ML20133B159

Annual Rept for Montaup Electric Co for Yr Ending 951231

ML20133B159
Person / Time
Site:	Seabrook
Issue date:	12/31/1995
From:	MONTAUP ELECTRIC CO.
To:
Shared Package
ML20133B135	List: ML20133B132 ML20133B145 ML20133B151 ML20133B159 ML20133B163 ML20133B171 ML20133B180
References
NUDOCS 9701030015
Download: ML20133B159 (139)

Text

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Form Approved THIS FILING 15 (CHECK ONE BOX FOR EACH ITEM)

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, ANNUAL REPORT OF MAJOR ELECTRIC i

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{ Exact isgal Name of Respondent (Company)! J'. Year of Report

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j n l 1I ie 5I THIS FILING 15 (CHECK ONE BOX FOR EACH ITEM) Form Approved OMB No.1902-0021 item 1: O An infilal(Original) OR O ResubmissionNo. (Expkes 7/31198)

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FERC Form No.1:

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ANNUAL REPORT OF MAJOR ELECTRIC i UTILITIES, LICENSEES AND OTHERS

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j, This report is mandaewy under the Federal Pomer Act. Sections 3. 4(s),304 and 309, j and 18 CFR141.1. Fadare to report may result m crynnd 6nes, cui peneMws and omer sanciens as prossed by Wm The Federal Enwgy Reemassy Comrmanen does j' not consaner thm soport W be of a con 6dertal naeure.

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i Exacs Lapal Name of Respondern (Company) Year of Report j MONTAUP ELECTRIC Dec. 31.19.9 5 i

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FERC FORM NO.1 (REV.12-95)

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?d g Coopers & Lybrand LLP.

&Lyaranc a -e. a, e_es ,_ ,

v, REPORT OF INDEPENDENT ACCOUNTANTS

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m Montaup Electric Company Somerset, Massachusetts

. We have audited the balance sheets of Montaup Electric Company as of December 31,1995 and 1994, and the related statements ofincome, retained eamings, and cash flows for the years then ended, included on pages 110 through 123 of the accompanying Federal Energy Regulatory Commission Form No.1. These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with generally accepted auditing standards. Those standards l require that we plan and perform the audit to obtain reasonable assurance about whether the financial l

statements are free of matedal misstatement. An audit includes examining, on a test basis, evidence i supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation.' We believe that our audits provide a reasonable basis for our opinion.

In out opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Montaup Electric Company as of December 31,1995 and 1994 and the results ofits operations and its cash flows for the years then ended in conformity with generally accepted accounting principles and in accordance with the accounting requirements of the Federal Energy Regulatory

. Commission as set forth in its applicable Uniform System of Accounts and Published accounting releases.

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Boston, Massachusetts March 5,1996 I

d Coopers & Lyorand LL P.. a registerec nmne: naomy partnersne is a enernoer brm of Coopers & Lyoranc Uniernanonals d

I"O l PJ INS 7 RUCTIONS FOR FILING THE

= FERC FORM NO. 1 f GENERAL INFORMATION

1. Purpose

& This form is a regulatory support requirement (18 CFR 141.1). It is designed to collect financial and operational information from major electric utilities, ticensees and others stbject to the jurisdiction of the Federal Energy Regulatory Comission. This report is also secondarily considered to be a nonconfidentist pelic use form supporting a statistical pubitcation (Financtet Statistics of Selected Electric Utilitles), published by the Energy Information Administration.

! 11. Who Must Sthmit

! Each Major electric utility, licensee, or other, as classified in the Connission's Uniform System of Accotatts 7

Prescribed for Public Utilities and Licensees Subject To the Provisions of The Federal Power Act (18 CFR 101),

aust submit this form.

Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the followings (1) One mittion megawatt hours of total annual sales, (2) 100 megawatt hours of annual sales for resale, (3) 500 megawatt hours of annual power exchanges dettvered, or (4) 500 megawatt hours of annual wheeling for others (deliveries plus losses),

f III. What and Where to submit (a) Submit this form on electronic media consisting of two (2) duplicate data diskettes and an original and i

six (6) conformed paper copies, property filed in and attested, tor l Office of the Secretary I Federal Energy Regulatory Comnission 888 First Street, NE.

l Room 1A208 Washington, DC 20426 l

- Retain one copy of this report for your files, include with the original and each conformed paper copy of this form the stbscription statement required by 18 C.F.R. 385.2011(c)(5). Paragraph (c)(5) of 18 C.F.R. 385.2011 requires each respondent submitting data l i l- electronicotty to file a subscription stating that the paper copies contain the same information as contained '

on the electronic media, that the signer knows the contents of the paper copies and electronic media, and that the contents as stated in the copies and on the electronic media are true to the best knowledge and j l

belief of the signer.

l (b) Submit inmediately upon publicat on, four (4) copies of the latest annual report to stockholders and any annual financist or statistical report reputarty propered and distributed to bondholders, security analysts, l l

or industry associations. (Do not include monthly and quarterly reports. Indicate by checking the l

appropriate box on Page 4, List of Schedules, if the reports to stockholders will be submitted or if no annual report to stockholders is prepared.) Mall these reports to:

Chief Accountant Federal Energy Regulatory Comission 888 First Street, NE.

Room 72-04 Washington, DC 20426 l (c) For the CPA certification, submit with the original submission, or within 30 days after the filing date

' for this form, a letter or report (not applicable to respondents classified as Class c or Class D prior to January 1, 1984):

(1) Attesting to the conformity, in all materlat aspects, of the below listed (schedules and) l pages with the connission's applicable Uniform Systems of Accounts (including applicable notes l relating thereto and the Chief Accountant's published accotssting releases), and (II) Signed by independent certifled pubtle accountants or an Independent licensed p4 tic accountant, certified or licensed by a regulatory authority of a State or other political subdivision of the U. S.

' (See 18 CFR 41.10-41.12 for speelfic quellfications.)

Page 1 FERC FORM NO. 1 (REV. 12-95) i

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o CENERAL INFORMATION (Continued) _

Ill. What and Where to Sutalt (Continued)

(c) Continued '

Reference Schedules Pcges s

Comparative Balance Sheet 110 - 113 Statement of Income 114 - 117 .

Statement of Retained Earnings 118 119 Statement of Cash Flows 120 - 121 Notes to Financial statements 122 - 123 When acconpanying this form, insert the letter or report imediately following the cover sheet. When submitting af ter the filing date for this form, send the letter or report to the office of the secretary at the address Indicated at III (a).

Use the following form for the letter or report unless unusual circianstances or conditions, explained in the letter or report, demorni that it be varied. Insert parenthetical phrases only when exceptions are reported.

In connection with our regular examination of the financial statements of for the year ended on which we have reported separately under date of we have also reviewed schedat es of FERC Form No.1 for the year flied with the Federal Energy Regulatory Comission, for conformity in att materlat respects with the requirements of the Federal Energy Regulatory Comission as set forth in its applicable Uniform system of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.

Based on our review, in our opinion the acconpanying schedules identified in the preceding paragraph (except as noted below) conform in all materlat respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases, state in the letter or report, which, If any, of the pages above do not conform to the commission's requirements. Describe the discrepancies that exist.

(d) Federal, State and Local Governments and other authorized users may obtain additional blank copies to meet their requirements free of charge from:

Public Reference and Files Maintenance Branch Federal Energy Regulatory Comission 888 First Street, NE.

Room 21-A ED 12.2 Washington, DC 20426 (202) 208-2474 IV. When to submit Submit this report form on or before April 30th of the year following the year covered by this report.

V. Where to send Comments on Public Reporting Burden.

The public reporting burden for this collection of information is estimated to average 1,217 hours0.00251 days <br />0.0603 hours <br />3.587963e-4 weeks <br />8.25685e-5 months <br /> per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data needed, and completing and reviewing the collection of information. Send coments regarding this burden estimate or any aspect of this collection of information, including suggestions for reducing this burden, to the Federal Energy Regulatory Conmission, 888 First Street NE., Washington, DC 20426 (Attention: Mr. Michael Miller, ED 12.3); and to the Of flee of Information and Regulatory Aff airs, Office of Management and Budget, Washington, DC 205C3 (Attention: Desk Officer for the Federal Energy Regulatory Commission). i

-l FERC FORM NO.1 (REV. 12 95) Page 11 l

'Y Oj GENERAL INSTRUCTIONS m ,

C.  !. Prepare this report in conformity with the Uniform System of Accounts (18 CFR 101) (U.S. of A.). Interpret all accomting words and phrases in accordance with the U. S. of A.

_ II. Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for everages and

, ,j figures per unit where cents are important. The truncating of cents is alicued except on the four basic en financist statements where rounding is required.) The amomts shown on att' supporting pages must agree with  !

i the amounts entered on the statements that they support. When applying thresholds to determine significance I for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting year,

.. and use for statement of income accounts the current year's arrounts.

III. complete each question fully and accurately, even if it has been answered in a previous annual report. Enter the word "None" 6here it truly and cogletely states the fact.

IV. For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2, 3, and 4.

m V. Enter the month, day, and year for att dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below). The date of the reaubnission must be reported in the header for at1 form pages, whether or not they ata changed from the previous filing.

VI. Generetty, except for certain schedules, att rsabers, whether they are expected to be debits or credits, aust be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the rambers in parentheses. ( ).

VII. For any resubmissions, two (2) new data diskettes and an original and six (6) conformed paper copies of the entire form, as well as the appropriate number of copies of the subscription statement indicated at

+ Instruction III (a) must be filed. Resubmissions must be numbered sequentistly both on the diskettes and on l . the cover page of the paper copies of the form. In addition, the cover page of each paper copy must Indicate l that the filing is a resubmission. Send the resubmissions to the address indicated at instruction III (a). I l l n

VIII. Do not make references to reports of previous years or to other reports in lieu of required entries, except as speelfically authorized.

IX. Wherever (schedule) pages refer to fleures from a previous year, the figures reported must be based upon those shown by the annual report of the previous year, or an appropriate explanation given as to why the different 2 figures were used.

1 DEFINITIONS l

l. commission Authorization (Conn. Auth.) -* The authorization of the Federal Energy Regulatory Consission, or any other ccanission. Name the connission whose autv erization was obtained and give date of the authorization.

II. Respondent -- The person, corporation, licensee, agency, authority, or other legal entity or instrumentality in whose behalf the report is made, i

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FERC FORM No.1 (REY. 12-95;s Page ill

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~.7 FERC FORM NO. is t ANW.lAL REPORT OF MAJOR ELECTRIC 17f1LITIES LICENSEES AND OTHER IDENTIFICATI0W 02 Year of Report.

01 Exsct legal Name of Respondent De c . 31. 19 9 5 Monttup Electric Company >

(if name changed during year) 03 Previous Nese and Date of Change City, State, tip Code) 5 04 Address of Principal office at End of Year (Street, .

P. C. Box 543, West Sridgewater, Ma 02379 150 weit Center Street, 06 Title of Contact Person I 05 Name of Contact Person Vice President l Riahard M. Burne 07 Address of contact Person (Street, City, State, tip Code) 1 Liberty Square, Boston, Ma 02107 to Date of Report 09 This Report is to Tsltphone of Contact Person, (No. De, YT)

(1) x An Original (2) A Resukeiosion including Area C W 03/31/96 is17) 357-9590 ATTESTATION that to the best of hie / her knowledge The undersigned officer certifies that he/she has examined the accompanying report, nd the accompanying report is information and belief, all statements of f act contained in the accompanying report are true a d every matter set forth 6 eorrect statement of the business and affairs of the above named respondent in respect to each an and including January 1 to and including December 31 of the year of the report.

thtrein during the period from 04 Date Signed 03 Signature 91 Name (Mo, Da, Tr)

Rithard M. Burme

1. 2 Title 03/31/96 Tiss President United title 18, U.S.C.1001, makes it a crime for any persion knowingly and willingly to make to any Agency or Department of the States any f alse, fictitious or fraudulent statemente as to any matter within its jurisdiction.

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, FERC FORn No. 1 (ED. 12 91)

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Year sf Report.

cf hospondent ate Electric Company T a r

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Dec. 31, 1995 -

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• LIST OF SCHEDULES (Electric Utility)

• Enter in cotum (d) the terms "none," "not applicable," have been reported for certain pages. Omit pages where the Er "NA," as appropriate, where no information or amounts respondents are "none," "not applicable," or "NA". >

Title of Schedule Reference Date Remarks

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l Page No. Revised (G (b) (c) (d) l GENERAL CORPORr.E INFORMATION AND t i

l: FINANCitL STATEMENTS

\. s Ed. 12 87 General Information ........................................... 101

. Control Over Respondent ...................................... 102 Ed.12 87 CIrporations Controlled by Respondent ........................ 103 Ed. 12 95 ,

I Officers ..................................................... 104 Ed.12 87 ,

Directors ..................................................... 105 Ed. 12 95 l

[ d Security Holders and Voting Powers ........................... 106 - 107 Ed. 12-b7

!sportant Changes During the Year ............................ 108 - 109 Ed. 12 90 l- Ed. 12 94 couperative Balance Sneet. .................................... 110 - 113  :

lt Statement of Income for the Year .............................. 114 - 117 Rev. 12 95 Statement of Retalnad Earnings for the Year ................... 118 119 Ed.12 M St tement of Cash Flows ...................................... 120 - 121 Rev. 12 94 N tes to Financlet Statements ................................. 122 123 Ed. 12-88 l.

BALANCE SNEET SUPPORTING SCHEDULES (Assets and Other Debits) l i

Suunnry of Utility Plant and Accumulated Provisions for i Depreciation, Amortization, and Depletion ................... 200 - 201 Ed. 12-89 Nuclear Fuel Materiets ....................................... 202 - 203 Ed.12-89  ;

, Electric Plant in Service .................................... 204 - 207 Rev.12-95 213 Rev. 12 95 none Electric Plant Leased to others ...............................

Etoctric Plant Held for Future Use- ............................ 214- Ed. 12-89 ,

Construction Work in Progress - Electric ..................... 216 Ed. 12-87 Construction overheads -- Electric ........................... 217 Ed. 12 89  ;

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General Description of Construction Overhead Procedure ........ 218 Ed. 12 88 Acetmutated Provision for Depreclatlon of Electric Utility Plant. 219 Ed. 12 88 Nonutility Property .......................................... 221 Rev. 12 95 i ,

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- Investment in Subsidiary compentes ........................... 224 225 Ed. 12 89 Materiets and Supplies ....................................... 227 Ed. 12-89 '

228 - 229 Ed. 12 95 none 4 Attowances '...................................................

, Extraordinary Property Losses ................................ 230 Ed. 12-93 Unrecovered Plant and Regulatory Study Costs .................. 230 Ed. 12-93 Other Regulatory Assets ....................................... 232 Ed. 12-95 Miscettaneous Deferred Debits ................................. 233 Ed. 12 94 AccumJtated Deferred Income Taxes (Accrunt 190) ............... 234 Ed. 12-88 BALANCE SNEET SUPPORTING SCHEDULES (Llabilities and Other Credits)

Capital Stock ... .............................................. 250 251 Ed. 12-91 Capital Stock Sthscribed, Capital Stock Liability for Conversion, Premites on Capital Stock, and Instattments l Rev. 12-95 none

! Received on Capitet Stock ................................... 252 other Pald in Capital ........................................ 253 Ed. 12-87 254 Ed. 12-87 none Olscount on Capital Stock ....................................

254 Ed. 12-36 none Capitet Stock Expense ........................................

Long Term Debt .................................... .......... 256 - 257 Ed. 12-91 l ~. t Page 2 FERC FORM NO. 1 (REV. 12 95) l c , .--y , - , - - . - - -a7 -_

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Name of Resi- Gat " i s R port is: _.Date of Report Montaup Electric Company Year of Report -

[.a? {x AnOrgatssion A Res ( g /a Y r) Dec. 31, 1995 LIST OF SCHEDULES (Electric Utility) (Continued)

Title of Schedule Reference Date '

Page No. Remarks Revised (a) (b) (c) (d)

BALANCE SHEET SUPPORTING SCHEDULES (Llabilities and other Credits) (Continued)

Reconelliation of Reported Net Income with Taxable income i

fir Federal Income Taxes ................................... 261 Ed. 12-88 Taxis Accrued, Prepaid and Charged During Tear ............... 262 263 Rev. 12-95

• Accumulated Deferred Investment Tax Credits ................... 266 267 Ed. 12-89 Oth r Deferred Credits ....................................... 269 Ed.12 88 Accumulated Deferred Income Taxes -- Accelerated Amortization Property ................................................... ,j 272 - 273 Ed. 12-94 none Accoulated Deferred Income Taxes - other Property ........... 274 - 275 Ed. 12 94 Acetswitated Deferred Income Taxes - other ................... 276 - 277 Ed. 12-94 oth:r Regulatory Liabilities ................................. 278 Ed. 12-94 INCOME ACCOUNT SUPPOR11NG SCHEDULES Electric operating Revenues .................................. 300 - 301 Ed. 12-90 Sales of Electricity by Rate Schedules ....................... 304 Ed. 12-95 none Sites of Resale .............................................. 310 - 311 Ed. 12-88 Electric Operation and Maintenance Expenses .................. 320 - 323 Ed. 12 95 N aber of Electric Department Employees .......................  ;

323 Ed. 12-93 Purchased Power i

.............................................. 326 - 327 Ed. 12-95 Transmission of Electricity for Others ........................ 328 - 330 Ed. 12 90 Tr:nsmission of Electricity by others ........................ 332 Ed. 12-90 Ciscellaneous General Expenses -- Electric ...................  !

335 Ed.12 94 Depreciation and Amortization of Electric Plant ............... 336 - 337 Ed. 12-95 Particulars Concerning Certain income Deduction and Interest Charges Accounts j

........................................... 340 Ed. 12-87 COMMON SECTION R gulatory Commission Expenses 350 351

............................... Ed. 12-90 Research, Development and Demonstration Activities ........... 352 353 Ed. 12-87 none Distribution of Salaries and Wages ........................... 354 - 355 Ed. 12 88 Common Utility Plant and Expenses ............................ 356 Ed. 12 87 none ELECTRIC PLANT STATISTICAL DATA l

Ettetric Energy Account ....................................... 401 Rev. 12 90 Monthly Peaks and Output ..................................... 401 Rev. 12-90 St:am-Electric Generating Plant Statistics (Large Plants)

..................................................... 402 - 403 Rev. 12-95 Hydroelectric Generating Plant Statistics (large Plants) ...... 406 - 407 Ed. 12-89 none Funped Storage Generating Plant Statistics (Large Plants) ..... 408 - 409 Ed. 12-88 none Generating Plant Statistics (Small Plants) .................... 410 - 411 Ed. 12-87 none FERC FORM ho 1 (REV.12 95) Page 3

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g E LIST OF SCHEDULES (Electric Utility) (Continued)

Reference Date

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Title of schedute Page No.

Remarks Revised (a) (b) (c) (d)

ELECTRIC PLANT STATISTICAL DATA (Continued)

' h..s, Transmission Line Statistics ................................. 422 - 423 Ed.12 87 Transmission Lines Added During Year ......................... 424 - 425 Ed. 12-86 none j N SL& stations .................................................. 426 427 Ed.12 95 Electric Distribution Meters and Line Transformers ........... 429 Ed. 12-88 none l

Environmental Protection Facilities .......................... 430 Ed. 12-88 j . Environmental Protection Expenses ............................ 431 Ed. 12-88 4 Footnote Data ................................................ 450 Ed. 12-87 none

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stockholders' Reports Check appropriate box:

() Four copies will be submitted.

[] No annual report to stockholders is prepared.

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P FERC FORM NO. 1 (REV. 12-95) Page 4

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k Nion 3 Dec ,

GENERAL INFORMATION 1

1. Provide name and title of of ficer having custody of the general corporate books of account and address ,

af office where the general corporate books are kept, and address of the office where any other corporate books are kept, if different from that where the general corporate books are kept.

Augustine Camara, Assistant Comptrotter EUA Service Corporation l 750 West Center street l West gridgeweter, Ma 02379  ;

2. Provide the name of the state Lmder the laws of which respondent is incorporated, and date of  ;

incorporation. If Incorporated under, a speclat law, give reference to such law. If not incorporated, j etate that fact and give the type of organization and the date orpenfred. .;

Commonwealth of Massachusetts Apri1 28, 1923  ;

Incorporated under section 9A, Chapter 164 of General Laws of Massachusetts.  !

3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) {

name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which  ;

the receiverahlp or trusteeship was created, and (d) date when possession try receiver or trustee ceased.

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4. State the classes of utility and other services furnished by respondent during the year in each State in editch the respondent operated. '

Montate Electric sold electricity under a wholesale M rate to its (3) Associated Companies: Eastern Edlaon  ;

Company Brockton, Me ; Blackstone Valley Electric of Lincoln, RI ; Newport Electric of Newport, RI ; also Pascoag Fire District of Pascoag, RI & Middleborough Gas & Electric of Middleborough, Ma.

Electricity was also sold to verlous compentes throughout the New England Power Exchange (NEPEX). Sales under one unit contracts were made to Teunton Municipal Lighting Plant, Middleborough Gas & Electric,  ;

Braintree Electric Light, Mass. Municipal Wholesale Electric, New England Power Company, Northeast Utillties, i

& Connecticut Municipal Electric Energy Cooperative. ,

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5. Have you engaged as the principal accountant to audit your financlel statements an accountant who is not the s the principal accountant for your previous year's certified financial statements?

i Yes... Enter the date when such Independent accountant was inittatty engaged: .

x No B

4 FERC FORM No.1 (ED. 12-87) Page 101 l

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ear of Report

• _ NoNn aN NNkompany *!IE2n' chi *i

,ak3AR.subnalusion {$$f3d9683gfRgrt Dec. 31,1995 CONTROL OVER RESPONDENT

1. If any corporation, businuss trust, or similar orge- name of trustee (s), name of beneficiary or beneficiaries nization or combination or such organizations jointly held for whom trust was maintained, and purpose of the control over the respondent at end of year, state name trust, cf controtting corporation or organization, manner in 2. If the above required information is avaltable from which control was held, and extent of control. If control the SEC 10 K Report Form filing, a specific reference was in a holding company organization, show the chain to the report form (i.e., year and company titte) may be i;.' af ownership or control to the main parent company or listed provided the fiscal years for both the 10-K report

. organization. If control was held by a trustee (s), state and this report are compatible.

See Annual Report of Form 10-K for the year ended December 31, 1995 of Eastern Edison Company.

Eastern Edison Company owns 100% of Montaup Electric Company.

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1 FERC FORM NO.1 (ED.12 87) Page 102

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• 0 $ i 1 yg g gt t U of Report

, c Ch31796 Dec. 31, 1995 t

CORPORATIONS CONTROLLED BY REEPONDENT

1. Report below the names of att corporations, 3. If control was held jointly with one or more other j,l

~ business trusts, and slmitar organizations, controtted interests, state the fact in a footnote and name the other G directly or indirectly by respondent at any time during interests. l the year. If control ceased prior to end of year, give par- 4. If the above required information is evaltable from

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ticulars (detalls) In a footnote. the SEC 10-K Report Form filing, a specific reference  ;

2. If control was by other means than a direct holding to the report form (f.e., year and company title) may be cf voting rights, state fr. a footnote the manner in which itsted in column (s) provided the fiscal years for both the  ;

control was held, naming any intermedlaries Irwolved. 10-K report and this are compattbte.

DEFINITIONS

1. See the Unifore System of Accounts for a definition of the other, as where the voting control is equally dt. ,

cf control. vided between two holders, or each party holds a veto ,

2. Direct contr'A is that which is exercised without in- power over the other. Joint control may exist by mutual t:rposition of an intermedlary. agreement or understanding between two or more par- I

3. Indirect control is that which is exercised by the in- ties who together have control within the meaning of t:rposition of an Intermediary which exercises direct control. the definitlon of control in the Uniform System of l

4. Joint control is that in which neither interest can Accounts, regardless of the relative voting rights of each '

cffectively control or direct action without the consent party.

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'i Name of Company Controlled Kind of Business Percent Voting Footnote g Stock owned Ref.

N 3. (a) (b) (c) (d) 1 none

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10 11 12 13 14 -

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l FERC FORM N0.1 (ED.12 95) Page 103 O

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0FFICERS

1. Report below the name, title and salary for each tion of the previous inctmbent, and the date the change executive officer whose salary is $50,000 or more. An "ex- In Inctmbency was inade.

ecutive officer" of a respondent includes its president, 3. Utilities which are required to file the same data

, secretary, treasurer, and vice president in charge of a with the Securities and Exchange Comalsalon, may principal business unit, division or function (such as substitute a copy of item 4 of Regulation S-K (Identifled sites, administration or finance), and any other person as this page). The substituted page(s) should be the who performs similar policymaking functions. same site as this page.

2. If a change was made during the year in the In-cumbent of any posit 1on, show name and total rasunera-C Lg Title Name of Officer gtg$

(a) (b) (c

n. y l I I 3

4 5

6 7

8 9

, 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43

. 44 FERC FORM No.1 (ED. 12-87) Page 104

.2 9

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Year of Report .

NEIe*d lf* eft 7f!"$ompany d8[fPjnoJys,n,tu2lk3AResdission pg$f31796te u gf gt Dec. 31,1995  !

DIRECTORS

1. Report below the inforestion called for concern- 2. Designate members of the Executive Conunittee  ;

ing each director of the respondent who held office at by a triple asterisk and the Chairmen of the Executive any time during the year. Include in column (a), ob- Connittee by a double asterisk. .)

i br'.vlated titles of the directors who are officers of the i ress ;.at.

Lg Name(andTge)ofDirector Principal Bgness Address l l l 1

2 4 Donald G. Pardus chairman. P. D. Box 2333 Boston, Me. 02107 I 5

6 John R. Stevens President P. D. Box 2333 Boston, Ms. 02107 7

8 Robert C. Powderly Exe. Vice President P. D. Box 543 W. Bridgewater, Ma. 02379

.9 10 John D. Carney Exe. Vice President P. O. Box 543 W. Bridgewater, Ma. 02379 t 11 12 David H. Gulvin Vice President P. D. Box 543 W. Bridgewater, Ms. 02379 f 13 14 Kevin A. Kirby Vice President P. O. Box 543 W. Bridgewater, Me. 02379  ;

15  !

