmission and distribution utility it was subject to the requirements of
Chapters 301, 304 and 322 of the Commission's Rules and therefore it "is or may be substantially and directly affected by
this proceeding."  Counsel for MPS questioned whether CMP needed to participate in the factual aspects of the case.  Based
on the arguments at the conference, and with the consent of the parties, CMP was granted discretionary intervention status
with participation limited to briefing and commenting on policy matters.



In its petition, the IECG claimed that "it has been and continues to be substantially and significantly involved in the
development in competitive markets for electricity, not just in southern Maine, but on a statewide, regional and national
levels."  MPS argued that since the IECG had no members which were customers of MPS they were not directly affected by
the outcome in this

[3]By way of a Procedural Order dated June 27, 2001, Docket No. 98-138 was consolidated in this docket and closed.

**Order Approving...                                             -9-                                                  Docket No. 2000-894**

proceeding and, therefore, should not be given full party status.  MPS indicated that it would agree to limited intervention
similar to that granted to Central Maine Power Company whereby the IECG would receive all filings and could brief and
comment on legal and policy questions.  The Examiner concluded that, although the IECG would not directly and
substantially be affected by the outcome of this proceeding, and therefore was not entitled to intervene as a matter of right
under section 720 of the Commission's Rules of Practice and Procedure, the IECG's interest was sufficient to warrant full
party status as a discretionary intervenor pursuant to MPUC Rules, ch. 110, s. 721.



On July 13, 2001, the Examiner issued a Procedural Order which found that there was a reasonable likelihood, given
the narrowing of the issues in this case, that the remaining issues could be presented on a stipulated set of facts.  A deadline
of August 3, 2001 was established for either the parties to submit a stipulated set of facts or for MPS to submit its pre-filed
testimony.  At the request of the parties, this deadline was extended until September 7, 2001.  On September 7, 2001, MPS
submitted the pre-filed testimony of Stephen Johnson.  A technical conference on Mr. Johnson's testimony was held on
October 17, 2001.



A case conference was held on November 6, 2001 to discuss the next steps to bring this proceeding to a conclusion.
At that time, all parties agreed that hearings were not necessary and the case could be presented to the Commission based
on the discovery conducted to date (including the October 17, 2001 technical conference) and on briefs.  The parties also
agreed that it appeared possible that the remaining issues could be resolved through a negotiated agreement.



Following the case conference, a number of settlement conferences involving the parties and the Advisory Staff
were held.  On February 27, 2002, the Commission received a Stipulation entered into between MPS, WPS, the OPA and
the IECG.  On March 8, 2002, we received a Revised Stipulation which withdrew and replaced the earlier Stipulation.