16 17 P. O. Box 543 W. Bridgewater, Ms. 02379 18 (1) Wittlam F. O'Connor Clerk 19 20 (1) Richard M. Burns Vice President P. D. Box 2333 Boston, Ma. 02107 21 Exe. Vice President P. D. Box 2333 Boston, Ma, 02107 22 (2) Arthur A. Hatch 23 24 (1) Resigned effective 7/19/95 25 (2) Retirod 3/31/95

• 26 ,

27 28 29 30 31 32 33 34 35 ,

36 37 38 39 40 41 ~

42 .l 43 44 45 46 47

) 48 l FERC FORM NO.1 (ED. 12 95) Page 105 i

P

- - - , .~ ._ -

%v l g Na#up Wec T rMonpany c2 'kY) O A

W Inst AR2submusion Nf3N06 Dec. 31,1995 SECURITY NOLDERS AND VOTING POWERS

1. Give the names and addresses of the 10 security whereby such security became vested with voting rights and h:lders of the respondent who, at the date of the latest clos- give other important particulars (details) concerning the ing of the stock book or conpflation of list of stockholders voting rights of such security. State whether voting rights are of the respondent, prior to the end of the year had the actual or contingent; if contingent, describe the contingency.

highest voting powers in the respondent, and state the 3. If any class or issue of security has any spectet nunber of votes which each would have had the right to cast privlteges in the election of directors, trustees or managers,

,., on tht date if a meeting were then in order. If any such or in the determination of corporate action by any method, hilder held in trust, give in a footnote the known particulars explain briefly in a footnote.

of the trust (whether voting trust, etc.) duration of trust, and 4. Furnish particulars (details) concerning any options, principal holders of beneff clary Interests in the trust. If the warrants, or rights outstanding at the end of the year for stock book was not closed or a (Ist of stockholders was tot others to purchase securities of the respondent or any conpfled within one year prior to the end of the year, or if securities or other assets owned by the respondent, including since the previous conpitation of a list of stockholders, some prices, expiration dates, and other material information other class of security has become vested with voting rights, relating to exercise of the options, warrants, or rights.Specify then show such 10 security holders as of the close of the the amount of such securities or assets so entitled to be pur-ye:r. Arrange the names of the security holders in the order l chased by any officer, director, associated company, or any '

cf voting power, consnencing with the highest. Show in cot- of the ten largest .xurits 9f ders. This instruction is inap-unn (a) the titles of of ficers and directors included in such plicable to convertible securities or to any securities substan-list of 10 security holders. tielly att of which are sutstanding in the hards of the general

2. If any security other than stock carries voting rights, public where the optforv, warrants, or rights were issued on a explain in a supplemental statement the circunstances prorats basis.

1. Give date of the latest closing of the stock 2. State the total nunber of Mes cast at the 3. Give the date book prior to end of year, and state the purpose latest general meeting prior no end of year and place of such cf such closing: for election of directors or the respondent and meeting:

nunber of such votes cast by pi oxy February 6, 1995 N/A Eastern Utilities Assoc.

Total: 15,586 1 Liberty square Boston, Ma. 02107 sy proxy: 15,586 Line Nann (Title) and Address of Security Number of votes as of (date): Decesibeb 1 No. Holder Total Preferred Conmon Other Votes Stock Stock (a) (b) _

(c) (d) (e) 4 TOTAL votes of all voting securities 15,186 586 15,000 0 5 TOTAL ruber of security holders . 1 1 0 6 TOTAL votes of Security holders listed below 15,586 586 15,000 0 7

8 Eastern Edison conpany 15,566 586 15,000 0 9

10 11 12 13 14 15 16 17 18

- FERC FORM NO.1 (ED. 12-87) Page 106 NEXT PAGE IS 108

• ' I #*

E.E N $ N "bompany yon *loal k a k A RestSanssion II @

k'3U96 OD Dec. 31,1095

~,,.

IMPORTANT CHANGES DURING THE YEAR Cive particulars (details) concerning the matters indicated natural gas conpany must also state major new continuing below. Make the statements explicit and precise, and rumber sources of gas made available to it from purchases, them in accordance with the Inquiries. Each incpiry should development, purchase contract or otherwise, giving be answered. Enter a none" "not applicable," or "NA" where location and approximate total gas voltanes avaltable,  ;

applicable. If information which answers an inquiry is period of contracts, and other parties to any such given elsewhere in the report, make a reference to the arrangements etc.

schedule in which it appears. 6. obligations incurred as a result of issuance of  ;

i. Changes in and luportant additions to franchise rights: securities or asstaption of liabilities or guarantees D ucribe the actual consideration given therefor and state including issuance of short-term debt and comercial paper .

from whom the franchise rights were acquired. If accpired having a maturity of one year or less. Give reference to .i without the payment of consideration, state that fact. FERC or State Commission authorization, as oppropriate, and

2. Acquisition of ownership in other companies by the amount of obligation or guarantee.

reorganization, merger, or consolidat8on with other 7. Changes In articles of incorporation or amendernts to 3

companies: Give names of companies involved, particulars charter: Explain the nature and purpose of such changes or concerning the transactions, name of the Comission amendnents. ,

authorizing the transaction, and reference to Comission 8. State the estimated annual effect and nature of any authorization. Important wage scale changes during the year. D

3. Purchase or sale of an operating unit or system: Give 9. State briefly the status of any materlatly important a brief description of the property, and of the legal proceedings pending at the end of the year, and the transactions relattaa hereto, and reference to Consnission results of any such proceedings culminated during the year.

authorization, if any was required. Give date journal 10. Describe briefly any materfally important tran-entries called for by the Uniform system of Accounts were sections of the respondent not disclosed elsewhere in this ,

submitted to the Cor. mission. report in which an officer, director, security holder

4. Important leaseholds ( other than leaseholds for reported on page 106, voting trustee, associated conpany natural gas Lands ) that have been acquired or given, or known associate of any of these persons was a party or tssigned or surrendered: Give effective dates, lengths of in which any such person had a materlat interest.

terms, names of parties, rents, and other conditions. State 11. (Reserved.)

name of Consnission authorizing lease and give reference to such authorization.

5. Important extension or reduction of transmission or distribution system: State territory added or relinquished 12. If the inportant changes during the year relating to and date operations began or ceased and give reference to the respondent company appearing in the annual report to Connission authorization, if any was required. State also stockholders are applicable in every respect and furnish the approximate number of customers added or lost and the data required by Instructions 1 to 11 above, such notes  ;;

rpproximate annual revenues of each class of service. Each may be attached to this page.

PAGE 108 INTENT 10NALLY LEFT BLANK ,j SEE PAGE 109 FOR REQUIRED INFORMATION :1 FERC FORM NO.1 (ED.12-90) Page 108

.t

.. . . . . . = . . -. - - . . - ~ . ~ - . - - -

- - . - - - = - - - -- - - - - - -

.g -

,.::;t i

1 ;

j*  :.,. Nams of Rocpondant This Report In: Date of Report Year of Report '

' ] Montaup Electric Company (1) [x] An Original (Mo,Da,Yr)

(2) [ ] A Resubmission 03/31/96 Dec. 31, 1995 i

r '".;

.. IMPORTANT CHANGES DURING THE YEAR (Continued) i-m g 8) A general wage increase of approximately 5.0% effective March 15, 1995.

i ,.; .

i See notes to the Company's Financial Statements, beginning 4

on page 123A.

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4

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FCC FORM NO.1 (ED. 12-88) Page 109 l

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Dec. 31,1995 M oNna#up $N"bmpany k2)*k]AE0hicalAResubission COMPARATIVE BALANCE SHEET (AF. SETS AND OTHER DEBITS)

Ref. Balance at Balance at Line Title of Account End of Tear Page No. Beginning of Tear No .

(b) (c) (d)

(a)

UTILITY PLANT $555,826,470 1

200 201 5546,282,486 2 U ut1ty Plant (101 106, 114) 5,787,562 2,831,270

, 200-201 3 Construction Work in Progress (107) $5 q n70.042 5558,657,740 4 TOTAL UllLITY PLANT (Enter Total of lines 2 and 3) 147,994,800 157,837,086 200-201 5 (Less) Accm. Prov. f or Depr. Amort. Dept. (108,111,115) - 5404,075,248 5400,820,654 6 N;t Utility Plant (Enter Total of line 4 Less 5) 15,038,485 11,204,980 202-203 7 Cuclear Fuet (120.1-120.4, 120.6) 9,156,396 6,018,350 202 203 8 (L:ss) Acetan. Prov. for Amort. of Nucl. Assenblies (120.5) -

$5,882,089 55,186,630 9 N;t Nuclear Fuel (Enter Total of lines 7 Less,8) ,

' - ' 5409,957,337 $406,007,284 10 N;t Utility Plant (Enter Total of lines 6 and'9) 122 11 Utility Plant Adjustments (116) -

12 Gas Stored Underground-Noncurrent (117) 13 OTHER PROPERTY AND INVESTMENTS 2,609,614 221 2,609,614-14 No5 utility Property (121) -

'. 5 (Less) Acetsa. Prov. f or Depr. and Amort. (122) -

16 Investments in Associated Conpanies (123) 13,488,281 13,222,435 224-225 Investment in Subsidlery Companies (123.1) 17 18 (For cost of Account 123.1, See Footnote Page 224, Line 42)

MM 228-229 19 Noncurrent Portion of Attowances 20 Other Investennts (124) ~

21 Speclat Funds (125128) $16,097,895 515,832,049 22 TOTAL Other Property and Investments (Total of lines 14 - 17,19 - 21) 23 CURRENT AND ACCRUED ASSETS

- (2,140,223) 128,544 24 Cash (131) ~

25 Special Deposits (132-134) - 6,500 6,500 26 Working Fund (135) - 13,296,000 27 Temporary Cash Investments (136) 28 Notes Receivable (141) - 1,136,256 1,436,622 29 Customer Accounts Receivable (142) - 1,125,641 151,119 30 Other Accounts Receivable (143) -

31 (Less) Accum. Prov. for Uncollectible Acct.-Credit (144) -

32 Notes Receivable from Assoltated companies (145) - 53,411,952 63,125,169 33 Accounts Receivable from Assoc. Companies (146) 6,170,911 7,231,433 227 34 fuel Stock (151) 172,716 153,726 227 35 Fuel Stock Expenses undistributed (152) 227 36 Residuals (Elec) and Extracted Products (153) 1,978,202 1,992,294 227 37 Plant Materlats and Operating Supplies (154) 227 38 Merchandise (155) 227 39 other Materiets and Supplies (156) 202-203/227 40 Nuclear Materials Held for Sale (157) 34,938 228 229 41 Attowances (158.1 and 158.2) 228-229 42 (Less) Noncurrent Portion of Allowances - 45,079 41,226 43 Stores Expense Undistributed (163) -

44 Cas Stored underground Current (164.1) -

45 Liquefied Natural Gas Stored and Held for Processing (164.2-164.3) - 7,605,193 3,493,806 16 Prepayments (165) ~

47 Advances for Gas (166167) - 41,420

~48 Interest and Dividends Receivable (171) - 42,807 69,465 49 Rents Receivable (172) ~

50 Accrued Utility Revenues (173) 68,821 115,198 .

51 Miscettaneous current and Accrued Assets (174)  ; $82,961,275 $77,980,040 52 TOTAL Current and Accrued Assets (Enter Total of tines 24 thru 51)

Page 110 FERC FORM NO.1 (ED.12 94)

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~* NE[up lNcNeepany

• o t r Ef Report k ' @A Res fssion y8Mf,f96Rygt 0313 Dec. 31,1995 COMPARA11YE BALANCE SHEET (ASSETS AND OTHER DEBITS) (Cont l'*wd)

Line Title of Account Ref. Balance at Balance at .

% o. Page No. Beginning of Year End of Year l

, ,'; (a) (b) (c) (d) I 53 DEFERRED DEBI15 j 54 Unamortized Debt Expenses (181) -

.j_ _ $30,526 $28,338 l P 55 Extraordinary Property Losses (182.1) 230

,N 56 Unrecovered Plant and Regulatory Study Costs (182.2) 230 20,227,130 11.510.905 57 Other Regulatory Assets (182.3) 232 38,377,299 40,477,477 j Prelim. Survey and Irwestigation Charges (Electric) (183) y 58 -

613,913 (11,094) 59 Prelim. Sur. and Invest. Charges (Gas) (183.1,183.2) -

60 Clearing Accounts (184) -

61 Ternporary Facilities (185) -

O 62 Miscellaneous Deferred Debits (186) 233 1,242,748 2,921,102

• 0 . 63 Def. Losses from Disposition of Utility Ptt. (187) -

64 Research, Devet. and Demonste ation Expend. (188) 352-353 l

"' e .

65 Unamortized Loss on Reacquired Debt (189) - .

') 66 Acetmulated Deferred Income Taxes (190) 234 10,775,790 9,314,429 67 Unrecovered Purchased Gas Costs (191) -

O TOTAL Deferred Debits (Enter Total of Lines 54 thru 67) $71,267,406 $64,241,157

. 69 g egend other Debits (Enter Total of lines 10,11,12' $580,283,913 $564,060,530

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FERC FORM No.1 (REVISED 12-93) Page ill

1

oNnaup e N i ompany hY0hical (2) kJ AResubtssion h k**31f96kW Dec. 31,1995

~

COMPARATIVE BALANCE SHEET (LIABILITES AND OTHER CREDITS)

Line Title of Account Ref. Balance at Balance at N3. Page No. Beginning of Year End of Year (a) (b) (c) (d) 1 PROPRIETARY CAPITAL 2 Corrmon Stock issued (201) 250-251 568,600,000 $58,600,000 3 Preferred stock Issued (204) 250-251 1,500,000 1,500,000 4 Capital stock subscribed (202, 205) 252 5 Stock Liability for conversion (203, 206) 252 6 Premitse on Capital Stock (207) 252 7 Other Paid-in Capital (208 211) 253 29,528,000 29,528,000 8 Installments Received on Capital Ltock (212) 252 9 (Less) Discount on Capital stock (213) 254 10 (Less) Capital stock Expense (214) 254

_11 Retained Earnings (215, 215.1, 216) 118-119 91,158,268 92,916,771 12 unappropriated undistributed subsidiary Earnings (216.1) 118-119 3,891,727 3,674,935 13 (Less) Reacquired Capital stock (217) 250-251 14 TOTAL Proprietary Capital (Enter Total of Lines 2 thru 13) - $194,677,995 5186,219,706

• ~

15 LONG-TERM DEBT 16 Bonds (221) 256-257 171,899,113 172,169,730 17 (Less) Reacquired sonds (222) 256-257 18 Advances from Associated Conpanies (223) 256-257 19 Other Long-term Debt (224) 256-257 20 unamortized Premium on Long-Term Debt (225) -

21 (Less) unamortized Discount on Long Term Debt-Debit (226) -

22 TOTAL Long-Term Debt (Enter Total of Lines 16 thru 21) - $171,899,113 $172,169,730 23 OTHER NONCURRENT LIABILITIES 24 Obligations under capital Leases-Noncurrent (227) -

25 Acetsnulated Provision for Property Insurance (228.1) -

26 AccLanulated Provision for Injuries and Damages (228.2) -

27 Accumulated Provision for Pensions and Benefits (228.3) -

28 Accumulated Miscellaneous Operating Provisions (228.4) - 511,155 504,082 29 Acetanulated Provision for Rate Refunds (229) - 7,329,995 4,141,886 30 TOTAL OTHER Noncurrent Liabilities (Enter Total of lines 24 thru 29) 57,841,150 54,645,968 31 CURRENT AND ACCRUED LIABILITIES 32 Notes Payable (231) -

33 Accomte Payable (232) - 23,086,796 26,526,255 34 Notes Payable to Associated Conpanies (233) -

35 Account Payable to Associated Companies (234) - 3,174,688 1,807,446

?6 Customer Deposits (235) -

[J7 Taxes Accrued (236) 262 263 686,160 1,809,693 38 Interest Accrued (237) - 5,346,809 5,131,500 39 Dividends Declared (238) -

60 Matured Long-Term Debt (239) -

41 Matured Interests (240) -

42 Tax Collections Payable (241) -

43 Miscellaneous Current and Accrued Liabilities (242) 6,269,822 2,833,802 44 Obligations Under capital Leases-Current (243) 45 TOTAL Current and Accrued Liabilities (Enter Total of lines 32 thru 44) 538,564,275 538,108,696 l

i FERC FORM No.1 (ED. 12 89) Page 112

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NoNn eup kNNbonpany o

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!j"k A Res* hiission cal k'b3f796'Y%'

O Dec. 31, 1995 COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CRECITS) (Continued)

Line Title of Account Ref. Balance at Balance at N 3. Page No. Beginning of Year End of Year (a) (b) (c) (d) 46 DEFERRED CREDITS 47 Customer Aerances for Construction (252) 48 Accumulated Deferred Investment Tax credits (255) 266-267 14,238,245

, 13,610,093 49 Deferred Gains from Disposition of Utility Plant (256) 50 other Deferred Credits (253) 269 19, % 9,215 11,723,537 31 Other Regulatory Liabilities (254) 278 19,424,498 17,429,814 52 unamortized Gain on Reacquired Debt (257) 269 53 Accumulated Deferred Income Taxes (281283) 272 277 113,669,422 120,152,986 54 TOTAL Deferred Credits (Enter Total of Lines 47 thru 53) 5167,301,380 S162,916,430 55 56 57 58 59 60 61 62 63

- g 65 66 67 65 gTgL Lgilities and other Credits (Enter Total of Lines 14, 22, 30, $580,283.'13v $564,060,530 4

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W FERC FORM NO.1 (REVISED 12 93) Page 113

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t yate of gt Year M Rep m

$*Eieup h[*eMc'"bonpany k((Pg30g;0,tJAResubssion f OD3N96 Dec. 31,1995 STATEMENT OF INCOME FOR THE YEAR

1. Report amomts for accounts 412 and 413, Revenue and 5. Give concise explanations concerning unsettled rate Expenses from Utility Plant Leased to others, in another proceedings where a contingency exists such that refunds utility cottan (I,k,m,o) in a similar manner to a utility of a material amount may need to be made to the utility's department. Spread the amount (s) over lines 02 thru 24 as customers or which may result in a material refmd to the appropriate. Include these amounts in columns (c) and (d) utility with respect to power or gas purchases. State for titels. each year effected the gross revenues or costs to which the

2. Report amomts in account 414, other Utility operating contingency relates and the tax effects together with an income, in the same manner as accounts 412 and 413 above. explemtion of the major factors which affect the rights of

3. Report data for lines 7,9, and 10 for Natural Gas com- the utility to retain such revenues or recover amounts paid panies using accomts 404.1, 404.2, 404.3, 407.1 and 407.2. with respect to power and gas purche cs.

4. Use page 122 for important notes regarding the state- 6. Give concise explanations concerning si t e,1ficant sent of income or any account thereof. amounts of any refunds made or received dJing the rear. ,

Account (Ref.) TOTAL

o. PagNo. Curre Year Previ g Year 1 UTILITY OPERATING INCOME M 2 Operating Revenues (400) 300-301 5345,737,930 $345,514,918 3 operating Expenses 4 operation Expenses (401) 320-323 267,928,711 267,15f,290 5 Maintenance Expenses (402) 320-323 10,234,192 9,534,053 6 Depreciation Expense (403) 336-337 16,322,578 16,242,709 7 Amort. & Dept. of Utility Plant (404 405) 336 337 18,737 14,719 8 Amort. of Utility Plant Acq. Adj. (406) 336-337 0 59,894 9 Amort. of Property Losses, Unrecovered Plant and Regulatory study Costs (407) 0 0 10 Amort. of Conversion Expenses (407) 0 0 Regulatory Debits (407.3) 0 0 11 12 (Less) Regulatory credits (407.4) 0 0 13 Taxes other Than Income Taxes (408.1) 262-263 5,876,891 6,185,307 14 Income Taxes - Federal (409.1) 262-263 3,900,037 3,301,741 15 - other (409.1) 262 263 958,428 627,684 16 Provision for Deferred Income Taxes (410.1) 234,272 277 6,183,315 7,714,326 234,272 277 2,770,432 2,847,855 17 (Less) Provision for Deferred Income Taxes - Cr. (411.1) 18 Investment Tax credit Adj. - Net (411.4) 266 (628,152) (31,489) 19 (Less) Cains from Disp. of Utility Plant (411.6) 0 20 Losses from Disp. of Utility Plant (411.7) 21 (Less) Gains from Disposition of Allowances (411.8) 62,881 22 Losses from Disposition of Attowances (411.9) 23 TOTAL Utility Operating Expenses (Enter Total of Lines 4 thru 22) 5307,961,424 5307,960,379 2$ Net Utility Operating Income (Enter Total of line 2 tess 23) (Carry forward to page 117, line 25) 537,776,506 $37,554,539 ll l

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FERC FORM NO.1 (REY. 12-95) Page 114 l

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\  : l D eN $ EE M ompany

• 80 GU cf ePort 0 cal

i. A Res ission {OD3ff96Ryyt Dec. 31,1995 1;l STATEMENT OF INCOME FOR THE YEAR (Continued)

.$ resulting from settlement of any rate proceeding affecting had an effect on net income, including the basis of attoca-

, , revenues received or costs incurred for power or gas tions and apportionments from those used in the preceding purchases, and a susnary of the adjustaents made to balance year. Also give the approximate dotter ef fect of such changes.

sheet, income, and expense accounts. 9. Explain in a footnote if the previous year's figures

~l,' 7. If any notes appearing in the report to stockholders are different from that reported in prior reports.

V cre applicable to this Statement of Income, such note. may 10. If the colums are insufficient for reporting ad-be attached at page 122. ditional utility departments, s@ ply the appropriate account

,_s 8. Enter on page 122 a concise explanation of only those titles, lines 2 to 23, and report the information in the changes in accounting methods made chring the year which blank space on page 122 or in a supplemercat statement.

ELECTRIC UTILITY CAS UTILITY OTHER UTILITY Currgfear Previg Year CurregYear Previ g Year CurregYear Previ g Year

$345,737,930 5345,514,918 2

_ 3_

267,928,711 267,159,290 4

! 10,234,192 9,534,053 5 16,322,578 16,242,709 6 18,737 14,719 7 59,894 8 9

10

r. 11 12 5,876,891 6,185,307 13 3,900,037 3,301,741 14 958,428 627,684 15 6,183,315 7,714,326 16 2,770,432 2,847,855 17

} (628,152) (31,489) 18 19 20 62,681 21 22

$307,961,424 5307,960,379 23 24

$37,776,506 $37,554,539 l

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Nameafg eng Tl s R port

• Date of Re rt Year of Report k Rs slon D3 06 Dec. 31, 1995 '

STATEMENT OF INCOME FOR THE YEAR (continued)

Account (Ref.) TOTAL PagNo. CurrgYear Prev g Year 25 Net Utility operating income (Carried forward from page 114) -

537,776,506l $37,554,539 26 Other Income and Deductions 27 other Income 28 Nonutility Operating income 29 Revenues f rom Merchandising, Jobbing and contract Work (415) l 30 (Less) Costs and Exp. of Merchandising, Job. & Contract Work (416) l '

31 Revenues From Nonutility Operations (417) l

, 32 (Less) Expenses of Nonutility Operations (417.1) l 33 Nonoperating Rental Income (418) l 34 Equity in Earnings of subsidiary Companies (418.1) 119 1,646,357l 1,700,065 4

35 Interest and Dividend inecme (419) 259,239l 418,965 36 Allowance for other Fmds Used During Construction (419.1) 433,894l 172,014 37 Miscettaneous Nonoperating Income (421) 408,898) 1,002,728 1

38 Gain on Disposition of Property (421.1) l 39 TOTAL Other Income (Enter Total of lines 29 thru 38) 52,748,388l $3,293,772 40 Other Incone Deductions 41 Loss on Disposition of Property (421.2) l j 42 Miscellaneous Amortization (425) 340 l 43 Miscellaneous Income Deductions (426.1-426.5) 340 26,Y44) _49,479

. 44 TOTAL Other Income Deductions (Total of lines 41 thru 43) $26,944l $49,479 4.5 - Taxes Applic to other Income and Deductions 46 Taxes other Than income Taxes (408.2) 262-263 l 47 Income Taxes - Federat (409.2)

• 262-263 310,600l 423,405 48 Income Taxes - other (409.2) 262 263 111,725l 149,021 49 Provision for Deferred Inc. Taxes (410.2) 234,272 277 (67,224)l (67,224) 50 (Less) Provision for Deferred Income Taxes Cr. (411.2) 234,272 277 l 51 Investment Tax Credit Adj. - Net (411.5) l 52 (Less) Investment Tax Credits (420) l 53 TOTAL Taxes on Other Income and Deduct. (Total of 46 thru 52) $355,101) S505,202 54 Net Other Income and Deductions (Enter Total of lines 39, 44, 53) $2,366,343l 52,739,091 55 Interest Charges ,c 56 Interest on Long-Term Debt (427) 19,994,750l 19,994,750 57 Amort. of Debt Disc. and Expense (428) 68,950l 58,799 58 Amortization of Loss on Reacquired Debt (428,1) 203,B55l 202,612 59 (less) Amort. of Premium on Debt Credit (429) l 60 (Less) Amortization of Gain on Reacquired Debt - Credit (429.1) l 61 Interest on Debt to Assoc. Companies (430) 340 l 62 Other Interest Expense (431) 340 596,692l 913,890 63 (Less) Allowance for Borrowed Fmds Used During Construction-Cr. (432) 419,009l 716,953 64 Net Interest Charges (Enter Total of lines 56 thru 63) $20,445,238) $20,v53,098 6b Income Before Extraordinary items (Total of lines 25, 54 and 64) 319,697,611l 519,340,532 66 Extraordinary Items 67 Extraordinary income (434) 68 (Less) Extraordins. / Deductions (435) 69 Net Extraordinary items (Enter Total of line 67 less line 68) 70 Income Taxes-Federal and other (409.3) 262-263 71 Extraordinary items Af ter Taxew (Enter Total of line 69 tess line 70) 72 Net income (Enter Total of lines 65 and 71) 519,697,611 $19,340,532 FERC FORM No.1 (ED. 12-94) Page 117

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Nameefgs ngmpany " sR t g*

Dit3 f Re rt YGsr 6f Report

._ A ,gs g slon D3 06 ' Dec. 31, 1995 I STATEMENT OF RETAINED EARNINGS FOR THE TEAR

1. Report att changes in appropriated retained earnings, 5. Show dividends for each class and series of unappropriated retained earnings, and unappropriated mdis- capital stock, tributed sdaldlary earnings for the the year. 6. Show separately the State and Federal income trx ef fect

2. Each credit and debit during the year should be of items shown in account 439, Adjustments to Retained identified as to the retained earnings account in which Earnings. {

recorded ( Accounts 433, 436 - 439 inclusive ). Show the 7. Explain in a footnote the basis for cetermining contra primary account affected in column (b). the amount reserved or appropriated. If such reserva- )

3. State the purpose and amount of each reservation or tion or appropriation is to be recurrent, state the appropriation of retained earnings. ranber and annual amomts to be reserved or appro-

4. t,ist first accomt 439, Adjustments to Retained priated as well as the totals eventually to be Earnings, reflecting adjustments to the opening balance of accunulated.

retained earnings. Follow by credit, then debit items 8. If any notes appearing in the report to stockholders in that order, are applicable to this statement, attach them at page 122.

5?5*

{ne Item go Amount

' (a) (N (c)

\

UhAPPROPRI ATED RETAINED EARNINGS (Accomt 216) '

Balance - Beginning of Tear 2

1 Changes (Identify by prescribed retained earninsa accounts)

Ml $91,158,268 l l

3 Adjustments to Retained Earnings (Account 439) 6 Credits l 5 Credits l 6 Credits l 7 Credit: l

'. 8 Credit l 9 TOTAL Credits to Retained Earnings (Acc. 439) (Total of lines 4 thru 8) l l

^; 10 Debit l 11 Debit l 12 Debit: l 13 Debit l 14 Debit: l 15 TOTAL Debits to Retained Earnings (Acc. 439) (Total of lines 10 thru 14) l 16 Balance Transferred from Income (Account 433 less Account 418.1) 18,051,254 l

17 Appropriations of Retained Earnings (Account 436)

- 18 19 20 21 22 TOTAL Appropriations of Retained Earnings (Acc. 436) (Total of lines 18 thru 21) 23 Dividends Declared - Preferred Stock (Account 437) 24 (388,500) 25 26 27 28 29 TOTAL Dividends Declared - Preferred Stock (Acet. 437) (Total of lines 24 thru 28) (388,500) 30 Dividends Declared - Common Stock ( Account 438) M 31 (17,767,400) 32 33 ,

3' 35 36 TOTAL Dividends Declared - Comon Stock (Acet. 438) (Total of lines 31 thru 35) (s17,767,400,,

37 Transfers f rom Acet. 216.1, Unappropriated Undistributed Subsidiary Earnings 1,863,149 38 Balance - End of Tear (Total of lines 01, 09,15,16, 22, 29, 36, ard 37) $92,916,77' FERC FORM NO.1 (ED. 12 89) Page 118

=

?!sion 3 '96 ,

STATEMENT OF RETAINED EARNINGS FOR THE YEAR (Continued)

Y APPROPRIATED RETAINED EARNINGS (Accomt 215)

State balance and purpose of each appropriated retained earnings amount at end of year and give -

accounting entries for any applications of appropriated retained earnings during the year.

39 40 41 42 43 44 45 TOTAL Appropriated Retained Earnings (Account 215) -

APPROPRIATEDRETAINEDgN SgO IZATION RESERVE,FEDERA'.

state below the total amount set aside through appropriations of retained earnings, as of the end of the year, in compliance with the provisions of Federetty granted hydroelectric project Licenses .. .

held by the respondent. If any reductions or changes other than the normal annual credits hereto have ,,

been made ciaring the year, explain such items in a footnote.

46 TOTAL Appropriated Retained Earnings - Amortization Reserve, Federal (Account 215.1) 47 TOTAL Appropriated Retained Earnings (Account 215, 215.1) (Enter total of lines 45 and 46) 48 TOTAL Retained Earnings (Account 215, 215.1, 216) (Enter total of lines 38 and 47) $92,916,771 UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (ACCOUNT 216.1) 49 Balance - Beginning of Year (Debit or Credit) 3,891,727 50 Equity in Earnings for Year (Credit) (Account 418.1) 1,646,357 51 (Less) Dividenda Received (Debit) 1,863,149 52 Other Changes (Explain) 53 Balance - End of Year (Total of Lines 49 Thru 52) $3,674,935 6

FERC FORM NO.1 (ED.12-94) Page 119

. 1

.- l l

e i w N AIJh blk W bOMPANY leal kh)kx N O3 A Restlxussion Nh 03/E0/h5) Dec. 31,1994 STATEMENT OF RETAINED EARNINGS FOR THE YEAR

1. Report all changes in appropriated retained earnings, 5. Show divideres for each class and series of  ;

, mappropriated retained earnings, and mappropriated mdis- capital stock.

tributed sLbsidiary earnings for the the year. 6. Show separately the State and Federal Income tax effect  !

2. Each credit and debit daring the year should be of items shown in account 439, Adjustments to b tained  !

identifled as to the retained earnings account in which Earnings.

recorded ( Accomts 433, 436 439 inclusive ). Show the 7. Explain in a footnote the basis for determining the contra primary accomt affected in colum (b). the amount reserved or appropriated. If steh reserva-

3. State the purpose ord amomt of each reservation or tion or appropriation is to be recurrent, state the

, appropriation of retained eamings. s number and anrual amounts to be reserved or appro-

4. List first account 439, Adjustments to Retained priated as well as the totals eventually to be Earnings, reflecting adjustmerrts to the opening balance of accumJtated.

retained eamings. Follow by credit, then debit items 8. If any notes appearing in the report to stockholders in that order. are applicable to this statement, attach them at page 122.

" * ^"*

Ma' (a) if{Uh?b*'!d (c)

UNAPPROPRIATED RETAINED LARNINGS (Accomt 216) 1 Balance - Beginning of Year ] $91,0W,,708 2 Changes (Identify by prescribed retained earnings accounts) ___

3 Adjustments to Retained Eamings (Account 439) 4 Credit:

~~

5 Credits 6 Credits 7 Credits 8 Credits 9 TOTAL Credits to Retained Earnings (Acc. 439) (Total of lines 4 thru 8) 10 Debit:

4 11 Debits 12 Debit: J 13 Debit: ,

14 Debit:

15 TOTAL Debits to Retained Earnings (Acc. 439) (Total of lines 10 thru 14) 16 Batance Trarsferred from Income (Acenmt 433 Less Account 418.1) 17,640,467

, 17 Appropriations of Retained Earnings (Account 436) 18

! 19 20 21 22 TOTAL Amropriations of Retained Earnings (Acc. 436) (Total of lines 18 thru 21) 23 Dividends Declared Preferred Stock (Account 437) 24 PREFERRED (409,200) 25 26 27 j 23 l 29 TOTAL Dividends Declared Preferred Stock (Acet. 437) (Total of lines 24 thru 28) (409,200) 30 Dividends Declared Ccamon Stock (Account 438) _

31 COMON (18,714,0B0)

~32 33 34

)

35 36 TOTAL Dividends Declared Common Stock (Acct. 438) (Total of lines 31 thru 35) ($18,714,080) 37 Transfers from cct. 216.1, unapprcpriated Undistributed subsidiary Eamings 1,636,373

- 38 Balance End of Tear (Total of lines 01, 09, 15, 16, 22, 29, 36, and 37) 591,158,268 FERC FORM No.1 (ED. 12-89) Page 118 A

NAP hN bPANY h b0 i ission C2j *k 3 A ResEnal N120795 Dec. 31,1994 STATEMENT OF RETAINED EARNINGS FOR THE YEAR (Continued)

& 1s$ Y APPROPRIATED RETAINED EARNINGS (Account 215)

State betwe and purpose of each appropriated retained earnings amount at end of year and give accounting entries for any applications of appropriated retained earnings during the year.

39 NONE 60 61 43 43 OS 45 TOTAL Appropriated Retained Earnings (Accomt 215)

APPROPRIATEDRETAINEDgN S g IZATION RESERVE, FEDERAL State below the total anomt set aside through appropriations of retained earnings, as of the end . ,

of the year, in conplierre with the provisions of Federetty granted h)droelectric project licenses .!

held ty the respondent. If any redactions or changes other than the normat annual credits hereto have i been made during the year, explain such items in a footnote. .

46 TOTAL Appropriated Retained Earnings - Amortization Reserve, Federal (Account 215.1) :l

.j 47 TOTAL Appropriated Retained Earnings (Accomt 215, 215.1) (Enter total of lines 45 and 46) j 48 TOTAL Retained Earnings (Accomt 215, 215.1, 216) (Enter total of Lines 38 and 47) $91,158,268 UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (ACCOUNT 216.1) l 69 Balarse - Begining of Year (Debit or credit) 3,828,035 50 Equity in Earnings for Year (Credit) (Accomt 418.1) 1,700,065 51 (Less) Dividends Received (Debit) 1,636,373 52 Other (hanges (Explain) '

53 Balance - End of Year (Total of Lines 49 Thru 52) 53,891,727 1

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FERC FORM NO.1 (ED. 12 94) Page 119A

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of Report E k N ionpany kjkJAResu* ! N 0 % ssionf2OD3N06 7 Dec. 31, 1995 i

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STATEMENT OF CASH Flous

1. If the notes to the cash flow statement in the respondents 2. Under "Other" specif y significant amounts and group others, annual stockholders report are applicable to this state- 3. Operating Activities - Other: Include gains and losses per-ment, such notes should be attached to page 122. Informa- talning to operating activities only. Gains and losses per-tion about noncash investing and financing activities teining to investing and financing activities should be should be provided on page 122. Provide also on page 122 a reported in those activities. Show on page 122 the amounts

. reconcillation between " Cash and Cash Equivalents at End of interest paid ( net of amounts capitallred ) and income cf Tear" with related amounts on the balance sheet. taxes paid.

Line Description (See Instruction No. 5 for Explanation of Codes) Amounts H2. (a) (b) 1 Net Cash Flow free Operating Activities:

2 Net income (Line 72(c) on page 117) $19,697,611 3 Noncash Charges (Credits) to income:

4 Depreciation and Depl6 tion 15,367,047 5 Amortization of (Specify) 6 Nuclear Fuel - 3,646,532 Debt Expense - 272,806 3,919,338 7 Elec. Plant - 11,924 Deferred Debits - 1,137,162 1,149,086 8 Deferred Income Taxes (Net) 3,345,659 9 Investment Tax credit Adjustment (het) (628,152) 10 Net (Increase) Decrease in Receivables (9,065,718) 11 Net (Increase) Decrease in Inventory (1,086,710) 12 Net (Increase) Decrease in Allowances Inventory 13 Net increase (Decrease) in Payables and Accrued Expenses 3,195,750 15 Net (Increase) Decrease in Other Regulatory Assets (2,100,177) 15 Net Increase (Decrease) in Other Regulatory Liabilities (1,994,684)

(Less) Allowance for other Funds Used During Construction 433,894 16 17 (Less) Undistributed Earnings from Subsidiary Companies 1,558,497 18 Other: Current Assets Current Liabilities (6,839,440) 19 Other Net 5,706,627 20 21 Net Cash Provided by (Used in) Operating Activities (Total of lines 2 thru 21) 531,790,840 22 23 25 Cash Flows from Investment Activities:

25 Construction ord Acquisition of Plant (Including Land):

Gross Additions to Utility Plant (less nuclear fuel) (15,096,065) 26 27 Gross Additions to Nuclear Fuel 28 Gross Additions to Comon Utility Plant 29 Gross Additions to Nonutility Plant (Less) Allowance for Other Funds Used During Construction 433,894 30 31 Others 32 33

($14,662,171) 34 Cash Outflows for Plant (Total of lines 26 thru 33) 35 36 Acquisition of Other koncurrent Assets (d) 37 Proceeds f rom Disposal of Noncurrent Assets (d) 38 29 Investments in and AWances to Assoc. and Subsidiary Conpanies 40 Contributions and AWances from Assoc. and Subsidiary Companies 41 Disposition of Investments in (and Advances to) 42 Associated and subsidiary Carpenies 43 44 Purchase of Investment Securities (a) 45 Proceeds from Sales of Investment Securities (a)

FERC FORM NO.1 (ED. 12-94) Page 120

N Ah EN W hCMPANY OWinal u) k J t Rest 2xussion 83/2h9bW Dec, 31, 1994 STATEMENT OF CASH tLOWS (Continued)

6. Investing Activities 5. Codes used:

Include at other (Line 31) net cash outflow to acquire other (a) Net proceeds or payments.

conpanies. Provide a reconciliation of assets acquired with (b) Bonds, debentures and other long term debt.

Liab1Lities assuned on pape 122. (c) Include comnercial paper.

Do not incttde on this statement the dollar amotsit of leases (d) Identify separately such items as investments, fixed capitalized per US of A Generat Instruction 20; instead assets, intangibles, etc.

provide a reconciliation of the dollar amount of leases 6. Enter on page 122 clarifications and explanations.

capitalized with the plant cost on page 122.

Line Description (See Instruction No. 5 for Explanation of Codes) Amounts No. (a) (b) 46 Loans Made or Purchased 47 Collections on Loans 48 49 Net (Increase) Decrease in Receivables 50 Net (Increase) Decrease in Inventory 51 Net (Increase) Decrease in Allowances Held for Speculation 53 Net Increase (Decrease) in Payables and Accrued Expenses 53 Other 54 55 56 Net Cash Provided by (Used in) Investing Activities 57 (Total of lines 34 thru 55 ) (512,057,782) .

58 59 Cash Flows from Financing Activities 60 Proceeds frcun Issuance of:

61 Long - Term Debt (b) 62 Preferred Stock 63 Ce.- ,. Stock 64 Others 65 66 Net Increase in Short - Term Debt (c) 67 Other:

68

q

(

69 '

1 70 Cash Provided by Outside Sources (Total of lines 61 thru 69) 71 72 Payments for Retirement of:

73 Long - term Debt (b) 74 Preferred Stock 75 Common Stock I 76 other:

77 78 Net Decrease in Short-Ters Debt (c) 79 80 Dividends on Preferred Stock (409,200) 81 Dividends on Comen Stock (18,714,080) 82 Net Cash provided by (Used in) Finarcing Activities 83 (Total of lines 70 thru 81) (S19,123,280) 84 83 Net Increase (Decrease in Cash ard Cash Equivalents 86 (Total of lines 22, 57,and 83) 510,466,441 87 88 Cash and Cash Equivalents at Beginning of Year 695,836 89 90 Cash and Cash Ecpivalents at End of Year 11,162,277 -

FERC FORM NO.1 (ED. 12 94) Page 121 A

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g/j l{sgg h' a I k g3tApRest s,issiong gtsgfRgrt Year af Report

_g 2m 0S131796 Dec. 31, 1995 l .f NOTES TO FINANCIAL STATEMENTS 5

1. Use the space below for toportant notes regarding the plan of disposition contenplated, giving references to Com-I sitance Sheet, Statement of Income for the year, Statement mission orders or other authorizations respecting classifica-7 af R:tained Earnings for the year, and Statement of Cash tion of amounts as plant adjustments and re@lraments as

.. Flows, or any account thereof. Classify the notes according to disposition thereof.

ta cach basic statement, providing a subheading for each 4. Where Accounts 189, Unamortized Loss on Reacquired eft st:tement except where a note is applicable to more than Debt, and 257, Unamortized Cain on Reacquired Debt, are

• *!I one ctatement. not used, give an explanation, providing the rate treatment

2. Furnish portfeuters (details) as to any significant contin- given these items. See Generat Instruction 17 of the Uniform sent assets or liabilities existing at end of year, including a System of Accounts.

brl:f explanation of any action initiated by the Internal 5. Give a concise explanation of any retained earnings Revenue Service involving possible assesament of additional restrictions and state the amount of retained earnings affected income taxes of materlat amount, or of a claim for refund of by such restrictions.

• Income taxes of a materlat anoint initiated by the utility.Give 6. If the notes to financial statements relating to the also a brief explanation of any divldends in arrears on respondent company appearing in the annual report to the cunutative preferred stock, stockholders are applicable and furnish the data required by h 3. For Accotet 116, Utility Plant Adjustments, explain the trigin of such amount, debits and credits daring the year, and instructions above and on pages 114-121, such notes may be attached hereto.

- PAGE 122 INTENTIONALLY LEFT gLANK SEE PAGE 123 FOR REQUIRED INFORMATION W.

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l l FERC FORM NO.1 (ED. 12 88) Page 122

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4.a Y

MONTAUF ELECTRIC COMPANY * ,

NOTES TO FINANCIAL STATEMENTS December 31, 1995 and 1994 i

t (A) Nature of Operations and Summary of Significant Accounting Policies:

e

- General: Montaup Electric Company (the " Company) is a generation and h,',

transmission company which supplies electricity to associated companies and to two unaffiliated utilities for resale.

The preparation of financial statements in conformity. with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and "

disclosure of contingent assets and liabilities at the date of the financial .

statements and the reported amounts of revenues and expenses during the  :,

reporting period. Actual results could differ from those estimates.

The accounting policies and practices of Montaup Electric are subject to regulation by the Federal Energy Regulatory Commission (FERC) with respect to -'

their rates and accounting. Montaup Electric ccuforms with generally accepted accounting principles, as applied in the case of regulated public utilities, "'

and conform with the accounting requirements and ratemaking practices of the PERC. .:

Reclassifications: Certain prior period amounts on the financial statements have been reclassified to conform with current presentation.

Jointly Owned Companies: The Company follows the equity met. hod of accounting for its stock ownership investments in jointly owned companies

- including four regional nuclear generating companies. The Company's investments in these nuclear generating companies range from 2.25 to 4.50 ,

percent. The Company is entitled to the electricity produced from these ~

facilities based on its ownership interests and is billed pursuant to contractual agreements which are approved by FERC.

One of the four nuclear generating facilities is being decommissioned, but Montaup is required to pay its share of certain continuing costs (see Note I -

Commitments and Contingencies - Nuclear Power Issues). -

Montaup also has an equity investment of 3.27% in each of the- two companies which own and operate interconnection facilities used to transmit hydroelectric power between the Hydro-Quebec Electric System and New England.

Transactions with Affiliates: The Company is a wholly-owned subsidiary of Eastern Edison Company (Eastern Edison), a subsidiary of Eastern Utilities Associates. In addition to its investment in the Company and Eastern Edison, EUA has interests in two, other retail wholesale utility companies, a service corporation, and three other non-utility companies.

• 123A

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(A) Summary of Significant Accounting Policies - (Continued)  ;

-3 .

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r e Transactions between Montaup and other affiliated companies include the ,

L,/. '

following: sales of electricity by the Company to Blackstone, Newport and'  !

Eastern Edison of approximately $327,469,000 in 1995 and $319,011,000 in 1994; i

accounting,. engineering and other services rendered by EUA Service of

'M, approximately $10,522,000 and $10,759,000 in 1995 and 1994 respectively; ,

:," operating expense from the rental of transmission facilities to the Company by

• l Eastern Edison, Blackstone Valley and Newport of approximately $5,442,000 in u 1995 and $4,283,000 in 1994; and Montaup rental of transmission facilities to Newport and Eastern Edison for the years 1995, and 1994, amounted to $95,000 and $303,000 respectively. Transactions with affiliated companies are subject to' review by applicable regulatory commissions.

, Utility Plant and Depreciation: Utility plant is stated at original cost. The cost of additions to utility plant includes contracted work, direct m labor and material, allocable overhead, allowance for funds used during

, construction - and indirect charges for engineering and supervision. For financial statement purposes, depreciation is computed on the straight-line method based on estimated useful lives of the various classes of property.

2 Provisions for depreciation were equivalent to a composite rate of approximately 2.8% for 1995 and 1994 based on the average depreciable property balances at the beginning and and of each year.

, 1 l

Electric Plant Held for Future Use: In January 1994 Montaup determined

! that it would not be economically feasible to bring its 42-year old, coal-fired i

"a Somerset Station Unit 5 generating unit into compliance with Clean Air Act l Amenemts of 1990 (Clean Air Act). The unit was placed in cold storage and its nes. investment, $5.4 million, was transferred to electric plant held for future use pending final determination by Montaup of . its usefulness. "ader ,

l terms of the settlement agreement filed with FERC, entered into by %Jcaup and l the intervenors in Montaup's 1994 rate decrease application Montaup continues j to earn a return on the net investment of the unit. l l

, Regulatory Accounting: Montaup Electric is subject to certain accounting i

!- rules that are not applicable to other industries. These accounting rules allow regulated- companies, in appropriate circumstances, to establish S regulatory assets and liabilities, which defer the current financial impact of i

. certain costs that are expected to be recovered in future rates.

~

Montaup i Electric believes that its operations continue to meet the criteria established in these accounting standards. Effects of legislation and/or regulatory initiatives or EUA's own initiatives such as " Choice and Competition" could  !

ultimately cause Montaup Electric to no longer follow these accounting rules.

in such an event, a non-cash write-off of regulatory assets and liabilities could be required at that time.

Allowance for Funds Used During Construction: AFUDC represents the  ;

estimated cost of borrowed and equity funds used to finance the Company's construction program. In accordance with regulatory accounting. AFUDC is  ;

capitalized, as a cost of' utility plant, in the same manner as certain general l and administrative costs. AFUDC is not an item of current cash income, but is recovered over the service life of utility plant in the form of increased The combined

revenues collected as a result of higher depreciation expense.

rate used in calculating AFUDC was 9.3% in 1995 and 9.5% in 1994.

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6 (A) Summary of Significant Accounting Folicies - (Continued) ,

Operating Revenues: Revenues are based on billing rates authorized by FERC. The Company recognizes revenues when billed. In addition, it also records the difference between fuel costs incurred and fuel costs billed. The Company also records the difference between purchased power costs incurred and billed. ',

Income Taxes: The general policy of the Company with respect to ~~..

accounting for federal income taxes is to reflect in income the estimated amount of taxes currently payable, as determined from the consolidated tax return on an allocated basis, and to provide for deferred taxes on certain items subject to temporary differences to the extent permitted by the various regulatory commissions. See Note C - Income Taxes for further details.

As permitted by the regulatory commissions, it is the policy of the Company to defer recognition of the annual investment tax credits and to amortize these credits over the productive lives of the related assets.

Cash and Temporary Cash Investments: The Company considers all highly liquid investments and temporary cash investments with a maturity of three months or less, when acquired, to be cash equivalents.

New Accounting Standard:- In March 1995, the Financial Accounting Standards Board issued Statement of Financial Accounting Standard No. 121,

" Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed of" (FAS 121), effective for fiscal year 1996. FAS 121 requires all regulatory assets, aasets which were established as a result of high probability of recovery in a regulated environment, to continue to meet that high probability of recovery at each balance sheet date. Based on the current .

regulatory framework, management does not expect that adoption of this standard vill have a material effect on Montaup's financial position or results of -

operation. However, this assumption may change in the future as changes are made in the current regulatory framework or as competitive factors influence wholesale and retail pricing in the electric utility industry.

(B) Rate Activity sad Electric Utility Industry Restructuring:

Rates: On May 21, 1994 Montaup filed an application with the FERC for authorization to reduce its wholesale rates by $10.1 million or three percent.

Montaup supplies electricity at wholesale to EUA's retail electric utilities -

Eastern Edison, Blackstone and Newport - and to two non-af filiated municipal utilities. This application was designed to match more closely Montaup's revenue with its decreasing cost of doing business resulting from, among other things, a reduced rate base, lower interest costs and successful cost control efforts.

On May 21, 1994, Montaup began billing the reduced rates, and on April 14, 1995, FERC approved a settlement agreement between Montaup and the intervenors in the case calling for an annual reduction of approximately $13.9 million (inclusive of the filed $10.1 million reduction).

Montaup refunded to its customers the difference collected between the

$10.1 million filed reduction and the $13.9 million settled reduction in April 1995. Montaup had previously reserved for that refund.

5 123C

T.A

.o-

. t

7 Electric Utility Industry Restructuring

The electric industry is in a period  ;

y' . of transition from a traditional rate. regulated environment to a competitive  !

marketplace. While competition in the wholesale electric market is not new, l

,,.,., electric utilities are facing impending competition in the retail sector.

l S.n  !

In . January 1996, EUA unveiled its preliminary proposal for a restructured -l l-electric utility industry called " Choice and Competition" and began discussions {

l $, . with the Rhode . Island and Massachusetts Collaboratives. The plan proposes,

?? among other things: choice of power supplier by all customers as early as l L January 1998; open access transmission services; performance based rates for t

, electric distribution services; all utility generation competing for power I

f. '

sales and; a transition charge allowing regional utilities the opportunity to i recover, among other things, the costs of past comunitments to nuclear and l independent power. The company believes the plan, which requires participation  ;

, 7. by all New ~ England parties, satisfies the principles adopted in both Rhode '

! , E) Island and Massachusetts,- and provides a fair and equitable transition to a  ;

competitive electric utility marketplace for all parties. j m) i l jj, Historically, electric rates have been designed to recover a utility's l- full costs of providing electric service including recovery of investment in  ;

plant assets. Also, in a regulated' environment, electric utilities are subject i

@ to certain accounting rules that are not applicable to other industries. .These G  :

accounting rules allow regulated ' companies, in . appropriate circumstances, to establish regulatory assets and liabilities, which defer the current financial a impact of certain costs that are expected to be recovered in future rates. EUA ]

JO believes that its Core Electric operations continue to meet the criteria j established in these accoutiting standards. Effects of legislation and/or regulatory initiatives or EUA's own initiatives such as " Choice and.

Competition" could ultimately cause EUA's Core Electric companies to no longer l follow these accounting rules. In such an event, a non-cash write-off of

! regulatory assets and liabilities could be required at that time, m

In addition, if legislative or regulatory changes and/or competition result in electric rates which do not fully recover the company's costs, a write-down of plant assets could be required pursuant to Financial Accounting i Standard No. 121, " Accounting for the Impairment of Long-Lived Assets and for

~

Long-Lived Assets to be Disposed Of" (FAS 121) issued in March 1995, effective ,

i for fiscal year 1996. j i

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[d (C) Income Taxes:

Components of income tax expense for the years 1995 and 1994 are as follows:

1995 1994 b.I (In Thousands)

Federal:

• Current $ 3,900 $ 3,302 Deferred 4,108 3,973 Investment Tax Credit, Net (628)- (32) 7,380 7,243 State:

Current 958 628 Deferred (695) 893 263 1,521 Charged to Operations 7,643 8,764 Charged to Other Income:

Current 422 572 Deferred (67) (67) '

Total 1,799g3 g,jagg' ,

4 Total income tax expense was different than the amounts computed by .

applying federal income tax statutory rates to book income subject to tax for the following reasons:

(In Thousands) 1995 1994 Federal Income Tax Computed at Statutory Rates $ 9,694 $10,014 .

(Decreases) Increases in Tax from:

Equity Component of AFUDC (151) (60)

Depreciation differences (175) (233)

Amortization and Utilization of ITC (628) (628)

State Taxes, Net of Federal Income

. Tax Benefit 235 1,078 Other (977) (902)

. Total Income Tax Expense g,7 399g g,93 g9

)

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!T (C) Income Taxes - (Continued) b l m The Company adopted FASB statement No. 109, " Accounting for Income Taxes" l $1" (FAS109) effective as of January 1, 1993, which required recognition of i deferred income taxes for temporary differences that are reported in different years for financial teporting and cax purposes using the liability method.

l TM Under the liability method, deferred tax liabilities or assets are computed l' using the tax rates that vill be in effect when temporary differences reverse.

! Generally, for regulated companies, the change in tax rates may not be immediately recognized in operating results because of rate making treatment and provisions in the Tax Reform Act of 1986. At December 31, 1995 and 1994 no valuation allowance was deemed necessary for total deferred tax assets.

Total deferred tax assets and liabilities are comprised as follows:

Deferred Tax Deferred Tax

. Assets Liabilities

($000) ($000) 1995 1994 1995 1994

1. . Plant Related Plant Related Differences $ 9,272 $ 9,735 Differences $123,529 $116,808 Alternative C & LM 221 Minimum Tax 4,378 4,378 YAS 106 350 419 9 Litigation Provisions 795 Pensions 433 178 Pensions 339 466

. Other 292 1,175 Other 613 811 Total $143 3Z5 $lgg2 gl Total $1243g31 $11gg725 As of December 31, 1995 and 1994, the Company had recorded on its Balance Sheet a regulatory liability to ratepayers of approximately $17.4 million and

$19.4 million, respectively. This amount primarily represents excess deferred incomo taxes resulting from the reduction in the federal income tax rate and also includes deferred taxes provided on investment tax credits. Also at December 31, 1995, and 1994 a regulatory asset of approximately $38.2 million and $35.5 million, respectively had been recorded, representing the cumulative amount of federal income taxes on temporary depreciation differences which were previously flowed through to ratepayers.

The Company has approximately $4.4 million, of alternative minimum tax credits which can be utilized to reduce the EUA System's consolidated regular tax liability and have no expiration.

(D) Capital Stock:

On December 1, 1995 Montaup paid Eastern Edison $10,000,000 as a return of capital by the retirement of 100,000 shares of common stock. There were no j changes in the number of shares of common stock outstanding during 1994.

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.h ys (E) Long-Term Debt:

The Company's Debenture Bonds are collateralized by substantially all of I its Utility Plant. In 1995 and 1994 there was no activity related to the issuance or retirement of such securities.

(F) Lines of Credit:

The EUA System companies, which includes the Company, maintains short-term lines of credit with various banks eggregating approximately $150 million. At December 31, 1995, unused short-term lines of credit were approximately $111 million. In accordance with informal agreements with the various banks, commitment fees are required to maintain certain lines of credit.  :

(G) Jointly Owned Yacilities:

At December 31, 1995, in addition to the stock ownership interests discussed in Note A, Summary of Significant Accounting Policies - Jointly Owned Companies, the Company had direct ownership interests in the following electric generating facilities (dollars in thousands):

Accumulated Provision For Net Construc- .

Utility Depreciation Utility tion Percent Plant in and Plant in Work in Owned Service Amortization Service Progress Montaup:

Canal Unit 2 50.00% $ 71,715 $42,657 $ 29,058 $2,085 Lyman Unit 4 1.96% 4,050 2,020 2,030 Seabrook Unit 1 2.90% 194,735 23,993 170,742 454 Millstone Unit 3 4.01% 178,231 40,482 137,749 42 The foregoing amounts represent the Company's interest in each facility, including nuclear fuel where appropriate, and are included on the V like-captioned lines on the Balance Sheet. At December 31, 1995, the Company's total net investment in nuclear fuel of the Seabrook and Millstone Units amounted to $3.0 million and $2.2 million, respectively. The Company's share of related operating and maintenance expenses with respect to units reflected in the table above are included in the corresponding operating expenses.

(H) Fair Value of Financial Instruments:

Cash and Temporary Cash Investments: The carrying amount approximates fair value-because of the short-term maturity of those instruments.

Long Term Debt: Eastern Edison holds all of the Company's Debenture Bonds. The Company finds it '.aappropriate to determine the securities, fair market value. Therefore, the carrying amounts approximates its fair value.

123G J

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4 Q (I) Commitments and Contingencies:

q Nuclear Power Issues: The owners (or lead participants) of the nuclear

,,M units in which Montaup has an interest have made, or expect to make, various arrangements for the acquisition of uranium concentrate, the conversion, enrichment, fabrication and utilization of nuclear fuel and the disposition of Q.j that fuel after use. The owners (or lead particip^ ants) of United States

'. nuclear units have entered into contracts with the DOE for disposal of spent nuclear fuel in accordance with the NWPA. The NWPA requires (subject to  !

I r., various contingencies) that the federal government design, license, construct and operate a permanent repository for high level radioactive vastes and spent )

nuclear fuel and establish prescribed fees for the disposal of such vastes and fuel. The NWPA specifies that the DOE provide for the disposal of such vaste i and spent nuclear fuel starting in 1998. Objec.tives on environmental and other grounds have been asserted against proposals for' storage as well as disposal of spent nuclear fuel. The DOE now estimates that a permanent disposal site for spent fuel will not be ready to accept fuel for storage or disposal until as

+

late as the year 2010. Montaup owns a 4.01% interest in Millstone Unit 3 and a ,

, 2.9% interest in seabrook Unit 1. Northeast Utilities, the operator of the I units, indicates that Millstone Unit 3 has sufficient on-site storage

~'

facilities which with rack additions can accommodate its spent fuel for the projected life of the unit. At the Seabrook Project, there is on-site storage capacity which, with rack additions, will be sufficient to at least the year 2011.

The Energy Policy Act requires that a fund be created for the decommissioning and decontamination of the DOE uranium enrichment facilities.

The fund will be financed in part by special assessments on nuclear power plants in which Montaup has an interest. These assessments are calculated based on the utilities' prior use of the government facilities and have been levied by the DOE, starting in Septembet 1993, and will continue over 15 years. This cost is passed on to the joint owners or power buyers as an additional fuel charge on a monthly basis ard is currently being recovered by Montaup through rates.

Also, Montaup is recovering through rates its share of estimated decommissioning costs for Millstone Unit 3 and Seabrook Unit 1. Montaup's share of the current estimate of total costs to decommission Millstone Unit 3 is $19.2 million in 1995 dollars, and Seabrook Unit 1 is $12.5 million in 1995 dollars. These figures are based on studies performed for the lead owners of

the units. Montaup also pays into decommissioning reserves pursuant to contractual arrangements with other nuclear generating facilities in which it has.an equity ownership interest or life of the unit entitlement. Such expenses are currently recoverable through rates.

In December 1992, Montaup commenced a declaratory judgment action in which it sought to have the Massachusetts Superior Court determine its rights under the Power Purchase Agreement between it and Aquidneck Power Limited Partnership (Aquidneck).

In April 1995, Montaup filed a motion for summary judgement, and in June 1995, the court granted Montaup's motion. In July, Aquidneck filed for appeal of the court's decision.

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(1) Commitments and Contingencies - (Continued)

Montaup, EUA and EUA ' Service intend to vigorously contest the appeal and continue to believe that Aquidneck's claims have no basis in law.

Pensions: The Company participates with the other EUA System companies in .

non-contr,1butory defined benefit pension plans covering substantially .all . of their ' employees. Retirement Plan benefits are based on years of service and i average compensation over the four years prior to retirement. It is the EUA System's policy to fund. the Retirement Plan on a current basis . in amounts determined to meet the funding standards. established by the Employee Retirement

j. Income Security Act of 1974. Net pension (income) expense for the Retirement Plans including amounts related to the'1995 voluntary retirement incentive, was

$294,299 in 1995, $130,146 in 1994 and included the following components:

1995 1994 Service. cost - benefits earned during the period $ 453,867' $ 535,917

-Interest cost on projected benefit obligation- 1,765,645 1,603,149 Actual loss (return) on assets (6,693,096) 276,040 Net amortization and deferrals 4,485,290 -(2,284,960) .

Net periodic pension expense'(income) 11,706 130,146 Voluntary retirement incentive 282,593 Total periodic pension (income) . expense ),J9M,21 f,,_1,30,146 Assumptions used to determine pension cost:

1995 1994 Discount Rate 8.25% 7.25%

Compensation Increase Rate 4.75% 4.75%

Long-Tern Return on Assets 9.50% 9.50%

The discount rate and compensation increase rate used to determine pension costs were changed effective January 1, 1996 to 7.25% and 4.25, respectively.

The funded status of the Retirement Plan cannot be presented separately for i Montaup as they participate in the Retirement Plan with other subsidiaries of :i EUA. ,

'The one-time voluntary retirement incentive also resulted in approximately

$348,000.of non-qualified pension benefits which were expensed in 1995. .At

' December 31, 1995, approximately $223,000 is included in other liabilities for these unfunded benefits.

l l 'j l

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P (I) Commitments and Contingencies - (Continued)

.-. EUA also maintains non-qualified supplemental retirement plans for certain i^ officers of the EUA System (Supplemental Plans) . Benefits provided under the Supplemental Plans are based primarily on compensation at retirement date. EUA maintains life insurance on the participants of the Supplemental Plans to fund in

%) whole, or in part, its future liabilities under the Supplemental Plans. For the

, 3) years ending December 31, 1995 and 1994 expenses related to the supplemental plan were approximately $254,842 and $78,191, respectively.

Post-Retirement Benefits: Retired employees are entitled to participate in health care and life insurance benefit plans. Health care benefits are subject to deductibles and other limitations. Health care and life insurance -

3M benefits are partially funded by EUA System companies for all qualified employees.

l r] The Company adopted FAS 106, " Employers' Accounting for Post-Retirement  !

Benefits Other Than Pensions," as of January 1, 1993. This standard

.}:}

establishes accounting and reporting standards for such post-retirement benefits as health care and life insurance. Under FAS 106 the present value of l future benefits is recorded as a periodic expense over employee service

}C' periods through the date they become fully eligible for benefits. With respect to periods prior to adopting PAS 106, the Company elected to recognize )

accrued costs (the Transition Obligation) over a period of 20 years as A permitted by PAS 106. The resultant annual expense, including amortization of I

the Transition Obligation and net of amounts capitalized and deferred, was

. approximately $1.7 million in 1995 and $1.3 million in 1994. The total cost of  !

Post-Retirement Benefits other than Pensions for 1995 and 1994 includes the l I

following components (in thousands)*

- 1995 1994 Service cost $ 168 $ 287 Interest cost 885 1,000 Actual return on plan assets (120) (22)

Amortization of transition obligation 574 599 l Net other amortization & deferrals (203) (10)  !

Net periodic post - retirement benefit costs 1,304 1,854 Voluntary retirement incentive 195 Total Post-Retirement Benefit Cost $1,499 $1,854  ;

6 I

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.w (1) Commitments and Contingencies - (Continued)

b In April' 1992, (NESCAUM), an environmental advisory group for eight

• d Northeast states including Massachusetts. and Rhode Island, . issued recommendations for oxides of nitrogen controls for existing . utility . boilers p required to meet the ozone _ non-attainment - requirements - of the Clean ' Air ' Act St

-Amendments. The NESCAUM recommendations are more restrictive -than EPA's [

requirements. The DEP has amended its regulations to require that Reasonably . ^1 Available Control Technology (RACT) be implemented at all stationary sources .j potentially emitting _50 ' tons per year or more of ' oxides of nitrogen. Rhode 'l Island has also issued similar regulations requiring that RACT be ' implemented -

at all stationary sources potentially emitting 50 tons or more per year. of - .;

nitrogen oxide. Montaup has initiated compliance through, among other things. P selective noncatalytic reduction processes.

A number of scientific studies in the past several years have' examined' the I possibility of health effects from electric and magnetic fields (ENF) that:are

• found wherever there .is electricity. While some of the studies have indicated some association between exposure to EMF and health effects, many_ studies have m indicated no - direct . association. The research to date has not conclusively .'

established a direct causal relationship - between . EMF exposure and human t health. Additicnal studies, which are intended to provide a better g understanding of ENF, are continuing. .

Some states have enacted regulations to - limit the strength of EMF at the edge of transmission line rights-of-way. Rhode Island has ' enacted a statute  !

which authorizes and directs the Energy Facility Siting Board to establish .

rules and/or' regulations governing ' construction . of high voltage transmission-lines of. 69 KV or more.- There is a-- bill pending in the Massachusetts. ,

legislature that would authorize the MDPU to examine the potential health

• effects of ' EMF. Management cannot predict the impact, if any, which '

legislation or other developments concerning EMF may have on the Company.

TS

,n Guarantee of Financial Obligations: The Company is a 3.27% equity 'i participant in two companies which own and operate transmission facilities _;

interconnecting New England and the Hydro Quebec system in Canada. Montaup has guaranteed approximately $5.2 million - of the outstanding debt of these two companies. In addition, Montaup has a minimum rental commitment which totals approximately $13.5 million under a noncancellable transmission facilities m support agreement for years subsequent to 1995. '

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. NNaE kN c bornpany *! k kk$k[YohinalJAResubission kW 0$131796 Dec. 31, 1995 '

j

SUMMARY

OF UTILITY PLANT AND ACCLMJLATED PROVIS!Oh5 i FOR DEPRECIATION. AMORTIZATION AND DEPLETION i

! Cas Other(Specify) Other(Specify) Other(Speci f y) Conunon Line

] No. l j (d) (e) (g)

(f) (h) 3 1 4

1 2

j. 3 4

i 5

6 7

) 8 9

, 10

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1 11 1

12 13 14

15 16 17

{ . 18 j

19 20 21 22

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. 28 29 f

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32 33 i

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' FERC FORM NO.1 (ED.12-89) Page 201 4

.l C fe c onpany $ Oh!'i bk

• Dec. 31,1995 m.

($$k1AResubmiatssion 0$131IO6 NUCLEAR FUEL MATERIALS (Accounts 120.1 through 120.6 and 157)

1. Report below the costs incurred 2. If the nuclear fuel stock is ob- and quantity on hand, and the costs incurred under such teasing arrange-for nuclear fuel materiets in process of tained under leasing arrangements, at-f brication, on hand, in reactor, and in tach a statement showing the amount of ments.

cooling, owned by the respondent. nuclear fuel leased, the quantity useo Line Description of itee Balance No. Beginning of Year Additions (a) (b) (c)

YoNSEson kbSc[m $$ k FN $'(120.1) _

438,728 2,104,246 2 Fabrication 3 Nuclear Materiets Attowance for funds used during Construction 29,911 103,411 4

5 (other Overhead ';onstruction Costs) 6 SUST0TAL (Enter Total of lines 2 thru 5) S468,639 7 Nuclear Fuel Materiets and Assemblies 163,476 3,504,406 8 In Stock (120.2) 14,406,370 5,460,513 9 In Reactor (120.3) 10 SUST0TAL (Enter Total of lines 8 thru 9) 514,569,846 0 8,657,912 11 Spent Nuclear fuet (120.4) ,

12 Nuclear Fuel Under Capital Leases (120.6) -I hu!Iear E "A!s E6L !s I N h}' 9,156,396

$5,882,089 i N 5" k8fi$ M Th l N ((ne lSh 15 Eg g g j g n{g g age Value of Nuclear 16 E g g ny g ag Value of Nuclear Ma kNs$ !at e! sin _

18 Nuclear Materials held for Sale (157) 19 Uranius 20 Plutoniun 21 Other r  ! oh' fine! 9 ,and'$*

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4 FER: FORM NO.1 (ED. 12-89) Page 202

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Dec. 31,1995 l

l . . ,

j l NUCLEAR FUEL MATERIALS (Accounts 120.1 through 120.6 and 157)(continued)

! l l l l

Changes Durir.g the Year l Amortization Other Reductions (Explain in a footnote) End of Year No.

(d) (e) (f) l 2,512,545 30,429 2 l l 0 3 l 139,759 (6,437) 4 j l 0 5 523,992 6 l.a. l 7  ;

i-. l 3,671,619 (3,737) 8 8,682,158 11,184,725 9 l l

! 511,180,988 10 l 8,657,912 0 11 l 0 12 ,

i 13 l (3,396,351)l 6,534,397 6,018,350

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i FERC FORM NO.1 (ED.12-89) Page 203 3

N aup b Ei M o g any N Oki k2lk)AResubnatssion UD3b'6Y Dec. 31,1995 ELECTRIC PLANT IN SERVICE (Accounta 101,102,103,and 106)

1. Report below the original cost of electric plant in serv- counts, on an estimated basis if necessary, and inclucle the ics according to the prescribed accounts. entries in colum (c). Also to be included in colmn (c) are

2. In addition to Account 101, Electric Plant in Service entries for reversals of tentative distributions of prior

( Clissified ), this page and the next include Account 102, year reported in cottavi (b). Likewise, if the respondent has Elcriric Plant Purchased or Sold; Accomt 103, Experimental a significant amount of plant retirements which have not Electric Plant unclassified; and Account 106, Completed been classified to primary accounts at the end of the year, +

construction Not Classified-Electric. Include in colmn (d) a tentative distribution of such re-

3. Include in cotum (c) or (d), as appropriate, corrections tirements, on an estimated basis, with appropriate contra of additions and retirements for the current or preceding year. entry to the account for a'ec mulated depreciation provision. -

4. Enclose in parentheses credit adjustments of plant include also in colmn(d) reversals of tentative distributions accounts to indicate the negative effect of such accounts. of prior year of metassified retirements. Show in a

5. Classify Account 106 according to prescribed ac- footnote the account distributions of these tentative classifications in col m ns (c) and (d), including the N Ac t Begi fNear Addgon 1 1. INTANGIBLE PLANT 2 (301) organization 0 3 (302) Franchises and Consents 272,509 4 (303) Miscellaneous Intangible Ptant 0 5 TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4) 5272,509 6 2. PRODUCTION PLANT 7 A. Steam Production Plant 8 (310) Land and Land Rights 657,787 0 9 (311) Structures and Inprovements 22,029,605 928,996 10 (312) Boiler Plant Equipment 55,474,318 5,920,438 11 (313) Engines and Engine-Oriven Generators 0 0 12 (314) Turbogenerator units s7,022,028 3,626,161 13 (315) Accessory Electric Equipment 7,580,241 105,838 14 (316) Misc. Power Plant Equipment 1,401,129 84,327 15 TOTAL steam Production Plant (Enter Total of 1ines 8 thru 14) %114,165,108 510,665,760 16 B. Nuclear Production Plant f i 17 (320) Land and Land Rights 144,109 0 j 15 (321) Structures and Inprovements 111,046,305 409.'s57 19 (322) Reactor Plant Equipment 172,419,296 413,998 20 (323) Turbo generator Units 34,934,195 483,959 21 (324) Accessory Electric Equipment 36,959,915 343,384 22 (325) Misc. Power Plant Equipment 10,708,084 198,060 23 TOTAL Nuclear Production Plant (Enter Total of lines 17 thru 22) 5366,211,904 51,848,458 25 C. Hydraulic Production Plant 25 (330) Land and Land Rights 0 0 26 (331) Structures and Inprovements 0 0 27 (332) Reservoirs, Dams, and Waterways 0 0 28 (333) Water Wheels, Turbines, and Generators 0 0 29 (334) Accessory Electric Equipment 0 0 30 (335) Misc. Power Plant Egalpment 0 0 31 (336) Roads, Railroads, and Bridges 0 0 32 TOTAL Hydraulic Production Plant (Enter Total of lines 25 thru 31) 0 0 33 D. Other Production Plant 34 (340) Land and Land Rights 0 0 35 (341) Structures and Inprovements 21,465 0 36 (342) Fuel Holders, Products, and Accessories 224,156 0 37 (343) Prime Movers 2,056,653 0 38 (344) Generators 1,974,029 0 39 (345) Accessory Electric Equipment 286,401 0 FERC FORM NO.1 (REV.12 95) Page 204

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a N$Nionpany *IYO inst k2) k A Resubmission k

DN31796 W Dec. 31,1995 1 1

ELECTRIC PLANT IN SERVICE (Accounts 101,102,103,and 106)(Continued)

I reversals of the prior years tentative account distributions of mn (f) only the offset to the debits or credits distributed in these amounts. Careful observance of the above instructions coltam (f) to primary account classifications.

erd the texts of Accomts 101 and 106 will avoid serious omis- 7. For Account 399, state the nature and use of plant included sions of the reported amo m t of respondent's plant actually in this account and if substantial in amount siinit a supple-

) in service at end of year. mentary statement showing subaceount classification of such

6. Show in col m n (f) reclassifications or transfers within plant conforming to the requirements of these pages. j i utility plant accounts. Include also in column (f) the additions 8. For each amount conprising the reported balance and or reductions of primary account classifications arising from changes in Accomt 102, state the property purchased or sold, distribution of amomts initially recorded in Account 102. In name of vendor or purchaser, and date of transaction. If pro-

] chowing the clearance of Account 102, include in col m n (e) posed jour' t entries have been filed with the Commission I

th2 amounts with respect to acetsnulated provision for as required by the Uniform System of Accounts, give also depreciation, acquisition adjustments, etc., and show in cot- date of such filing. l Retignts Adjugnts Tra ers b

• Y!ar N O

] O (301) 2 0 272,509 (302) 3 i 0

0 (303) 4 0 $272,509 5 s .

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O' 657,757 (310)

I 7,259 22,951,342 (311) 9 543,676 (32,539) 60,818,541 (312) 10 j 0 0 (313) 11

~

797,279 29,850,910 (314) 12

37,481 7,648,598 "15) 13

! 2,500 1,482,956 (316) 14 l _ $1,388,195 ($32,539) $123,410,134 15 16 l 0 144,109 (320) 17 172,954 111,282,408 (321) 18 I

194,519 172,638,775 (322) 19

{ 1,214,101 34,204,053 (323) 20 i 4,052 37,299,247 (324) 21 l 33,371 10,872,773 (325) 22 1 51,618,997 $366,441,365 23 I

Y O

l' O (330) 25 j 0 0 (331) 26 j 0 0 (332) 27 0 0 (333) 28 1 0 0 (334) 29

O 0 (335) 30

O O (336) 31

] O O 32

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j 0 0 (340) 34 i 0 21,465 (341) 35

! 0 224,156 (342) 36 4

0 2,056,653 (343) 37

O 1,974,029 (344) 38 1 0 286,401 (345) 39 j FERC FORM NO.1 (EO. 12 88) Page 205 i

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YAR pal ission Ob 3 796 [

Dec. 31,1995 ELECTRIC PLANT IN SERVICE (Accounts 101,102,103,and 106)(Continued) oNYear Acgt Beg Add ons 40 (346) Misc. Power Plant Equipment $9,384 41 TOTAL Other Prod. Plant (Enter Total of lines 34 thru 40) 54,572,088 0 Il 42 G?AL Prod. Plant (Enter Total of lines 15, 23, 32, and 41) $484,949,100 512.514,218 43 3. TRANSMISSION PLANT _

t.4 (350) Lord and Land Rights 2,909,250 (5 (352) structures and Imeovements 1,337,485 46 (353) Station Equipment 30,863,106 375,471 47 (354) Towers and Fixtures 6,158,060 0 48 (355) Poles and Fixtures 2,210,601 128,812 j 49 (356) Overhead conductors and Devices 4,322,003 130,846 50 (357) undergromd 0.niutt 0 ) j 51 (358) underground conductors and Devices 0 0 52 (359) Roads and Trails 1,025,650 4,149 l 53 TOTAL Transmission Plant (Enter Total of lines 44 thru 52) $48,826,155 5639,278 .

54 4. DISTRIBUTION PLANT 55 (360) Lord and Land Rights 0 0 56 (361) structures and I mrovements 0 0 57 (362) station Equipaent 0 0 58 (363) storage Battery Equipment 0 0 59 (364) Poles, Towers, and Fixtures 0 0 60 (365) overhead conductors and Devices 0 0 61 (366) Undereround Condutt 0 0 62 (367) underground conductors and Devices 0 0 63 (368) Line Transfomers 0 0 64 (369) Services 0 0 65 (370) Meters 0 0 66 (371) Instattattons on customer Premises 0 0 67 (372) Leased Property on Customer Premises 0 0 ,,

68 (373) Street Lighting and signat Systems 0 0 69 TOTAL Distribution Plant (Enter Total of lines 55 thru 68) 0 0 '

70 5. GENERAL PLANT 71 (389) Land and Land Rights 0 0 72 (390) structures and Igrovements 2,506,142 571,465 q 73 (391) Office Furniture and Equipment 1,916,154 25,502

]

74 (392) Transportation Equipnent 69,716 0 i

' (393) Stores Equipment 104,104 0 .I

~71 (394) Tools, shop and Garage Equipment 746,427 40,094 77 (395) Laboratory Equipment 251,357 0  ;

78 (396) Power Operated Equipment 102 0 l 79 (397) Commnication Equipment 504,769 0 j B0 (398) Misee1(aneous Equipment 118,002 16,866 81 SUBTOTAL (Enter Total of lines 71 thru 80) 46,216,773 5653,927 82 (399) Other Tangible Property 0 83 TDTAL General Plant (Enter Total of lines 81 and 82) $6,216,773 $653,927 84 TOTAL (Accomts 101 and 106) (lines 5,15,23,32,41,53,69,83) $540,264,537 513,807,423 .I 85 (102) Electric Plant Purchased (See Instr. 8) 0 86 (Less) (102) Electric Plant Sold (See Instr. 8) 0 87 (103) Experimental Plant Unclassifled 0 88 TOTAL Electric Plant in Service (Enter Total of lines 84 thru 87) $540,264,537 $13,807,423 FERC FORM NO.1 (ED. 12-94) Page 206

• : 1 a sr honpany A inal

, f2 k3ARst8nission 0$f3k/Mh Dec. 31, 1995 ELECTRIC PLANT IN SERVICE (Accounts 101.102,103,and 106)(Continued) (

Ret ts Adjugnts fra ers En$ eN k' t .. O s9,384 (346) 40 0 0 3 $4,572,088 41 l 53,007,192 ($32,539) $494,423,587 42 l 43

., 0 2,909,250 (350) 44 0

1,337,485 (352) 45 1,189,143 30,049,434 (353) 46 157 6,157,903 (354) 47 3,446 2,335,967 (355) 48 14,889 4,437,960 (356) 49 0

0 (357) 50 0

0 (358) 51 1,029,799 (359) 52

$1,207,635 548,257,798 53 0

0 (360) 0 0 (361) 56 0

0 (362) 57 0

0 (363) 58 0

_ 0 (364) 59 0

0 (365) 60 0

0 (366) 61 0 0 (367) 62 0

0 (3o8) 63 0 0 (369) 64 0 0 (370) 65 0 0 (371) 66 0

0 (372) 67 0 0 ( 3 73 ) 68 l 0 0 69 70 0 0 (389) 71 6,237 3,071,370 (390) 72 6,789 1,934,867 (391) 73 0 69,716 (392) 74 0 104,104 (393) 75 0 786,521 76 (394) 0 251,357 77 (395) 0 78 102 (396) 504,769 (397) 79 3,047 131,821 (398) 80 516,073 $6,854,627 81 0 (399) 82

$16,073 56,854,627 83 54,230,900 (S32,539) $549,808,521 84 0 (102) 85 0 86 0 (103) 87 54,230,900 (s32,539) 5549,808,521 88 FERC FORM NO.1 (ED.12-88) Page 207 NEXT PAGE IS 214

O Yssion 3 3, ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)

1. Report separately each property held for future use at future use, give in colt.nn (a), in addition to other required end cf the year having an original cost of $250,000 or more. Information, the date that utility use of such property was Group other items of property held for future use. discontinued, and the date the original cost was transferred

2. For property having an original cost of 5 250,000 or to Account 105.

more previously used in utility operations, now held for Ljne

o. ** 'h [ f y uni #  !!

Uti U [It' gcount g erv ce g 1 Land and Rights: .

M 2 Land in somerset, Massachusetts 11/30/73 $604,405 3

4 5 -

6 7

8 9

10 11 12 13 14 15 n:-

17 18 l 19 20 21 Other Property: M 22 Unit #5 in semerset, Mass. 08/09/94 5,413,544 l 23 (cold storage) 24 I 25 *The conpany will state its intent in its 26 next regional IRP filing, scheduled for 27 June 1,1996 whether somerset Unit #5 will 28 be retired, reactivated or continue to 29 remain in cold storage.

30 ER94 1062-000 and ER94-68 000 (M14) 31 -'

32 33 34 35 36 .-l 37 I 38 39 40 41 42 43 64 45 46  ;

67 t0TAL

$6,017,949 FERC FORM NO.1 (ED.12-89) Page 214 Next Page is 216

m N.)

.' I 3

• m N a'up heEIrI bonpany k(2j k J A Resu* Y kn ohT*l I ssion k$n/3 03 I%@' Dec. 31, 1995 CONSTRUCTION WORK IN PROGRESS

• ELECTRIC (Account 107)

1. Report below descriptions and belances at end of year Development, and Demonstration ( see Account 107 of the

-ra cf projects in process of construction (107). Uniform System of Accounts).

. 2. Show items relating to "research, development, and 3. Minor projects (5% of the Balance End of the Year for-demonstration" projects test, under a caption Research, Account 107 or $100,000, whichever is less) may be gr- W .

~fi gne Descriptim of Project in N he 1 le 034 Misc Projects Canal $1,994,169

, 2 la 055 Misc Projects SEABRo0K 169,624 3 la 707 Controt/Drawine seebrook 192,450 4 MinorProjects 475,027 5

6 7

8 9

10 11 12 13 14 15 16 17 18 19 20 21 22

.. 23

\ 24 25 26 27 l "i 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 TOTAL S2,831,270 FERC FORM NO.1 (ED. 12-87) Page 216

• 4 "*- IlhT1 hon iBA"m"  ;": "'."T,;' W CONSTRUCTION OVERHEADS-ELECTRIC

,g 3ea pa's'gegryo,pngh.vgypamaiw j ,4 ygg g o angIr:nipreyygrggsew:siponpmo:a, etc. er c to construct ..

2. On page 218 furnish Information concerning construction 4. Enter on this page engineering, supervision, adminis-overheads. trative, and attowance for funds used during construction,

3. A respondent should not report "none" to the page if no etc., which are first assigned to a blanket work order and ,'

overhead apportionments are made, but rather should exp- then prsrated to construction jobs.

Lg Description of Overhead 1 AFLDC 8848,394 2 A&G 122,998 3 Payroll Taxet 20,968 ,

4 Eup Pensions,senefits and Workmans Comp 81,272 5

6 7

8 9

10 11 12 13 14 15 16 17 18 19 20 21 22 23 l 23 ..I 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 ,

60 41 42 43 44 65 46 TOTAL $1,073,632 FERC FORM No.1 (ED. 12 89) Page 217

. ~ . . . . . . . -

in

• G:

• 8D ePort a $ N "konpany O {h3f96g k A Res Oat ssion Dec. 31,1995 GENERAL DESCRIPTION OF CONSTRUCTION OVERHEAD PROCEDURE

1. For each construction overhead explain: (a) the nature 2. Show below the conputation of allowance for funds and extent of work, etc. the overhead charges are Intended used during construction rates, in accordance with the

r. . ts cover, (b) the general procedure for determining the provisions of Electric Plant Instructions 3(17) of the I amount capitalized, (c) the method of distribution to construc- U.S. of A. l tion jobs, (d) whether different rates are applied to different 3. Where a net of-tax rate for borrowed funds is used, l types of construction,(e) basis of differentiation in rates for show the appropriate tax effect adjustment to the conputa- l

_7, different types of construction, and (f) whether the overhead tions below in a manner that clearly indicates the amount

.. is directly or Indirectly assigned. of reduction in the gross rate for tax effects.

1. (a) Portions of employee pension & benefit costs, payrott related taxes and G&A costs are components of

'~, , ,

construction overheads. Penslon & benefit costs and payrott taxes are capitalized because of direct relationship to construction payrott costs. Certain GLA costs are capitalized to cover the administrative costs of carrying out a construction program.

" (b) Pension costs, employee benefits and payrott related taxes are allocated on the basis of construction i tabor total to total Labor costs. A&G costs are allocated based on the time expended to supervise i and administer the construction activity.

(c) Attocated to construction jobs on the basis of direct construction costs excluding work orders or job ,

tickets for transformers, meters, transportation equipment & other generat plant equipment. l (d) No variation in percentage applied to different types or applicable construction. l (e) See (d) above.

', (f) overheads are indirectly assigned.

4 l

COMPUTATION OF ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION RATES i For Line 1(5), column (d) below, enter the rate granted in the tant rate proceeding. If such is not avaltable, use the average rate earned cbring the preceding three years.

1. Cosponents of Fornuta (Derived from actual book balances and actual cost rates):

gtgilzation I gostRate Lg Tge gt gercent) ergtage (1) Average short Term Debt S 52,102,923 (2) Short Term Interest s 7.20%

(3) Long-Term Debt D S166,779,360 46.75% d 8.59%

(4) Preferred Stock P 518,046,885 5.06% lp 7.00%

(5) Coninen Equity C $171,931,319 48.19% lc 11.10%

j (6) Total Capitalization $356,757,564 100% l M

• N og N k ance W $12,033,000 D

2. Gross Rate for Borrowed Funds g, D+P+b)(1,,SW} 4 $7Z

! W

+

3. Rate for Other Funds p 4.68%

I 1 - 3 I p(pp4) + c(ppg) 1

4. Walghted Average Rate Actually Used for the Tears

a. Rate for Borrowed Funds - 4.47%

b. Rate for Other Funds - 4.82%

i FERC FORM NO.1 (ED. 12-88) Page 218

.- . - ._ - . . ._~ - . - - -

I

.. l

- i NoNn aup bE$bonpany NO ission d*k]AResbinal c2I k

$3131796kN Dec. 31, 1995 -l ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)

1. Explain in a footnote any linportant adjustments If the respondent has a significant amount of plant retired during year, at year end which has not been recorded and / or classified i

2. Explain in a footnote any difference between the to the various reserse functional classifications, make amount for boek cost of plant retired, line 11, colinn preliminary closing entries to tentatively functionalize ,'

(c), and that reported for electric plant in service, the book cost of the plant retired. In addition, include all pages 204-207, coltann (d), excluding retirements of non- costs lv!uded in retirement work in progress at year end in depreciable property. the appropriate functional classifications.

3. The oiwvisions of Account 108 in the Uniform Sys- 4. Show separately interest credits under a sinking fund tan of Accounts . require that retirements of depreciable or siellar method of depreciation accounting.

plant be recorded when such plant is removed from service.

Section A. Balances and Changes During Year

{ne lg ( e) *#N e h YU!e the o s 1 Balance Beginning of Year $147,965,036l S147,965,036l l 2

D g g t g Provisions for Year, 3 (403) Depreciation Expense 4 (413) Exp. of Elec. Plt. Leas.to Others 15,360,233l l

'5,360,233l 1 ' lME '

l 5 Trar.sportation Expenses-Clearing l l 6 Other Clearing Accotrits 0l l l 7 Other Accou, .s (Specify): 0l l l 8

l l l (En$ TN{of({$i tN8) S15,360,233l $15,360,233l 10 Net Charges for Plant Retired:

11 Book Cost of Plant Retired (4,230,900) (4,230,900) 12 Cost of Removat (1,372,570) (1,372,570) 13 Salvage (Credit) 78,710 78,710

( N $ ak Y li ks U 'E r6'I3) (s5,524,760) (ss,524,760) 15 Other Debit or Cr. Items (Describe):

16 o N In! 1 9'T[,Y'and$b $157,800,509 $157,800,509 Section B. Balances at End of Year According to Functional Classifications 18 Steam Froduction 68,576,781 68,576,781 19 Nuclear Production 63,424,346 63,424,346 20 Hydraulic Production-Conventional 21 Hydraulic Production Pumped Storage 0 22 Other Production 3,190,630 3,190,630 23 Transmission 20,973,033 20,973,033 24 Distribution 25 General 1,635,719 1,635,719 ..

26 TOTAL (Enter Total of lines 18 thru 25) $157,800,509 $157,800,509 l

l FERC FORM NO (ED. 12-88) Page 219 Next Page is 221

i_.s . ~ ,

.a. ~

. .y cj g*j l{#gQ skg]pgtgt,i!ston DatsgfRgrt Y e r sf Report

• ~'

L A Res b $$f3d96 Dec. 31, 1995 NONUTILITY PROPERTY (Account 121)

1. Give a brief description and state the location of non- 4. List separately all property previously devoted to utility peoperty included in Account 121. public service and give date of transfer to Accomt 121,

2. Designate with a douote asterisk any property which is Nonutility Prg erty.

1:ssed to another conpany. State name of lessee and whether 5. Minor items ( 5% of the Balance at the End of the isssee is an associated conpany. Year), for Account 121 or $100,000, whichever is less)

Lt 3. Furnish particulars ( details ) concerning sales, pur- may be grouped by (1) previously ievoted to public ser-chases, or transfers of Nonutility Property charing the year. vice(Line 44), or(2) other nonutility property (tine 45).

Lg Descriptg and Location '**"o! '8'""

Era !f*,'et!

g *!*

o 1 Land on segregansett 2 River Dighton, Mass. n 3 Approx 3.34 Acres 915 915

~

4 Land On Arnolds Pt 0 5 Portsmouth,R.I. 0 6 Apprsx 32 Acres 2,608,699 2,608,699

7 4

a l

9

] 10 j , 11 l j 12 e 13

^

0 14 15 16 I 17 16 19 4 20 l 21 22 1

1 23 25

, 25 j d

26 l 27 j

- 28 l 29 30 31

~.,

32 33 34 35 36 37 38 39 40 41 42 43 44 Minor Item Previously Devoted to P2Lic Service g 45 Minor Items Other Nonutility Property

'- 46 TOTAL S2.609,614 52,609,614 0

FERC FORM No.1 (ED.12-95) Page 221 Next Page is 224 e

i^.

c-

.)

MEaup $Nbanpany s Qjk((P{((0N*loat3AResubssion yate g g ear f ep rt

• k2 OD31796 Dec. 31,1995 '

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)

1. Report below frwestments in Accounts 123.1, Invest- (b) Investment Advances - Report separately the i ments in Subsidiary Conpanies, amounts of loans or investment advances which are subject

2. Provide a subheading for each company and list to repayment, but which are not subject to current settlement.

thereunder the information catted for below. 5 4 total by With respect to each advance show whether the advance is ccupany and give a total in columns (e),(f),(g) and (h), a note or open account. List each note giving date of issuance, (a) Investment in Securities - List and Jescribe each maturity date, and specifying whether note is a renewal.

security owned. For bonds give also principal amount, date 3. Report separately the equity in undistributed subsidiary of issue, maturity and interest rate , earnings since acquisition. The total in column (e) should equal the amount entered for Accomt 418.1.

Lg DescriptigofInvestment g nysgtat t Yankee Atomic Er.ergy Company 51,169,646 2 Capital Stock 02/02/62 3

4 Maine Yankee Atomic Power (1) 2,721,330 5 Capital stock 03/18/69 6 Capital stock 03/19/69 7

8 Connecticut Yankee Atomic Power 4,566,962 9 Capital stock 11/15/63 10 Capital stock (2) g 11 Capital Stock (3)

S2 Capital Stock (4) 13 Capital Stock (5) '

14 Promissary Note 12/30/80 15 16 Vermont Yankee Nuclear Power 1,361,608 17 Capital Stock 02/07/68 ,

18 Capital stock 02/07/68 ,

19 Capital Stock 03/03/68 20 Capital Stock 05/06/68 21 Capital Stock 02/25/69 22 (6) 23 20 NE Hydro Trans Elec to 2,281,635 25 02/28/89 26 NE Hydro Trans Corp 1,387,100 27 02/28/89 '

28 29 30 31 32 33 34 35 36 37 38 39 40 41

• 42 lTOTALCostofAccount123.15 l TOTAL S13,488,281 .

FERC FORM NO.1 (ED.12-89) Page 224

C

q. '

honpany 0 lost Dec. 31,1995 e s2) k J A Resubmtssion bf31796 INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)(continued)

4. For any securities, notes, or accounts that were pledged, 7. In column (h) report for each investment disposed designate such securities, notes, or accomts in a footnote, of during the year, the gain or loss represented by and state the name of pledgee and purpose of the pledge. the difference between cost of the investment ( or the

5. If Commission approvst was required for any advance other amount at which carried in the books of accomt made or security accpired, designate such fact in a footnote if difference from cost) and the setting price thereof,

• r and give name of Consnission, date of authorization, and case not including interest adjustment includible in cot-j-l or docket mmber, umn (f).

6. Report cotum (f) Interest and dividend revenues from 8. soport on Line 42, cotum (a) the total cost of Investments, including such revenues from securities disposed Accomt 123.1.

tf during the year.

Amount of Gaigor oss g Ig in Yn$ eN Ear ng olYear N n! sp

($29,535) S82,836 S1,057,275 1 2

3 2,947,550 4 293,220 67,000 5

6 7

693,000 4,554,203 8 680,241 9

10 11 12 13 14 15 1,353,214 16 174,*495 182,789 17 18 19

]

20  !

21 22 23 2,005,875 24 312,894 588,654 ,

25 l 1

1,304,318 40,000 26 215,142 297,924 27 i 28 29  !

V 20 l 31 I 32 l 33  !

34 35 36 37 ;

38 39 40 '

41 42

.; 513,222,435 $40,000 S1,912,203

'4 S1,646,357 Next Papa is 227 l Page 225 FERC FORM NO.1 (ED. 12-89)

.J

. . _ - . . = .- -_ . _ ~ ~ . . . . ~. . . - . - .- _..-.-. - . . - ..- . . . -.. .. .. _

- l

.. j

< Paga,224 Line 41' Column a > ,

l Montaup Electric Company I (1) 4 Issues: 2000 Shares 6/3/89, 2000 Shares 7/7/69  !

4000 Shares 8/5/69, 2000 Shares 9/4/69  :

(2) 4 Issues: 1125 Shares each dated 4/6/84, 7/27/64, '

10/1/64 and 12/15/64 '

(3) 2 Issues: 1125 Shares each dated 1/15/65 and 12/15/65 ". i (4) 7 Issues: 675 Shares 3/31/66, 450 Shares 5/18/66 lii; 13350 Shares 6/23/66, 900 Shares 8/3/66 >

900 Shares 9/29/66, 450 Shares 11/7/66 .i 900 Shares 12/22/66 '

(5) 4 Issues: 225 Shares 3/2/67, 450 Shares 4/5/67 450 Shares 5/5/67, 1125 Shares 6/26/67 .

l (6) Sold 200 Shares Vermont Yankee in 6/91 at cost $30,000 .M

a 4

'! i

.j li t

4 e

e

,t i

!I i

~

i

-i l

Page 224-225 Footnote.1 '! 1 I

h, S.!

" Esh lIN"konpany 8 o

N$k[{PgthT*loal1 A RestErnission b

k*f3[1796'f$ Dec. 31,1995 MATERIALS AND SUPPLIES

1. For Account 154, report the amount of plant materiets 2. Give an explanation of inportant inventory adjust-

~

and operating supplies under the primary functional ments during the year (on a supplemental page) showing ettssifications as indicated in coltrm(s); estimates of general classes of materlat and smplies and the various amounts by f metton are acceptable. In cottann(d), desig- accounts ( operating expenses, clearing accounts, plant, note the department or departments which use the class of etc.) af fected debited or credited. Show separately )

,. materiet. debit or credits to stores expense-clearing, if applicable. j Account Beg I"g'of n En$'b!ar ch I gine

1. • Dek"mNIs" "N$

(s) $' (c)

~1 Fuet 5tock (Account 151) 56,170,911 $7,231,433 Etectric 2 Fuel Stock Expenses Undistrit:uted (Account 152) 172,716 153,726 Electric 3 Residuals and Extracted Products (Account 153) 4 Plant Materiets and Operating Supplies (Account 154) 5 Assigned to - Construction (Estimated ) 0 239,075 Electric 6 Assigned to - Operations and Maintenance 7 Production Plant (Estimated) 1,799,423 1,599,335 Electric 8 Transmission Plant (Estimated) 178,779 153,834 Electric 9 Distribution Plant (Estimated) 10 Assigned to - Other 11 TOTAL Account 154 (Enter Total of lines 5 thru 10) 51,978,202 51,992,294 12 Merchandise (Account 155) 13 Other Materiets and supplies (Account 156)

"Nf[ca$ibba!'U!if$ti!!Y 15 Stores Expense Undistributed (Account 163) 45,079 41,226 16 17 18 19 20 TOTAL Materiets and Supplies (Per Balance Sheet) 58,366,908 $9,418,679 m

i FERC FORM NO.1 (ED. 12-89) Page 227

Nahk[eE$NE"konpany $ b'f ** ' "

• M'k]IYoh!'inaAResuSetssion k2) kON*3N96 [ Dec. 31, 1995 Allowances (Accounts 158.1 and 158.2)

1. Report below the particulars (detalts) called for 4. Report the allowances transactions by the period they are concerning allowances, first ellgble for uses the current year's allowances in columns

2. Report all acquisitions of allowances at cost. (b)-(c), allowances for the three succeeding years in columns

3. Report attowsnces in accordance with a weighted average (d)-Cl), starting with the following year, and allowances for cost allocation method ard other accotnting as prescribed by the remaining succeeding years in colums (j)-(k).

< General Instruction No. 21 in the Uniform System of Accounts. 5. Report on line 4 the Envirorsnental Protection Agency (EPA)

Allowances Inventory Current Year l 19 h- '^cmn' "* n  %  %- l  % l nV l

01 Balance-Beginning of Year l l l IN (kessliN5!dAllow.)

05 Returned by EPA l l l ,

kh nE do 39,000 09 l l I to i I i 11 I I i 12 I l l u l l l 14 I I i 15 Total l 539,000l l anes'WA!$ NE' 4,062 t

19 Others l l l 20 l I I g Cost of Sales / Transfers:

a l l l 24 l l l .

25 l l l 26 l 1 1 27 I I I 28 Total l l l 29 Balance-End of Year 0l 534,938l l

!!t'$alesProceeds(Assoc.Co.)

33 Net Sales Proceeds (Other) l l l 34 Cains l l l 35 Losses l l l k!!o$$

36 Balance-Beginning of Year l l l 37 Add: Withheld by EPA l l l 38 Deduct: Returned by EPA l l l 39 Co t of Sales l l l 40 Balance-End of Year l l l kt'katesProceeds(Assoc.Co.)

44 Net Sales Proceeds (Other) l l l I 45 Gains l l l l 46 Losses l l l FERC FORM NO. (ED. 12-95) Page 228 1

i 1

g i

o7n $ N ionpany N1n 3 6 0 Allowances (Accounts 158.1 and 158.2) (continued) issued allowances. Report withheld portions lines 36-4o System of Accounts).

, l 6. Report on lines 5 allowances returned by the EPA. Report on

8. Report on lines 22 - 27 the name of purchasers /transfereesl

.ltino 39 the EPA's sales of the withheld allowances. Report on of allowances disposed of and identify associated conpanies. l!

.~-l Lines 4346 the net sales proceeds and gains / tosses resulting 9. Report the net costs and benefitsofhedgingtransactionsll lfrom the EPA's sale or auction of the withheld allowances. onaseparatelineunderpurchases/transfersandsales/ transfers li

-l 7. Report on lines 8-14 the names of vendors /transferors of io. Report on lines 32-35 & 43 46 thenetsalesproceedsandlI

-(lsttowances acquired and identify associated conpanies (see gains or lossss from allowance sales. l, 4 8:ssociated cornpanya under " Definitions" in the Uniform 19 l 19 l Future Years Totals

~,

95 ImI I

in ImI ni I m- in I m-o ba- '

I I I I al 01 0 0 1 I I I I ol o 05

~

l l I I I ol 39,000 $

I I I I I ol o 09 1 I I I I of a to 1 I I I I ol o 11 I I I I I ol 0 12

- I I I I I ol 0 13  ;

1 I I I I ol o 14 l l l l l ol 539,000 15 o 4,062 I I I I I ol 0 19 I I I i i ol o 20 l l l l l ol 0 N I I I I I ol o 23 I I I I I ol o 24 I I I I I ol o 25 I I I I I ol o 26 I I I I I ol o 27

- - 1 I I I I ol o 28 I I I I I ol s34,938 29 I I I I I I 11 I I I I I I 33 I I I I I I 34 I I I I I l 35 I I I l l l l 37 I I I I i l I 38 I I I I I I I 39 I I I I I I I 'o i I I I I '.

l. I 4' I I I I I l l '5 I I I I I I I '6

^ FERC FORM No.1 (FD. 12 95) Page 229

i!sion 13 96 3, EXTRAORDINARY PROPERTY LOSSES (Account 182.1)

N e te t Re fed

$ ort t E ,mo,yr, lk ttYam$AIc h.! an$ton,yr.

Nf]

CN M Amount j 0 0 0 3

4 5

'i 6

7 -

8 9

10 11 12

'3 to 15 16 I

20 TOTAL 0 0 0 UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2) b$ sk $fu- Cost ^i

• ph!ile!G& dss ' "I" 8m'dr aum -t BagEe'et a) (b) (c) (d) (e) (f) ,,

k) NI'odofAmor(5/94-6/00) 926 362,028 1,225,857 23 24 PRETOP canal 2 25 Period of Amor (5/94 - 6/00) 926 54,197 185,048 26 .

27 Yankee Atomic Shutdown 7, 28 Perid of Amor (3/92 00) 555 8,300,000 10,100,000 29 30 31 32 33 34 35 36 37 38 39 j 40 41  ;

42 ,

43 l 44 45 49 TOTAL $8,716,225 $11,510,905 ..

FERC FORM NO.1 (ED. 12-88) Page 230 Next Page is 232

e.

5 fon 13 oc 1,

,, OTHER REGULATORY ASSETS (Account 182.3)

W- 1. Report belou the particulars (details) catted for 3. Minor items ( 5% of the Balance et End of Year for Accomt concerning other regulatory assets which are created 182.3 or amounts less than $50,000, whichever is less) may be grouped through the retomaking actions of reputatory agencies by classes.

(and not includebte in other accounts).

2. For regulatory assets being amortized, show period of amortization in column (a).

CREDITS 1 E~

$ o Ets Gebits gcoun Amount ggeg (a) (b) N) (d) ke) j 1 Reg Asset DOE D80 - Seabrook S4,756 518 S22,080 $189,696 l 2 Reg Asset DOE 088 - Millstone 0 516 52,320 409,672 l 3 Dredging somerset Station 0 511 125,088 423,584 l

4 M-14 Rate case 126,192 928 4~33,861 165,343 5 Unit 5 Return 321,132 421 0 446,302

)

6 Unlt 5 Tax senef1t 8,489 (260,276) 236 192,484 7 Nuclear Fuet - Buyout Costs in Reactor 513,025 421 0 1,227,327

>, 8 Nucteer Fuet - Accus Amort of suyout Costs 0 518 252,814 (362,319) 9 Nuclear Fuet - Buyout cost in Stock 60,540 182 542,229 0 10 Fed Reg Asset FAS 109 2,519,836 190,283 662,550 32,094,629 11 MA Reg Asset FAS 109 1,071,068 190,282 241,434 6,143,519 12

, 13

>, 14 15 16 ,

17 h- 18 5 19 20

. 21

> 22 23 24 i 25 j

.. 26 I

27 28 29 30 31 1 32 l 33 34 35 36 37 38 39

- 40 41 42 43 44 TOTAL S4,625,038 S2,524,860 540,477,477 E FERC FORM Wo.1 (ED. 12-94) Page 232

T bien 3 '96 0 , .'-

MISCELLANEQUS DEFERRED DEglTS (Account 186) .-.

cor IrketNeNaneob $fef$b*b!b$$* "' #* 3. Minor items ( 1% of the Balance at End of Year for cf k[zEobnWtan ) I '* * * *

• me N o o d @ a!seN

• g Description of Miscellaneous Balance at CREDIT Balance at Deferred Debits Beginning of Year Amount End of Year (a) (b) (c) goun(b$g (e) (f) 1 1% Excess Depr DF17 (5/94-5/99) $174,418 0 410.1 $39,768 $134,650 2 Non-Quellffed Pnsn (5/94-5/99) 249,048 0 926 57,405 191,643 3 Misc Deferred (1860-60&1860-92) (310) 81,906 various 80,'T 859 4 C&LM Deferred 578,212 557 578,212 0 5 C&LM Underrecovery 209,783 2,979,766 449.1 3,189,549 0 6 Pensions 2,547,933 926 2,547,933 7 0 8 0 9 0 10 0 11 0 12 0 13 0 14 ,

15 16 17 18 19 20 21 22 23 25 25 26 27 2S 29 ..

30 J

31 32 33 34 35 i 36 37 l 38 39 .u-40 41 .G 42 .

43

• 44 45 46 u.

~

47 Misc. Work in Progress 31,597 46,017 b ! b s h e Y ges N 351) ,

49 TOTAL S3,790,681 52,921,102 @.

FERC FORM NO.1 (ED. 12-94) Page 233

.?

T i!sion 13 96 e , 995 ACCUMULATED DEFERRED INCOME TAXES (Account 190)

~

1. Report the information called for below concerning the 2. At other (Specify), include deferrals relating to respondent's accounting for deferred income taxes. other income and decbetions.

Account g ivisions BegN"# o! Year E'ho r eah 1 Electric 2 FAS 109 $9,290,901 58,527,993 3 Post Retirements other than Pension (325,962) (29,825) 4 Seabrook Unit 2 Salvage 0 349,981 5 Seabrrook Unfunded Pension Expense 120,700 144,195 6 Non-Qualified Pension 57,343 286,721 7 other 1,632,808 35,364 8 TOTAL Electric (Enter Total of lines 2 thru 7) 510,775,790 $9,314,429 9 Gas 10 11 12 14 15 Other 16 TOTAL Gas (Enter Total of lines 10 thru 15) 61 0 17 other 18 TOTAL (Acct 190)(Total of lines 8,16 and 17) 510,775,790; $9,314,429 NOTES Obsol te Inventory 72,845 11,191 Aquidneck Litigation 795,040 0 RAR GAA Expense capitalized 13,722 10,827 RAR Local Taxes Disallowed (17,435) (6,639)

Insurance Reserve 24,194 19,985 Seabrook 2 Writeoff overrecovery 414,557 0 Work;rs conip contingency 329,885 0 1,632,808 35,364 V.

l FERC FORM NO.1 (ED. 12-88) Page 234 Next Page 250 1

blon 13 , 995 '

~

• CAPITAL STOCK (Accounts 201 and 204)  ;( '

1. Report below the particulars ( details ) catted for con- a specific reference to report form (f.e. year and company title) corning cosmon and preferred stock at end of year, may be reported in cottssi (a) provided the fiscal years for both distinguishing seperate series of any general class. Show the 10 K report and this report are compatible.

seper:te totals for common and pr:ferred stock. If information 2. Entries in coluun (b) should represent the nLabor of ta meet the stock exchange reporting requirement outlined in shares authorized by the articles of incorporetton as columi (a) is evaltable from the SEC 10-K Report Form filing, amended to end of year.

Lg *l'mNfNSlch a

g End Yeer (a) (b) (c) (d) j 1 Common Stock 836,0 l S100.

2 TOTAL _COM 836,0 ,

3 '

4 Preferred stock 15,000 S100.00 3 5 TOTAL , PRE 15,000 - 1 6

7

• 8 9

10 11 12 13 14 15 16 17 .

18 19 20

^

21 22 23 25 j 25 26 j 27 l 28 29 -

30 31 ~

32 33 i

34 3-35 36 -

l 37

g i 38

39 40 41 42 t.

FERC FORM NO.1 (ED. 12-91) Page 250

?

rManpany 0 g 13 , 995 N .

CAPITAL STOCK (Account 201 and 204 )(Continued)

3. Give particutern (detalts) concerning shares of any 5. State in a footnote if any capital stock which has been class and series of stock authorized to be issued by a nominally issued is nominally outstanding at end of year.

regutctory commission which have not yet been issued. Give particulars (details) in coluan (a) of any nominally

4. The identification of each clasa of preferred stock issued capital stock, reacquired stock, or stock in sinking should show the dividend rate and whether the dividends and other funds which is pledged, stating name of pledgee tra cumulative or noncunulative, and purposes of pledge.

STANDING PER BA HELD BY RESPONDENT g$15CE y ET t

gs AS g g E g oCK IN g !g g Shgs gt shg Cg Sges t 586,000 S58,600,000 1 586,000 58,600,000 0 0 0 0 2 3

15,000 1,500,000 4 15,000 1,500,000 0 0 0 0 5 6

7 8

. 9 10 11 12 13 14 15 16 17 18 19 20

, 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 FERC FORM NO.1 (ED. 12-88) Page 251 p

g. NEXT PAGE IS 253

+

gl s ton 13 D ,

OTHER PAID IN CAPITAL (Accounts 208 211, Inc.)

Report below the balance at the end of the year and the g [

capital change which gave rise to amounts reported under d*

Infonnation specified below for the respective other paid-in this caption including identification with the class and series capit:L accounts. Provide a subheading for each accomt and of stock to which related.

show a total for the account, as wett as total of att accomts (c) Gain on Resale or Cancellation of Reacquired Capital for reconelliation with belance sheet, page 112. Add more Stock (Account 210)--aeport balance at beginning of year, citums for any account if deemed necessary. Explain credits, debits, and balance at end of year with a designe-changes made in any account during the year and give the tion of the nature of each credit and debt identified by the accounting entries effecting such change. class and series of stock to which related.

(c) Donations Received from Stockholders (Account (d) Miscellaneous Paid-In Capital (Account 211)-Classify 208)-8 tate amount and give brief explanation of the origin amounts included in this account according to captions and purpose of each donation.

• which, together with brief explanations, disclose the general (b) Reduction in Par or stated Value of Capital Stock (Ac-. nature of the transactions which gave rise to the reported coat 209)-State amount and give brief explanation of the amounts.

N N. N*

1 Miscellaneous Paid in Caoltal S29,528,000 2

3 4

5 ,

6 7 -

8 9

l10

" 11 12 3 -

u .

15 16 17 18 l 19 i a 21

=>

23 24 25 r i 27 28 l

N 30 -

31 32 .

I 33 j,

'}.-

34 r. - 4 35 36 37 Ci l

l 38 l 39 . . .

40 TOTAL S29,528,000 FERC FORM NO.1 (ED.12 87) Page 253 h.

1 e ,

-(

1 1:

7.

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BLANK PAGE (Mext page is 256) l i

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LONG-TERM DEBT (Accounts 221, 222,223, and 224) J**

1. toport by balance sheet account the particulars (detalls) 6. In column (b) show the principal amount of bonds or other ,

cone rning long-term debt included in Accounts 221, Bonds, 222, long-term debt originally Issued.

Reacquired Bonds, 223, Advances from Associated Companies, ard 7. In column (c) show the expense, premium or discount 'wlth 224, other Long Tern Debt. respect to the amount of bonds or other long-term debt origi-

2. In column (a), for new issues, give Commission authoriza- netly lasued.

tion nunbers and dates. 8. For column (c) the total expenses should be ilsted first

3. For bonds assumed by the respondent, include In column (s) for each lasuance, then the amount of premium (in parentheses) the name of the issuing conpany as well as a description of or discount. Indicate the premlun or discount Wlth a notation, the bonds, such as (P) or (D). The expenses, premius or discomt should

4. For advances from Associated Companies, report separately not be netted.

advances on notes and advances on open accounts. Designate 9. Furnish in a footnote particulars (detalts) regarding demand notes as such. Include in coluun(e) n of associated the treatment of unamortized debt expense, preolun or discount l compentes from which advances were recelved. associated with issues redeemed during the year. Also, give in

5. For receivers' cer*1ficates,show in colunn(s) the name of a footnote the date of the Commission's authorization of the court and date of court order under which such certlff- treatment other than as specified by the Uniform System of cctes were issued. Accounts, in go.e (Fornewissue$1 C'oh!!!!n bhSNzaklokMf! and dates) "toh P*

TNr

• D gaued bT!gt .

1 Account 221 Bonds 2 30 yr - 8% Debenture Bonds 8,500,000 8,122 0 3 30 yr - 81/4% Debenture Bonds 12,800,000 15,260 D 4 30 yr - 14% Debenture Bonds 26,000,000 12,959 0 5 30 yr - 10% Debenture Bonds 9,275,000 3,240 0 6 30 yr - 16 1/2 Debenture Bonds 19,000,000 7,243 D 7 25 yr - 10 1/8 Debenture Bonds 40,000,000 8 30 yr - 12 3/8% Debenture Bonds 30,000,000 5,332 D i 9 30 yr - 9 3/8% Debenture Bonds 25,000,000 11,225 0 1 10 30 yr - 9% Debenture Bonds 5,000,000 2,260 D l 11 12 SUBTOTAL 175,575,000 65,641 13 11 15 16 17 18 19 20 21 l

22 l 24 25 c 26 27 *I 28 29 30 31 32 R 33 TOTAL S175,575,000 S65,641 FERC FORM NO.1 (ED. 12-91) Page 256 p

$b

y l

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"P*"Y a lsion 13 6 Dc ,

LONG-TERM DEBT (Accounts 221, 222,223, and 224) (Continued) e

10. Identify separate undisposed amounts applicable to securities give particulars (detalts) in a footnote l Issues which were redeemed in prior years. Including name of pledgee and purpose of the pledge.

11. Explain any debits and credits other than amortiza- 14. If the respondent has any tong-term debt securities l tion deblted to Account 428, Amortization of Debt Discount which have been nominally issued and are nominally outstan-and Expense, or credited to Account 429, Amortization of ding at end of year, describe such securities in a footnote.

Premlun on Debt - Credit. 15. If interest expense was incurred during the year on

12. In a supplemental statement, give explanatory parti- any obligations retired or reacquired before end of year, cutars (details) for Accounts 223 and 224 of net changes include such interest expense in colum (1). Explain in a during the year. With respect to long-term advances, show footnote any difference between the total of colum (1) and for each conpany: (a) principal advanced during year, (b) the total of Accotrit 427, Interest on Long Term Debt and Interest added to principal amount, and (c) principal repaid Account 430, Interest on Debt to Associated Conpanies.

during year. Give Coninission authorization nunbers and dates. 16. Give particulars (details) concerning any long-term

13. If the respondent has pledged any of its long term debt debt authorized by a regulatory commission but not yet lasued.

AMORTIZATION PERIOD Outstandin sub ka y Date From Date To u Intere pYear gne 1

l 05/01/70 04/30/00 8,500,000 680,000 2 l 05/01/70 04/30/00 10/01/73 09/30/03 12,800,000 1,056,000 3 10/01/73 09/30/03 10/01/75 09/30/05 26,000,000 3,640,000 4 10/01/75 09/30/05 12/01/75 11/30/08 9,275,000 927,500 5 12/01/78 11/30/08  !

10/01/80 09/30/10 19,000,000 3,155,000 6 10/01/80 09/30/10 07/31/08 36,594,730 4. J50,000 7 08/01/83 07/31/02 08/01/83 05/01/83 04/30/13 30,000,000 3,712,500 8 05/01/83 04/30/13 11/30/20 25,000,000 2,343,750 9 12/01/90 11/30/20 01/01/91 11/30/20 5,000,000 450,000 10 12/01/90 11/30/20 01/01/91 11 172,169,730 19,994,750 12 l 13 14 15 16 17 18 19 20 21 22 23 24 25 l 26 27 28 l 29 30 31 32 5172,169,730 $19,994,750 33 Page 257 Next PaDe 261 FERC FORM NO.1 (ED. 12-90)

4 j*k !bn OWi l '

NoNns ([e $lonpany t JAResubmi!sion k'h31f96bW O D:c. 31, 1995 -

0 RECONCILIATIONOFgP Eg g g H TAXABLE INCOME '*

yea)* h W t !bN Yn e IN ti$g edNLinc edf'b!aEi ,Nv!!,15t!!!'ha$y o N Ys th N tax accruals and show computation of such tax accruals. In- eliminated in such a consolidated return. State names of l clude in the reconcillation, as far as practicable, the same group members, tax assigned to each group merber, and detall as furnished on Schedule M-1 of.the tax return for the basis of allocation, assignment, or sharing of the year. Submit a reconciliation even though there is no taxable consolidated tax among the group members.

Inecme for the year. Indicate clearly the nature of each recon- 3. A substitute page, designed to meet a particular citing amount. need of a company, may be used as long as the data is solf8a !d tlx r!t re!NifNepofIed 5 in!o"E n i$s!rNEibs Lg Particulag(Details) gt 1 Net Income for the Year (Page 117) $19,697,611 2 Reconciting Items for the Year 3

4 Taxable Income Not Reported on Books 5

6 7

d See Page 261.1 690,986 9 Dedactions Recorded on Books Not Deducted for Return 10 11 12 13 See Page 261.1 8,964,016 14 Income Recorded on Books Not Included in Return M 15 16 i 17 18 See Page 261.1 (1,956,219) 19 Deductions on Return Not Charged Against Book Income 20 21 22 23 24 25 26 See Page 261.1 (16,593,860) 27 Federal Tax Net Income 10,802,534 2S Show Conputation of Tax:

29 30 1995 Corporate Fed Income Tax a 35% 3,780,887 31 Attocated Consolidated Tax Savings (40,180) 32 1995 Conso;1 dated Federat income Tax Altoc (current) 3,740,707 33 34 35 36 37 38 39 40 41 42 43 44

• FERC FORM NO.1 (ED. 12 88) Page 261

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pe

< Paga 261 Line 44 Column a > l

- Taxable Income Not Reported on Books Compensation for Use of Capital 64,134 ,

OCA State Income Tax Benefits 44,482 I Unit #5 State Income Tax Benefits 23,424 l Dividends Received 30% Taxable 558,946 690,986 Deductions Recorded on Books Not Deducted for Return Federal & State Income Taxes (includes deferred) 7,041,927 Unearned Compensation-Restricted Stock Plan 51,797 Conservation & LM Amortization 578,212 M-14 Expense Amortization 433,862 Penalties 4,106 Civil, Political & Related Expenses 3,549 Seabrook Unfunded Pension Expense 67,657 .

Amortization Non-Qualified Pension 57,405 l Canal II PRBOTP Amortization 54,197 Non-Qualified Pension 198,600 Amortization-Dredging 125,088 Non-Qualified VRI 347,61,6 r,.

8,964,016 i

. Income Recorded on Books K t Included in Return j AFUDC Equity (432,830)

Equity in Earnings (1,646,357) l Pension Income-Montaup (325,607) l Pension Expense-EUASC 369,527  !

Pension Income Capitalized-Montaup (15,848)

Pension Capitalized-EUASC 16,530 Key Executive Life Insurance MECO & EUASC (23,378) '

R.O.I. Unit 5 Equity (173,556)

Getty Buyout AFUDC Equity (26,828)

Nemal Buyout AFUDC Equity 8,691 VRI Qualified Pension 293,437 c - (1,956,219)

Deductions on Return Not Charged Against Book Income Depreciation (10,488,566)

.[ Cost of Removal S/L & D/B Property (776,389)

obsolete Inventory (154,180) i FAS 106 85,453 M-14 Rate Case Expense (126,192)

Aquidneck Litigation (2,018,799)

Restricted Stock Plan Distribution (20,547) ,

Insurance Reserve . (10,086)  ;

Gains / Losses ACRS & MACRS Property (495,782)  !

ADR Cost of Removal (265,832)

IRS Interest Accrual (215,309)

Seabrook II Property Recovery / Loss (1,257,650)

Workers Comp Contingency (849,981)

(16,593,860)

Page 261 Footnote.1

e D.

Consolidated Group Members Consolidated Tax Allocation ^:f-EUA Parent 0 Blackstone Valley Electric 1,541,638 Eastern Edison Company 7,379,308 Montaup Electric Company 4,208,672 EUA Cogenex Corporation (182,930)

EUA Energy Investment (2,201,364)

EUA Ocean State Power 2,264,495 Newport Electric Corporation 916,418 EUASC 101,063 14,027,300 Basis of Allocation: .

Allocation is based upon each group member's contribution to consolidated taxable income in accordance with Eastern Utilities Associates and affiliated corporations tax sharing agreement.

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lon 3 ,

TAXES ACCRUED, PREPAID AMD CHARGED DURING YEAR *h

• j

1. Give particulars (details) of the conbined propold and Enter the amounts in both coluuns (d) and (e). The balancing of f accrued tax accomts and show the total taxes charged to this page is not affected by the inclusion of these taxes.

~

oper tions and other accounts during the year. Do not include 3. Include in coltain (d) taxes charged during the year, taxes gasoline and other sales taxes which have been charged to the charged to operations and other accounts through (a) accruals accounts to which the taxed materlat was charged. If the actual credited to taxes accrued,(blamomts credited to proportions of or eetlasted esamts of such taxes are know, show the prepeld taxes chargeable to current year, and(c) taxes peld and amounts in a footnote and designate whether estimated or actual charged direct to operations or acewnts other than accrued and anomte. prepold tax accounts.

2. Include on this page, taxes paid during the year and charged 4. List the aggregate of each kind of tax in such manner that direct ta final accomts,(not charged to prepold or accrued taxes).ggx for each state and subdivision can readily be BALANCE AT BEGINNING OF TEAR (seeN I Ton 5)

(J T* D 1 LOCAL 2 Property & R/E 3 Massachusetts 3,592 2,542,253 2,542,140 4 Rhode Island (557) 33,981 33,424 5 Connecticut 564,051 983,908 1,547,960 6 Maine (5,797) 80,414 84,028 -

7 New Hampshire 123,201 844,385 1,142,107 8 SUBTOTAL 684,490 0 4,484,941 5,349,659 9

10 New Hampshire 11 Corp current 72,545 147,950 12 Corp Prior 38,030 (106,681) (144,711) 13 susT0TAL 0 0 110,575 41,269 (144,711) 14 15 Massachusetts 16 sales & Use 1,631 10,629 11,029 17 Franchise-Prior (344,701) (144,703) ,

18 Franchise Current 552,345 360,000 19 SUBTOTAL 1,631 0 218,273 226,326 20 21 Connecticut 22 S:les 87,265 87,265 23 Corp sus Tax-Prior 0 (5,258) (5,258) 230,400 235,000 r 24 Corp sus Tax Current 0 25 SUBTOTAL 0 312,407 317,007 26 , , ,

27 Federal ,;,

485,452 "

28 Income-Prior (410,119) 0 29 income Current 3,740,712 1,330,000 (410,119) 30 SUBTOTAL 0 0 3,330,593 1,330,000 75,333 31 h 32 EU4sc Attocated 451,647 451,647 33 SUBTOTAL 0 451,647 451,647 0 ,,7 34 p.

35 other 36 Meco F/R 39 459,869 459,487 .,

37 Canal #2 Attoc 202,858 202,858 [N 38 tillstone #3 P/R 151,652 151,652 !U 39 seabrook #1 P/R 123,986 123,986 40 SUBTOTAL 39 0 938,365 937,983 0 g, 5686,160 0 59,846,801 $8,653,891 (S69,378) 41 TOTAL ["I,.

FERC FORM NO.1 (ED. 12 94) Page 262

a k.

' "'P""Y k i!slon 13 3, ,

a TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR (Continued) j

5. If any tax (exclude Federal and State income taxes) 8. Enter accounts to which taxes charged were distributed in '

covers more than one year, show the required information columns (1) thru (1). In cottari (I), report the anomts charged P seper:t:ty for each tax year,ldentifying the year in colum(a). to Accounts 408.1 and 409.1 for Electric Departner.t only.

6. Enter att adjustments of the accrued and propold tax Group the amounts charged to 408.1, 409.1, 408.2, and 409.2 accounts in cottsm (f) and explain each adjustment in a foot- mder other accounts in column (1). For taxes charged to other nota. Designate debit adjustments by parentheses, accounts or utility plant, show the number of the appropriate ,

7. D3 not include on this page entries with respect to de- balance sheet account, plant account or subaccount. I ferred income taxes or taxes collected through payrott deduc- 9. For any tax apportioned to more than one utility depart-tions or otherwise pending transmittat of such taxes to the ment or account, state in a footnote the basis (necessity) of taxing authority, apportioning such tax.

BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED l

' U

• kk!!"ounb N ' Acc TnN .1, IS Other

"'5) 2 (Acc (Acco 09.3) t cg % Ljne o.

1  !

2 3,705 2,542,253 3  !

O 33,981 4 j 0 983,908 5 (9,411) 80,414 6 (174,521) 844,385 7 (160,227) 4,484,941 0 0 0 8 f 9 )

10  !

(75,405) 67,458 5,087 11 j 0 41,496 (3,466) 12 (75,405) 108,954 0 0 1,621 13 l

14 i 15 1,231 10,629 16 (199,998) (5,476) (339,225) 1T 192,345 513,613 38,732 18 l (6,422) 508,137 0 0 (289,864) 19 l 20 21 0 87,265 22 4 0 108,936 ,

(114,194) 23 (4,600) 230,400 24 (4,600) 426,601 0 0 (114,194) 25 26 l 27 i 75,333 3,897,902 (403,899) 28 2,000,593 (6,220) (157,190) 29 2,075,926 3,891,682 0 0 (561,089) 30 31 451,647 32 0 0 451,647 0 0 0 33 34 35 384,898 74,971 36 )

421 202,858 37  !

151,652 38

? ,

b 123,986 39

{

0 863,394 0 0 74,971 40 j 421

$1,809,693 0 $10,735,356 0 0 (S888,555) 41 '

i l

Page 263 Next Page is 266 FERC FORM No.1 (REV. 12-95)

. _ _ _ . _ _ . _ _ ._. m ....__-..m _ _ _ . . _ _ . _ _ _ _ _ . _ . . _ _ . . _ _ _ . . _ ._ .

Mon a bospany 0 1 1 d2jk3ARIsubmNston bY 03121796 Dec. 31,1995 -

ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255) ,f-Report below information applicable to Accomt 255. footnote any correction adjustments to the account balance shown in Wh:re appropriate, segregate the balances and transac- column (g). Include in coltrnn(l) the average period over which the tax tions by utility and nonutility operationa. Explain by credits are amortized.

Line Accomt l lCurrehN!bs"fnSee galynceat Deferred for Year l N3. $ isions Electric Utility b l^b 'l l W*l W l (

3 4%

4 7%

10% 14,238,245 236 0 411.4 628,152 0 8 TOTAL $14,238,245l 5628,152l 0 l 0} l a

17 18 l

19 20 21 22 23 24 25 26 l 27 l 28 l

29 '

30 l

31 l

32 33 34 35 l 36 37 38 i 39 40 l

41 1 42 43 44 45 46 ~

47 48 FERC FCOM NO.1 (ED. 12-89) Page 266 d

-~ .- - .. -. . . ._. . . . _ - - .- . .

4:

. a Ned N'ceYE"bompany $NMoh!'ina i W.r of R w t 4 ., $f 8

• k1ARisu8 mission Y'**3196fRgrt l Dec. 31,1995 ACCUMJLATED DEFERRED INVESTMENT TAX CREDITS (Account 255) (Continued) ge Pg Adjustment Explanation Baga e at cf Year to neome ho.

(h) (1)

,MM 1 0 2

'l 0 3 0 4 13,610,093 23.67 YEARS 10 11 12 13 14

.;3 15 16 17 18 19 20 4- 21 4

22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 Page 267 Next Page is 269

' ~ FERC FCRM NO.1 (ED. 12 89) 2

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• slon 3 e 3, ,] ,

OTHER DEFERRED CREDITS (Account 253) @, ,

1. Report below the particulara (detalts) cetted for 3. Minor items (5% of the Balance End of Year for Ac-concerning other deferred credits, count 253 or amounta less than $10,000, whichever is

2. For ary deferred credit belng amortized, show the greater) may be grouped by classes.

period of amortlzation.

Line DEBITS gatencyat to. e C t oNr Contre Amomt n YNr b

(a) (b) #{[ (d) (e) (f)

$51,448 419.0 $55,922 S49,705 S45,231 1 C&LM Unearned Interest 2 Reg Liability Mass Yankee 18,400,000 182 & 555 8,300,000 10,100,000 3Unfmded Seabrook Pension Expense 309,532 926 67,657 377,189 4 Liability PRBOP = Tax Ded 1,208,235 242 & 926 229,782 978,453 5 Vilmtary Rettrement Incentive 0 232 36,267 258,931 222,664 6

7 8

9 i

10 11 12 13 14 15

~

16 17 I 18 4M 20 21 22 23 24 u 25 26 27 28 29 30 ,

31 32 33 34 .

35 36 37 re.

38 39 40 41 *.

42 43 44 45 a

46 S19,969,215M 58.621,971 S376,293 511,723,537 g 47 TOTAL tiC:

FERC FORM NO.1 (ED.12 88) Page 269 E.5.'

d:

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n0 ont k ##

, Rx ission OD*3 796Y'* Dec. 31, 1995 ACCUMULATED DEFERRED INCOME TAXES -- OTHER PROPERTY (Account 282) -

j 1. Report the information cetted for below concerning the to property not stbject to accelerated amortization.

l respondent's accounting for deferred income taxes relating 2. For other (Specify), include deferrats relating to other

{

l CHANCES DURING YEAR I Accomt Subdivisions 'gimIng

! "' gs s s

(a) (b) Acc$t4$8.1 AN (b) 1N1

{ 1 Account 282 ~

( 2 Electric S109,860,705 l 56,023,359 S2,322,252 l

3 Cas l l l 4 Other (Define) l l 5 TOTAL (Enter Totas of lines 2 thru 4) $109,860,705 l 56,023,359 l 52,322,252 6 Other (Specify) l l 7

l l 8

l l 9 TOTAL Accomt 282 (Enter Total of lines 5 thru 8) S109,860,705 l 86,023,359 l S2,322,252 10 Classification of TOTAL 11 Federal Income Tax 93,515,877 l 5,164,401 2,068,848 l

12 stite Income Tax 16,344,828 l 858,958 253,404 l

13 Local Income Tax I l l NOTES I

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FERC FORM NO.1 (ED 12-89) Page 274 "

c.i

• • ' I 'I g MoNn eup l[lNc"bonpany * ! N ohi i I'373i796** 8 N oec.

I si, 1995 l

3k3ARisdmtission 0 ACCUMULATED DEFERRED INCOME TAXES -- CTMER PROPERTY (Accomt 282) (Continued) income and deductions.

3. Us3 separate pages as required.

CHANGES DURING YEAR ADJUSTMENTS D Cre t b'Mf!ar Account 1bo.2 Accomt 11.0 geog g

Amount ggg)

Amount (k)

No.

(e) (f) (g) (h) (i (J) ,

(S67,224) 0 various 82,N1,635I410.1 S1,559,558l $112,352,511 2 l

l l 0 3 l

O '

I I I

($67,224) 0 $2,701,635l 51,559,558l $112,352,511 5 l

l 0 6 l l l 0 7 l l I O a I I

($67,224) 0 52,701,635l 51,559,558l 5112,352,511 9 l

10 (11,736)l 2,701,635l l 0l 14,237,011 12 l l 13 l l l l l l NOTES (Continued) l FERC FROM NO.1 (ED. 12-94) Page 275

-. . - -_~ . - . _ ._ . .. _. . - - . - . - .

ky '

oNna ec kompany '. j*]ARxubiss1on

[ Aft Chi inat. Y

$$131796 [ Dic. 31, 1995 ,

ACCUMULATED DEFERRED INCOME TAXES-0THER (Account 283) ,

1. Report the information catted for below concerning the to amounts recorded in Account 283.

respondent's accounting for deferred income taxes relating 2. For other (Specify), include deferrats relating to other l CHANGES DURING YEAR

{ne Account subdivisions glenegt gs gt 1 .1 ch er Acc 4N.1 Acco

)

2 fc 3 Fed FA3 109 56,666,033l l 184,032l l 184,032 4 Fed CALM

, 5 Fad AMT (4,377,856)l l 6 l l 7 l l 1,336,508l 61,245l 105,135 8 Other l

53,808,717l $61,245l S289,167 9 TOTAL Electric (Total of lines 3 thru 8) 10 Gas 11 l d l l 13 I I .

14 l l 15 I i 16 Other l l 17 TOTAL Cas (Total of lines 11 thru 16) l l 18 Cther (Spectfy) l l S3,808,717l 561,245l S289,167 19 TOTAL (Acct 283) (Enter Total of lines 9,17 and 18) 20 Classification of TOTAL 3,322,298l 50,253 l 243,275 21 Fe',arat income Tax 486,419l 10,992l 45,892 22 state Inccee Tax Lccal Income Tax l l 23 NOTES l

)

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Page 276 FERC FCCM NO.1 (ED. 12-89) m

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NEsup EI*scN"bcepany O cal

' , ;l A Res ission k *f3N96N 0$ Dec. 31,1995

['.'

ACCUMULATED DEFERRED INCOME TAXES-0THER (Account 283)(continued) income and deductions. and 277. Include amounts relating to insignificant items

3. Provide fa the space below explanations for page 276 listed under other.

4. Use separate pages as required.

CHANGES DURING YEAR l ADJUSTMENTS l g ts Agts l Debits l Credits l ggeg {ne Account 48.2 Account 4$T.2 Amount Amount l

(e) (f) geogtyl (g) (h) l] g(o 1)gunl l (j) l (k)

[ 1 j 2 l l l l l182 l S2,272,799l $8,938,832 3 l l l l 0 4 l l l l l l l l (4,377,856) 5 l l l 0 6 l l l l l 0 7

( l l l l l lvarious l 9,907 182 l 1,956,788l 3,239,499 8 l

$7,800,475

$9,907 l $4,229,587l 9 I l l l 10 i~ 11

~

12 4, 13 14 15 17 1,

33

$9,907 S4,229,587 $7,800,475 19 (3,834) 2,272,799 5,405,909 21 13,741 1,956,788 2,394,566 22 1 )

NOTES (Continued)

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FERC FORM No.1 (ED. 12 94) Page 277

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OTHER REGULATORY LIASILITIES (Account 254) ~'*

1. Reporting below the particulars (detalts) cetted for 3. Minor items ( 5% of the Balance at End of Year for Account concerning other regulatory liabilities which are 254 or anomts less than 550,000, whichever is less) may be created through the retomaking actions of regulatory grouped by classes.

i agencies (and not includable in other amounts).

l 2. For regulatory liabilities being amortized, show l period of amortlantion in cotum (a).

DEBITS b a ry ETIfes g ge4 Amount YYNr (a) to) (c) (d) (e) 1 Fed Reg Liab FAs 109 282,190 82,061,192 $17,109,942 2 tt:te Reg Lieb FAS 109 282,190 76,374 142,882 319,872 3

4 5

6 7

8 9  !

l 10 11 .

12 -

13 14 I 15 16 17 I 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 " i 34 35 36 w

37 38 39 i:4 40 41 TOTAL M $2,137,566 5142,882 $17,429,814 ,

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NEXT PAGE IS 300  !

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Ion 3 96 , 99 -,:

ELECTRIC OPERATING REVENUES (Account 400) ',-

1. Report below operating revenues for each prescribed for each group of meters added. The average number of account, and manufactured gas revenues in total. customers means the average of twelve figures at the close

2. Report ramber of customers, columns (f) and (g), on of each month, th2 basis of meters, in addition to the nunber of flat rate 3. If increases or c.'ecreases from previous year (colunns l accounts; except that where separate meter readings are (c),(e), and (g)), are not derived from previously reported )

added for bitting purposes, one custcener should be counted figures, explain any inconsistencies in a footnote.

]

OPERATING REVENUES 1 AmountgrYear AmountforgeviousYear I sales of Electricity 2 (440) Residentist sales I

3 (442) Commercial and Industrial Sales 4 small (or Comm.) (see Instr.4) 5 Large (or Ind.) (see Instr.4) 6 (444) Pubtle street and Highway Lighting 7 (445) Other sales to Public Authorities 8 (446) Sales to Raltroads and Railways _

9 (448) Interdepartmental sales 10 TOTAL sales to ultimate Constners i 11 .. .,47) Sales for Resale 5347,715,189 5349,442,387 j 12 TOTAL sales of Electricity $347,715,189 s349,442,387 j 13 (Less) (449.1) Provision for Rate Refunds $6,120,382 s7,953,748 -

14 TOTAL Revenues Net of Prov. for Refunds $341,594,807 s341,488,639 l 15 Other operating Revenues M 16 (450) Forfeited Olscounts i 17 (451) Miscellaneous service Revenues 18 (453) sales of Water and Water Power 19 (454) Rent from Electric Property 1,315,767 1,243,635 j 20 (455) Interdepartmental Rents 21 (456) Other Electric Revenues 2,827,356 2,782,644 22 23 24 25 ,

26 TOTAL Other Operating Revenues 54,143,123 $4,026,279 '

27 TOTAL Electric Operating Revenues $345,737,930 5345,514,918 l

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,a FERC FORM NO.1 (ED. 12 90) Page 300 -

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_ _ _ _m ____.___m- _ _ _ _ - _ _ _ . _ _ _ _ _ _ .

o7n ec bmpany Mion 3 6 99 j- ELECTRIC OPERATING REVENUES (Account 400)(Continued)

H 4. Cosinercial and Industrial Sales, Account 442, may be 5. See page 108, important changes During Year, fcf classified according to the basis of classification (Small inportant new territory added and important rate increases cr Consaarclat, and Large or Industrial) regularly used by or decreases.

th3 respondent if such basis of classification is not 6. For lines 2,4,5,and 6, see page 304 for a-xxJnts reta-generetty greater than 1000 Kw of demand. (See Account 442 ting to unbilled revenue by accomts.

cf th> Uniform System of Acccunts Explain basis of classi- 7. Include mmetered sales. Provide details of such sales

(; fication in a footnote.) in a footnote.

MEGAWATT HOURS SOLD AVG. No. CUSTOMERS PER MONTH Number Previous Year o.

AmountgrYear Amotnt fgPrevious Year Nmbergr Year 2

T 4

5 6

7 8

9 10 5,084,599 5,586,250 15 14 11 5,084,599 5,586,250 15 14 12 13 5,084,599 5,586,250 15 14 14 Line 12, Colum (b) includes S of tsbilled revenues.

Line 12, Colum (d) includes MWH relating to unblited revenues.

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SALES FOR RESALE (Accomt 4473  :.),

1. Report all sales for resale (i.e., sales to purchasers interrteted for economic reasons and is intended to rensin ethir than ultimate consumers) transacted on a settlement reliable even mder adverse conditions (e.g., the supplier besIs other than power exchanges durtng the year. Do not must attempt to buy emergency energy from third parties to report exchanges of electricity ( l.e., transactions meintain deliveries of LF service). This category should involving a balancing of debits and credits for energy, not be used for tong-term firm service which meets the capacity,etc.) and any settlements for isbelanced exchanges definition of RQ service. For att transactions identified ori this schedJle. Power exchanges must be reported on the as LF, provide in a footnote the termination date of the Purchased Power schedute (pege 326 327). contract defined as the earliest date that either buyer

2. Enter the name of the purchaser in column (a). Do note or setter can unilaterally get out of the contract. l abbreviste or trmeate the name or use acronyms. Explain In IF - for Intermediate term firm service. The same as LF l c footnote any ownership interest or affiliation the service except that " intermediate term" means longer than respondent has with the purchaser. one year but less than five years.

3. In coltan (b), enter a Statistical Classification Code SF = for short term firm service. Use this category for based on the original contractual terms and conditions of alt firm services where the duration of each period of th) service as folIows: consaltarnt for serylce Is one year or Iess.  !

RQ - for requirements service. Requirements service is LU - for long-term service from a designated generating I service which the supplier plans to provide on an ongoing unit. "Long terna means five years or longer. The avall-basis (i.e., the supptler includes projected toad for this ability and rettability of service, aside from transmission service in its system resource planning), in addition, the constraints, must match the avaltability and reliability of rettability of requirements service must be the same as, or designated unit.

suond only to, the supplier's service to its own ultimate IU - for intermediate-term service from a dessnated consumers. generating unit. The same as LU service except that  ;

LF - for long term service. "Long-term" teens five years " Intermediate-term" means longer than one year but less  !

cr tonger and " firma means that service cannot be than five years.

Actual Demand (MW)

(b ff (! ) -

T r 5 ,

1 etackatone Vattey Etectric RQ 1 220.30 222.99 220.30 2 Eastern Edison Company RQ 1 453.80 453.80 453.80 3 Newport Electric RQ 1 86.68 87.39 86.68 4 SUBTOTAL RQ 5 Mepool (2) Os FPC#2 none rwne none 6 Middleboro LF 75 8.00 Nval  :.00 7 Pascoag LF 64 4.70 Nval 4.70 l

8 TMLP LF 94 None None None i 9 graintree '

LF 87 25 Nvel Nvel 10 MmdEC LF 81 35.18 Nval Nval 11 Braintree (1) 05 ER96 437 000 None None None 12 conssonwealth (1) os ER95-1165-000 None None None 13 CNEEC (1) 05 102 None Nval Nval

)

14 Middleboro (1) 1 A

FERC FORM NO.1 (REVISED. 12 90) Page 310 -

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3 D aN N M "$ompany *![TokinL k b k J A ResuSmi!sion Y'D f8 gt

$131b6 Year Cf R*PCM Dec. 31,1995 SALES FOR RESALE (Account 447) (Continued)

OS - for other service. Use this category only for those demand in colum (f). For all other types of service, s:rvices which cannot be placed in the above-defined enter NA in columns (d), (e) and (f). Monthly NCP demand is p c:tegories, such as att non firm service regardless of the the maxinus metered hourly (60-minute integration) demand

() tength of the contract and service from designated units of in a month. Monthly CP demand is the metered demand less than one year. Describe the nature of the service in a during the hour (60-minute integration) in which the footnote. supplier's system reaches its monthly peak. Demand reported AD - for out of period adjustment. Use this code for any in cottans(e) and (f) must be in, megawatts. Footnote any accounting adjustments or "true-ups" for service provided demand not stated on a megawatt basis and explain.

In prior reporting years. Provide an explanation in a 7. Report in cottan (g) the megawetthours shown on bills footnote for each adjustment. rendered to the purchaser.

4. Group requirements RQ sales together and report them 8. Report demand charges in column (h), energy charges in starting at line nunter one. After listing att RQ sales, coltsm (I), and the total of any other types of charges, ent:r "Suototal - RQ" in cottenn (a). The remaining sales including out-of-period adjustments, in colunr1 (j). Explain may then be listed in any order. Enter " Subtotal-Non-RQ" in a footnote all conponents of the amount shown in coltan in esluen (a) after this listing. Enter " Total" in coltan (J). Report in cottrnn (k) the total charge shown on bills (a) as the test line of the schedule. Report subtotals and rendered to the purchaser.

tItri for columns (g) through (k). 9. The data in coltann (g) through (k) must be subtotalled

5. In coltsnn (c), identify the FERC Rate Schedule or based on the RQ/Non RQ grouping (see instruction 4), and Tirlff Nunber. On separate lines, List all FERC rate then totalled on the last line of the schedule. The schedules or tariffs under which service, as identified in " Subtotal - RQ" anount in coltam (g) must be reported as c Lumn (b), is provided. Requirements Sales For Resale on page 401, line 23. The

6. For requirements RQ sales and any type of service " Subtotal - Non RQ" amount in column (g) must be reported involving demand charges inposed on a monthly (or longer) as Non-Requirements Sales for Resale on page 401, tine 24.

basis, enter the avercge monthly billing demand in coltann 10. Footnote entries as required and provide exptanations (d), the average monthly non-coincident peak (WCP) demand following all required data.

In coltan (e), and the average monthly coincident peak (CP)

REVENUE Line Mega hours Demand arges Energ harges Other rges g ) No.

1,320,667 568,087,412 $24,473,868 53,121.092 595,682,372 1 2,696,289 135,284,617 50,058,145 8,285,028 193,627,790 2 548,095 26,841,458 9,879,357 1,437,732 38,158,547 3 l 4,565,051 230,213,487 84,411,370 12,843,852 327,468,109 4 1 5,133,509 208,348 0 0 5,133,509 5 58,658 2,510,177 1,099,891 0 3,610,068 6 16,113 1,267,179 302,414 0 1,569,593 7 28,453 0 816,830 0 816,830 8 71,281 1,389,000 2,046,591 0 3,435,591 9 90,795 1,681,413 2,623,779 0 4,305,192 10 8,625 32,700 162,371 0 195,071 11 1,260 3,059 32,974 0 36,033 12 1.570 , 12,560 18,840 0 31,400 13 2,736l 14,364 50,616 0 64,980 14 l

l FERC FORM NO.1 (ED. 12-91) Page 311 Next Page is 320 l

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fon 3 e ,

l SALES FOR RESALE (Accowit 647) r

-*t t ,

1. Report all sales for resale (f.e., sales to purchasers interr@ted for economic reasons and is intended to remain ether then uttleste consumers) transacted on a settlement rettable even under adverse conditions (e.g., the sgptier bests sther than power exchanges during the year. Do not must atteopt to buy emergency energy from third parties to ,

report eachanges of electricity ( l.e., transactions mainteln deliveries of LF service). This category should involving a belancing of debits and credits for energy, not be used for tong-term firm service which meets the '

capacity,etc.) and any settlements for labelenced exchanges definition of Re service. For att transactions identified ,

en this schedule. Power enchanges must be reported on the as LF, provide in a footnote the terminetton dote of the Purchased Power schedule (page 326-327). contract defined es the earliest date that either buyer ,

2. Enter the name of the purchaser in column (a). Do note or seller can tsilleteratty get out of the coitract. ,

abbreviate or truneste the name or use acronyms. Explain in IF - for intenmediate term firm service. The same as LF a footnote any ownership Interest or affiliation the service except that " Intermediate term" meer.s longer than reopendent has with the purchaser. one year but less then five years. (

3. In column (b), enter a statistical Classification Code SF - for short-term firm service. Use this cctegory for based on the originnt contractual terms and conditions of all firm services where the duration of each period of the service es follows: comaltment for service is one year or less.

no for reautrements service. Rowirements service is LU - for tong term service from a designated gererating service which the s gptler piens to provide on en ongoing unit. "Long tens" means five years or longer. The avait- '

bests (i.e., the sgptier includes projected load for this ability and rettability of service, aside from transatssion servica in its system resource planning). In addition, the constraints, sust match the evallability and retlebility of reliability of requirements servli.; must be the same as, or designated unit.

second only to, the supplier's service to its own uttleste IU for Intermediate-term service from a desgneted ,

consumers. generating unit. The same as LU service except that l "intermodlate-term" means longer than one year but less i LF = for long-term service. "Long ters" means five years .

er ionger and afire" means that service cannot be than five years.

Actual Demand (MW) t no ffNI 1 C -

T! r None None None i 1 NEP (1) 05 100 2 NU (1) 08 59 None None hone e 7 3 Rending Nunicipal (1) 05 ER96-847 000 Mene None Now ,

4 SugT0TAL-NON R0 5

6 7 Coet P1Le Adjustaant (6) AD None None None S I 9

10

~

11 .

s 12 * =

13  ;

15 total i +

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Page 310.1 G FERC FORM No.1 (REVISED. 12-90)

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, SALES FOR RESALE (Account 447) (Continued) 08 - for other service. Use this category only for those demand in coltan (f). For att other types of service, g services which cannot be ptoced in the above defined enter NA in coltans (d), (e) and (f). Monthly NCP demand is L categorles, such as all non firm service regardless of the the maxlaman metered hourly (60-minute integration) demand

~ ,

tength of the contract and service from designated units of in a month. Monthly CP demand is the metered demand toss than one year. Describe the nature of the service in a during the hour (60-minute Integration) _ in which the  ;

footnote. supptler's system reaches its monthly peak. Demand reported i AD - for out of period adjustment. Use thic code for any in cottans(e) and (f) must be in megewetts. Footnote any

• l .ac:ounting adjustments or "true-ups" for se wice provided demand not stated on a mege/ett basis and explain.

j. In prior .aporting years. Provide an exp. motion In a 7. Report In cottsun'(g) the .negewetthours shown on bitts footnote for each adjustment. rendered to the purchaser.

4. Grote requirements Re sales M eether and report thes 8. Report demand charges in column (h), energy charges in starting at line nuser one. After Listing att Re sales, coltan (I), and the total of any other types et charges,

! entzr "S 4 total - Ro" in coltsun (a). The remaining sales including out-of perlod adjustments, in cottsun (J). Expt:!a may then be listed in any order. Enter " subtotal Non-R0" in a footnote all conponents of the amount shown in cottsun in esttsen (a) after this list'ng. Enter " Total" In cotian (j). Report Ir. cottan (k) the total charge shown on bills (a) as the last lina of the 4ckdute. Report subtotals and rendered to the purchaser.

tat:1 for cottsuns (g) thraagh (k). 9. The date In cottan (g) through (k) must be st6 totalled

5. In coltsun (c), Identify the FERC Rate Schedule or based on the RQ/Non-RQ grouping (see Instruction 4), and Ttriff Ihauber. On separate lines, list all F3tc rate then totatted on the last line of the schedule. The schedules or tariffs under which service, as identified in " Subtotal - Roa amotet in column (g) must be reported as

. csttsun (b), is provided. Requirements Sales For Resale on page 401, line 23. The

6. For requirements RQ sales nd any type of service " subtotal - Non Rea amount in coltsun (g) must be reported involving dweend charges inposed on a monthly (or longer) as Non-Requirements Sales for Rosete on page 401, tine 24.

bests, anter the average monthly bitting demand in coltsun 10. Footnote entries as required and provide exptanettons (d), the average month'y non-coincident peak (NCP) demand

. following all required data. .

in estian (e), and the average monthly coincident peak (CP) i REVENUE 1

Line hours Demand arges Ener herges other rges g ) No.

3,475 S12,275 S66,725 579,000 1 28,114 100,479 598,487 698,966 2 120 330 2,730 3,060 3 519,548 7,023,536 12,955,757 0 19,979,293 4 5

6 0 0 267,187 0 267,187 7 8

9 10 11

, 12 13 5,084,599 237,237,023 97,634,314 12,843,852 347,715,189 14 l

)

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< P1ga 310 Lina 12 Column'a >

NOTES: (1) Short Term Opportunity Sales (hourly, daily, etc.)  ;:, j ,

(2) Montaup participates in the New England Power Pool >

(NEPOOL) which dispatches (hourly) participant generating facilities to meet pool wide demand in the msot optimum manner.

(3)'Other Charges ' = Conservation and Load Management None & Nval - such records not maintained f

(4) Adjustment to 1994 sales refunded in 1995.

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4 ih Page 310-311 Footnote.1 C y.t \

.- l MonIa'up N M e"Eayany k2h Nokin i i*k]ARisubmi!sion Sh Ob3* N96Y Dec. 31, 1995

. ELECTRIC OPERATION AND MAINTENANCE EXPENSES If the amount for previous year is not derived from previously reported figures, explain in footnotes.

ine gA Account Amount for Amount for Curr g Year Prev g Year 1 1. POWER PRODUCTICN EXPENSES 2 A. Steam Power Generation l .

3 operation l

~

4 (500) Operation Supervision and Engineering -

$1,719,759l S1,751,485 5 (501) Fuel 39,405,404l 37,061,332 6 (502) Stears Expenses 1,458,166l 1,513,260 7 (503) Steam from other sources 0l 0 8 (Less) (504) steam Transferred- Cr. 76,521l 61,337 9 (505) Electric Expenses 1,840,728l 1,857,279 10 (506) Miscellaneous steam Power Expenses 1,747,823l 1,935,595 11 (507) Rents 548,870l 396,928 12 (509) Allowance 4,062l 13 TOTAL Operation (Enter Total of Lines 4 thru 12) 546,648,291l S44,454,542 j 14 Maintenance .

l 15 (510) Maintenance Supervision and Engineering $293,988 5238,754 i 16 (511) Maintenance of structures '585,826 381,879 j 17 (512) Maintenance of Boller Plant 3,J58,283 3,542,050  !

18 (513) Maintenance of Electric Plant 1,857,154 1,350,510 l 19 (514) Maintenance of Miscellaneous steam Plant 323,109 291,492 20 TOTAL Maintenance (Enter Total of Lines 15 thru 19) $5,918,360 $5,804,685 21 TOTAL Power Production Expenses--Steam Power C.d.? Total of lines 13 and 20) $52,566,651 $50,259,227 22 B. Nuclear P m e Generation 23 Operation 24 (517) Operation 5@ervision and Engineering $1,408,498 $1,463,976 25 (518) Fuel 4,497,361 3,838,174 26 (519) Coolants and Water 105,013 111,114 27 (520) steam Expenses 699,234 785,000 23 (521) Steam from other Sources 0 0 29 (Less) (522) steam Transferred--Cr. 0 0 30 (523) Electric Expenses 173,575 158,309 31 (524) Miscellaneous Nuclear Power Expenses 1,949,746 1,982,866 32 (525) Rents 46,016 22,465 l 33 TOTAL Operation (Enter Total of lines 24 thru 32) 58,879,443 58,361,904 34 Maintenance 35 (528) Maintenance Supervision and Engineering $627,146 5545,680 36 (529) Maintenance of struetures 429,575 216,163 37 (530) Maintenance of Reactor Plant Equipnent 1,530,518 966,455 38 (531) Maintenance of Electric Plant 661,860 707,544 39 (532) Maintenance of Miscellaneous Nuclear Plant 229,928 329,311 40 TOTAL Maintenance (Enter Total of lines 35 thru 39) 53,479,027 $2,765,153 41 TOTAL Pover Production Expenses -Nuclear Power (Enter total of lines 33 and 40) $12,358,470 $11,127,057 42 C. Hydraulic Power Generation _

43 Operation 44 (535) Operation Supervision and Engineering 45 (536) Water for power 46 (537) Hydraultc Expenses 47 (538) Electric Expenses 48 (539) Miscellaneous Hydraulle Power Generation Expenses 49 (540) Rents 50 TOTAL Operation (Enter Total of lines 44 thru 49)

TERC FORM NO.1 (REVISED, 12-93) PAGE 320

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ompany fon 3 ELECTRIC OPERATION AND MAINTEMANCE EXPENSES (Continued)

N E Cur W Ye k (b) Prev he k (c) 51 C. Hydraulic Power Generation (Continued) 52 Mintenance 53 (541) Maintenance supervision and Engineering 54 (542) Maintenance of structures 55 (543) Maintenance of Reservoirs, Dams, and Waterways 56 (544) Maintenance of 'Etectric Plant 57 (545) Maintenance of Miscattaneous Hydraulic Plant 58 TOTAL Maintenance (Enter Total of lines 53 thru 57) 59 TOTAL Power Production Expenses Hydraulic Power (Enter total of lines 50 and 58) 0 0 60 D. Other Power Generation _ _ _ _ ____

61 Oper: tion 62 (546) Operation Supervision and Engineering $1,204 0 63 (5t7) Fuet 434,276 140,052 64 (548) Generation Expenses 16,737 11,355 65 (549) Miscettaneous Other Power Generation Expenses 6,663 0 66 (550) Rents 568,085 413,526 67 TOTAL Operation (Enter Total of lines 62 thru 66) 51,026,965 5564,933 68 Maintenance 69 (551) Maintenance Supervision and Engineering 0 70 (552) Maintenance of St'uctures 0 71 (553) Maintenance of r,enerating and Electric Plant 30,375 67,424 72 (551) Maintenance of Misceltsneous Other Power Generation Plant 0 73 TOTAL Mainte".ance (Enter Total of lines 69 thru 72) $30,375 567,424 24 TOTAL Power Pror'.Jction Expenses--Other Power (Enter Total of lines 67 and 73) 51,057,340 5632,357 75 E. Other Power Supply Expenses 76 (555) Purchased Power $172,003,784 $169,349,104 77 (556) System control and Load Olspatching 1,948,794 2,082,846 78 (557) Other Expenses 11,110,996 15,465,141 79 TOTAL Other Power Supply Expenses (Enter Total of lines 76 thru 78) $185,063,574 $186,897,091 80 TOTAL Power Production Expenses (Enter Total of lines 21,41,59,74,and 79) S251,046,035 5248,915,732 81 2. TRANSMIS$10N EXPENSES M 82 Operation 53 (560) Operation Supervison and Engineering $336,212 $220,992 84 (561) Load Dispatching 319,970 330,804 85 (562) Statton Expenses 396,617 405,945 86 (563) Overhead Lines Expenses 188,210 185,285 1 87 (564) Underground Lines Expenses 0 0 88 (565) Transmission of Electricity by Others 1,296,341 1,454,253

~89 (566) Miseetianeous Transmission Expenses 37,728 19,297 90 (567) Rents 11,169.913 9,875,761 91 TOTAL Operation (Enter Total of lines 83 thru 90) $13,744,991 512,492,337 92 Maintenance 93 (568) Maintenance S@ervision and Engineering $5,599 $8,196 94 (569) Maintenance of Structures 1,306 1,879 95 (570) Maintenance of Station Equipment 300,326 268,669 6 (571) Maintenance of overhead Lines 245,220 324,548 97 (572) Maintenance of Underground Lines 0 0 98 (573) Maintenance of Miscellaneous Transmission Plant 81,356 88,038 99 TOTAL Maintenance (Enter Total of lines 93 thru 98) 5633,809 5691,330 100 TOTAL Transmisalon Expenses (Enter Total of lines 91 and 99) $14,378,800 $13,183,667 101 3. DISTRIBUTION EXPENSES _

102 Operation 103 (580) operation Supervision and Engineering l FERC FCRM No.1 (REVISED.12 93) PACE 321

'o a b b onpany

)

ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)

Lg Aegt C r P s er 104 3. DISTRIBUTION Expenses (Continued) 105 (581) Load Dispatching 106 (582) Station Expenses (583) Overhead Line Expenses 107 108 (584) Underground Line Expenses 109 (585) Street Lighting and Signal System Expenses 110 (586) Meter Expenses til (587) Customer InstalLattons Expenses 112 (588) Miscettaneous Expenses 113 (589) Rents 114 TOTAL Operation (Enter Total of lines 103 thru 113) 115 Maintenance 116 (590) Maintenance Supervision and Engineering M

I' 117 (591) Maintenance of structures 118 (592) Maintenance of Station Equipment 119 (593) Maintenance of Overhead Lines I 120 (594) Maintenance of Underground Lines 121 (595) Maintenance of Line Transformers 122 (596) Maintenance of Street Lighting and Signal Systems 123 (597) Maintenance of Meters 124 (598) Maintenance of Miscellaneous Distribution Plant 125 TOTAL Maintenance (Enter Total of lines 116 thru 124) 126 TOTAL Distribution Expenses (Enter Total of Lines 114 and 125) 127 4. CUSTOMER ACCOUNTS EXPENSES 128 Operation 129 (901) Supervision 130 (902) Meter Reading Expenses 131 (903) Customer Records and Collection Expenses 132 (904) Uncollectible Accounts 133 (905) Miscellaneous Customer Accounts Expenses 134 TOTAL Customer Accounts Expenses (Enter Total of lines 129 thru 133) 135 5. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES 136 Operation 137 (907) Supervision 138 (908) Customer Assistance Expenses 139 (909) Information and Instructional Expenses 140 (910) Miscellaneous Customer Service and Information Expenses 141 TOTAL Cust. Service and Informational Exp.(Enter Total of lines 137 thru 140) 142 6. SALES EXPENSES l

143 operation I 144 (911) Supervision i 115 (912) Demonstrating and Selling Expenses 146 (913) Advertising Expenses 147 (916) Miscellaneous Sales Expenses 118 TOTAL Sales Expenses (Enter Total of lines 144 thru 147) 149 7. ADMINISTRATIVE AND GENERAL EXPENSES 150 151 Operation (920) Administrative and General Salaries 54,112,174

[

53,914 / 11 152 (921) Office Supplies and Expenses 569,260 715,265 153 (Less) (922) Administrative Expenses Transferred--Credit 106,599 97,067 f ERC F0;M NO.1 (REVISED.12-93) PACE 322

D a'up $ N "bompany N AResubmi i h)'k]Yokin!slon

',2

'I k'h3f796@

C

• • *E '

Dec. 31,1995 ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued) ~',

Y (a)

Y t(ESSear P

$* Seer 154 7. ADMINISTRATIVE A W CENERAL EXPENSES (Continued) 155 (923) Outside Services Employed ($1,233,441) 5928,175 156 (924) Property Insurance 687,113 656,019 157 (925) Injuries ord Damages 1,351,227 2,323,335 158 (926) Esployee Pensions and senefits 5,588,603 4,121,884 159 (927) Franchise Requirements 0 0 160 (928) Regulatory Commission Expenses 829,350 715,756 161 (929) (Less) Duplicate Charges--Cr. 0 0 162 (930.1) General Advertising Expenses 10,375 12,628 163 (930.2) Miscellaneous General Expenses 403,333 688,694 164 (931) Rents 354,052 509,383 1J TOTAL Operation (Enter Total of lines 151 Thru 164) S12,565,447 S14,388,483 166 Maintenance 167 (935) Maintenance of General Plant $172,621 S205,461 fb$er N'of* S N *k6 W "*** $12,738,068 S14,593,944 fN$er $a of s k , N ,5l "I D I, rM168) S278,162,903 S276,693,343 NUMBER OF ELECTRIC DEPARTMENT EMPLOYEES

1. The data on runber of esployees should be reported for construction employees in a footnote.

the payroll period ending nearest to October 31, or any 3. The runber of enptoyees assignable to the electric payrstt period ending 60 days before or af ter October 31. department from joint functions of combination utilities may

2. If the respondent's payroll for the reporting period be dete mined by estimate, on the basis of enployee equi-includes any special construction personel, include such valents. Show the estimated nunber of equivalent enptcyees esployees or line 3, and show the runber of such special attributed to the electric department from joint fmettons.

1. Payroll P triod Ended (Date) 12/31/95

2. Tztal Regu?ar Fult Time Esployees 99

3. T4til Part-Time and Temporary Employees 0

4. Tit;l Employees 99 u

/

E FERC FORM No.1 (ED. 12 95) PACE 323 Next Page is 326 L 4 .

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NEXT PAGE IS 326 i

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. . -- ..- - -..~ -__ - _ . - _ . - . - - . . _ . - . - - - - . . - . - - -

lon 13 Dec ,

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1. Report att power purchases made during the year. (so long-term firm service which meets the definition il of to service. For all transactions identified report exchanges of electricity (i.e. transactions involving a botancing of debits and credits for as LF, prov{de in a footnote the terminetton date energy, capacity, etc.) and any settlements for of the contract. defined as the earliest date that febatenced exchanges. either buyer or setter can tmitaterally get out

2. Enter _the name of the setter or other party in an of the tontract, i

' exchange transaction in colten (a). Do not abbreviste  ;

or trtsicate the name or use acronyms. Explain in e IF - for Intermediate term fire service. The same as  !

footnote any ownership Interest or affiliation the LF service expect that " Intermediate-ters" means j reopendent has with the setter. Longer than one year but less than five years.

3. In cotuen(b), enter a statistical classification Code ,

based on the original contractual terms d SF - for.short term service. Use this category for l .

conditions of the service as foltous: ett firm services, where the daration of each period "j of commitment for service is one year or less. l Re - for requirements service. Requirements service is service which the styptier plans to provide on an LU - for tong term service from a designated .

ensoing basis (1.e., the styptier includes projected generating smit. "Long-tern a means- five years or -

load for this service in its system resource longer. The avellability and rettability of service,  :

planning). In addition, the rettablility . of eside from transmission constraints, must match the ,

regulroment service must be the same as, or second eveltability and reliability of the designated unit. ,

only to, the supplier's service to its own ultimate  ;

'constaners. IU - for Intermediate term service from a designated j generating unit. The same as LU service expect that .

LF - for long term firm service. "Long-term" means five "Intermodlate-ters" means longer than one year but years or tonner and " firma means that service cannot less than five years.  !'

be interrupted for economic reasons and is intended ,

to reseln reliable even under adverse conditions EX - For exchanges of electricity. Use this category ,,.l (e.g., the supplier must attempt to buy emergency .for transactions involving a belancing of debits and  ;

I energy from third parties to maintain deliveries of credits for energy,capactty, etc. and any settlements '4 LF service). This category should not be used for for labelanced exchanges.

• ver Actual Demand (NW) u !

Stgtlett-bi

( no A b[ms) T r .

(e) (b) (c) (d) ( (

1 Connecticut Yankee LU 1 NONE N/A N/A 2 Maine Yankee LU 1 NOME N/A N/A 3 Yankee Atomic LU 1 NONE . M/A N/A ,

4 V;rmont Yankee LU 1 NONE N/A N/A 5 soston Edison Pilgrim #1 LU NDPU-17445 NONE N/A N/A 6 surtington LU N/A NONE N/A N/A j.

7 Come Electric - Canal #1 LU FPC #2 NONE N/A N/A }  !

8 Taunton-Cleary 39 C.C. LU 85 NONE N/A N/A  ;

9. IsaEC Stoney Brook #2a/2s LU 81 39.7 N/A N/A  !

10 Braintree Potter #2 LU 86 40 N/A N/A i 11 NEP Nisc Units IU NEPW324 NONE N/A N/A 2 12 Ocean State #1 LU 3 NONE N/A N/A 13 Ocean State #2 LU 7 NONE N/A N/A g. ., ,

14 NIrtheast Energy LU (1) NONE N/A N/A [.,5 {

a '

i 3

7ERC FORN N0.1 (REVISED 12-90) PAGE 326 p).'

D:

. _ . . .. ~ . - - .. - . _. -_ - -- - - . _ _ ~ _ - - ---.~~-._.~ - _

2

" Mion 3 D PURCMAgg g y Aeg tj5j g tinued)

, 05 for other service. Use this category only for those coluurts (e) and ( f) must be in megauetts. Footnote any services which cannot be placec in .the above-defined demand not stated on a megawatt basis and explain.

categories, such as all nonfirm service regardless of the 6. Report in column (g) the negauetthours shown on bitts Length of the contract and service from designated units rendered to the respondent. Report in column ( h) and (1) cf less than one year. Describe the nature of the servfce the negawatthours of power exchanges received and delivered, in a footnote for each edjustaent. used as the hasia for sett1ement.De not report not exchange.

7. Report demand charges in col m (J), energy charges in j AD for,out of period adjustment. Use this code for any column (k), and the total of any other types of charsee, I assounting adjustments or strue-spsa for service provided including out of period adjusteents, In cotuuri (1), Explain in prior reporting years. Provide an explanation in a in a footnote att components of the anomt shown in cotuun

4. footnote for each adjustment. (1). Report in column (m) the total charge shown on bills In cottan (c), identify the FERC Rate Sche &te Number or received as settlement by the -respondent, For power J. .

Ttriff,or,fornonFERCjurledlettonet setters, include an exchanges, report in column ('A) the settlement amount for l appropriate designation for the contract. On separate lines, the not receipt of energy.If more energy uns delivered than

. List att FERC rate schee tes, tariffs or contract designe- received, enter a negative amount. If the settlement amount l tions under which service, as identified in cottari (b), is (1) include credits or charges other than incremental '

5. provided. generation expenses, or (2) excludes certain credits or Far respirements Re purchases and any type of services charges covered by the agreement, provide en explanatory Involving demand charges japosed on a monthly ( or longer) footnote.

basis, enter the monthly ' average bitting demand In column 8. The data in coltart (g) through (m) must be totetted on the j (d), the average monthly non- coincident peak (NCP) demand last line of the schedule. The total anotsit in column (g) 1 in column (e), and the average monthly coincident peak (CP) must be reported as Purchases on page 401, ifne 10. The demand in cottart (f). For att other types of service, enter total amount in column (h) sust be reported as Exchange NA in coluuns (d), (e) and (f). Monthly NCP demand is the Received on page 401, line 12. The total amount in column anximum metered hourly (60 minute Integravon) cemand in a (i) must be reported as Exchange Delivered on page 401,

- month. Monthly CP demand is the metered demarmi during the Line 13.

hour (60-minute Integration) In idi!ch the supptler's 9. Footnote entries as required and provide explanations system reaches its monthly peak. Demand reported in foltoulns att required date.

I POWER EXCHANGES COST /gETTLE9ENT OF poler M

• YN

• EN@ Sf*** N) * *** Sf'*** of N t M $) Line

(:) (h) (I) (j) (k) (t) (m) l 164,793 $8,651,277 $861,355 -$9,512.632 1 j

7,083 T,302,783 161,683 7,464,466 2 0 2,010,272 55,369 2,065,641 3 86,817 3,615,024 444,851 4,059,875 4 493,443 37,914,842 2,246,131 40,160,973 5 l 2,653,141 832,443 3,485,584 6 I 20,719 235,644 8,279,939 5,463,512 13,743,451 7 14,401 0 373,233 373,233 8 5,915 4 % ,320 270,642 766,962 9 50,173 888,000 1,155,645 2,043,645 10

~

20,829 1,185,824 543,997 1,729,821 11 449,736 21,629,204 4,148,985 25,778,189 12 449,730 23,273,017 4,314,124 27,587,141 13 216,688 7,085,066 6,984,123 14,069,189 14 l

y l

FERC FORM No.1 (REVISED 12 90) PAGE 327

% W-l 1

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blon 3 0 ,

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1. Report all power purchases made during the year. Lso AM $} '

long-term firm service which meets the definition

-report exchanges of electricity (i.e. transactions of Re service. For att transactions identified '

frwolving a belancing of debits and credits for as LF, provide in a footnote the terminetton date t' energy, capacity, etc.) and any settlements for of the contract defined as the eartfest date that inhelanced exchanges. either buyer or setter can mitaterally set out

2. Enter the name of the setter or other party in an of the contract.

exchange transaction in coltan (a). Do not abbreviste or truncate the name or use acronyms. Explain in a IF - for intermodlate-term firm service. The same as footnote any ounership interest or affiliation the LF service expect that "InterneIlate-term" means

.- , - has with the setter. tonger than one year but less than five years.

l 3. In column (b), enter a statistical Classification Code bened on the originnt contractunt terms and SF - for short-term service. Use this category for ,

conditions of the servlee as fottows: att firm services, where the duration of each period

• of comaltment for service is one year or less. ~*

Re - for requirements service. Requirements ~ service is service which the staplier plans to provide on an LU - for long term service from a designated '

ongoing beste(f.e., the supptfor Includes projected generating unit. "Long-ters" means five years or .

load for this service in its system resource longer. The avsflability and reliability of service, planning). In addition, the reliablltity of aside from trenamission constraints, must match the ,.

requirement service must be the same es, or second availability and rettability of the designated unit.  :

only to, the supplier's service to'Its own uitlante consumers.

IU - for intermediate-term service from a desl eeted generating unit. The same as LU service expect that LF - for long term firm service. "Long terna means five " intermediate-term" means tonger then one year but .

years or longer and " firma means that service cannot less than five years.

be interrteted for economic reasons and is intended to remain reliable even under adverse conditions EX - For exchanges of electricity. Use this category (s.g., the supplier must attempt to buy emergency for transactions involving a botancing of debits and

• energy from third porties to maintain deliveries of credits for energy,cepecity, etc. and any settlements LF servlee). This estegory should not be used for for labelanced exchanges.

stgtisti. ver -

Actunt Demand (NW) b'.

( A b[ms) ITo* T r [g k plackstone Hydro (a) (b) (c) (d) (e) h(f) 4 1 os 1 NOME N/A N/A e 2 GNP Peakers NONE N/A N/A 3 NEP system Exel OS EL 92 91-000 NONE N/A N/A NU Syst Exel 4 05 59 NOIE N/A I N/A 5 Louis Dreyfus NOME N/A N/A 6 CIEEC NOME N/A N/A ..

T UI 08 101 NONE N/A N/A

~'

8 CIF NOME N/A N/A D 9 Niagra Mohawk NOME N/A N/A 10 CVP5 NONE N/A N/A 11 er system Exel NONE N/A N/A g 12 EPMI NONE N/A N/A 13 CVE MONE N/A N/A 14 Central Nudson NONE N/A N/A ghi

.1 f ,n c

FERC FORM No.1 (REVISED 12 90) PAGE 326.1 "

l rb d

I

s N Eaup lI! N honpany """

u j k* JYAYohi

1. 'E '

A Resulrr[ssl ion $'*f3f796@'

N Dec. 31,1995 PURCHAS gA tj$jgor tinued) 05 - for other service. Use this category only for t',ose columns (e) and ( f) must be in megawatts. Footnote any services which cannot be placed in the above-de fined demand not stated on a megawatt basis and explain.

categories, such as all nonfirm service regardless o1 the 6. Report in coltmin (g) the megawatthours shown on bills length of the contract and service from design ted units rendered to the respondent. Report in cottain ( h) and (I) cf less than one year. Describe the nature of the service the megawatthours of power excha.N es received and delivered, in a footnote for each adjustment. used as the basis for settlement.co not report net exchange.

7. Report demand charges in colum (J), energy charges in AD - for out of period adjustment. Use this code for any column (k), and the total of any other types of charges, accounting adjustments or "true-ups" for service provided including out of period adjustments, in coltsrn (1), Explain in prior reporting years. Provide an explanation in a in a footnote all conponents of the amount shown in column

4. footnote for each adjustment. (L). Report in cottmin (m) the total charge shown on bills In cotum (c), Identify the FERC Rate Schedule Ntaber or received as settlement by the respondent. For power Tariff, or, for nonFERC jurisdictional setters, include an exchanges, report in cotum (m) the settlement amount for appropriate designation for the contract. On separate lines, the net receipt of energy.If more energy was delivered than list att FERC rate schedules, tariffs or contract designa- received, enter a negative amomt. If the settlement amount tions trider which service, as identified in column (b), is (1) include credits or charges other than incrementat

5. provided. generation expenses, or (2) excludes certain credits or for requirements RQ purchases and any type of services charges covered by the agreement, provide en explanatory involving demand charges imposed on a monthly ( or longer) footnote.

basis, enter the monthly everage bitting demand in column 8. The data in column (g) through (m) must be totatted on the (d), the average monthly non- coincident peak (NCP) demand test line of the schedute. The total amount in column (g) in colum (e), and the average monthly coincident peak (CP) must be reported as Purchases on page 401, line 10. The demand in coltmin (f). For all other types of service, enter total amount in column th) must be reported as Exchange NA in colums (d), (e) and (f). Monthly NCP dema.t! (S the Received on page 401, line 12. The total amount in cottmin maxinun metered hourly (60-minute intep ction) demand in a (1) must be reported as Exchange Delivered on page 401, month. Monthly CP demand is the metered demand during the line 13.

hour (60 minute integration) in 6Alch the supptfer's 9. Footnote entries as required and provide explanations system reaches its monthly peak. Demand reported in following all required data.

POWER EXCHANCES COST / SETTLEMENT OF POWER W $a

• Nehef" Yh $f' " "*3) U" Sf' " of eItl $) Line No.

(g) (h) (1) (J) (k) (l) (m) 0 $377,813 0 $377,813 1 123 47,875 8,891 56,766 2 28,070 0 712,170 712,170 3 49,875 0 1,392,842 1,392,842 4 24,739 0 639,875 639,875 5 50 0 1,080 1,080 6 13,550 0 384,300 384,300 7 14,581 0 412,901 412,901 8 62,897 0 1,613,309 1,613,309 9 2,095 0 51,080 51,080 10 1.M5 0 41,120 41,120 11 16,693 0 476,443 476,443 12 3,483 0 91,440 91,440 13 1,833 0 54,200 54,200 14 fERC FORM No.1 (REVISED 12-90) PACE 327.1

i!ston 3 ,

M Nuhn po e!En k .

1. Report att power purchases made during the year, tso long-term firm service which meets the definition report exchanges of electricity (f.e. transactions of RQ service. For att transactions identified involving a balancing of debits and credits for as LF, provide in a footnote the termination date energy, capacity, etc.) and any settlements for of the contract defined as the earliest date that labetenced exchanges. either buyer or setter can unilateralty get out

2. Enter the name of the setter or other party in an of the contract.

exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a IF - for intermediate term firm service. The same as footnote any ownership Interest or affiliation the LF service expect that " Intermediate-ters" means respondent has with the setter. Longer than one year but less than five years.

3. In cotter >(b), enter a Statistical Classification Code based on the original contractuet terms and SF - for short term service. Use this category for conditions of the service as follows: att firm services, where the duration of each period of comunitment for service le one year or less.

Rg - for requirements service. Requirements service ,

lo service which the stpptler plans to provide on an LU - for long term service from .a designated ongoing basis (f.e., the supptler includes projected generating unit. "Long-ters" means five years or toed for this service in its system resource longer. The availability and rettability of service, planning). In addition, the rettablility of aside from transmission constraints, must match the ,

requirement service nust be the same as, or second avaltability and rettability of the designated ts11t.  !

only to, the supptler's service to its own uttleste l consumers. IU - for Intermediate-term service from a designated l generating unit. The same as LU service expect that I LF - for tong-term firm service. "Long-term" means five " Intermediate-terna means longer than one year but years or longer and " firma means that service cannot less than five years. j be Interrupted for economic reasons and is Intended ts remain rettable even under adverse conditions Ex - For exchanges of electricity. Use this category .

1. ~

(c.g., the supplier must attempt to buy emergency for transactions involving a balancing of debits and energy from third parties to maintain deliveries of credits for energy, capacity, etc. and any settlements LF service). This category should not be used for for imbalanced exchanges.

Actunt DemandOW) G St{ttsM-1 verge

( A [rts) I}*o

~

T!

r 4g i

(a) (b) (c) (d) (e) () .

1 Come Electric Syst NONE N/A N/A N 2 Elec Clearinghouse NONE N/A N/A 3 Uniti~t-Greatsay NONE N/A N/A 4 NU Stice of Syst IF 446 NONE N/A N/A 5 Nepoot OS 8/10 NONE N/A N/A 0

R' T

8 9

10 11 vf' 12 13 g 14 TOTAL 5:.

=

Op G.

D FERC FORM NO.1 (REVISED 12 90) PAGE 326.2 4

u

g.

(. lon 3 ,

PURCHASED POWEB (Account 555) (continued)

(Including power exchanges) ,

OS - for other service. Use this category only for those coltams (e) and ( f) must be in megawatts. Footnote any services which cannot be placed in the above-defined demand not stated on a megawatt basis and explain.

categories, such as att nonfirm service regardless of the 6. Report in colum (g) the megawatthours shown on bitts length of the contract and service from designated tnits rendered to the respondent. Report in cottan ( h) and (1) cf less than one year. Describe the nature of the service the megawatthours of power exchanges received and delivered. l In a footnote for each adjustment. used as the basis for settlement.Do not report net exchan6E. ,

7. Report demand charges in cottan (J), energy charges in l AD

• for out of-period adjustment. Use this code for any colunut (k), and the total of any other types of charges, i o ac:ounting adjustments or atrue tes" for service provided including out of period adjustments, in colism (L), Explain in prior reporting years. Provide an explanation in a in a footnote att conponents of the emotsit shown in column

4. footnote for each adjustment. (L). Report in cottan (m) the total charge shown on bills In c:ttan (c), Identify the FERC Ra,te SchedJte Nunber or received as settlement by the respondent. For power Tariff, or, for nonFERC jurisdictional setters, include an exchanges, report in coltan (m) the settlement amount for appropriate designation for the contract. On separate lines, the not receipt of energy.If more energy was dettvered than list att FERC rate schedules, tariffs or contract designa- received, enter a negative amount. If the settlement amount tions mder which service, as identified in cotum (b), is (1) include credits or charges other than incremental

5. provided. generation expenses, or (2) excludes certain credits or F:r requirements RQ purchases and any type of services charges covered by the agreement, provide an explanatory

.. Involving demand charges imposed on a monthly ( or tonger) footnote.

basis, enter the monthly everage bitting demand in cottan 8. The data in coltsun (g) through (m) must be totatted on the l (d), the average monthly non- coincident peak (NCP) demand test Line of the schedule. The total asomt in cottan (g)

In colum (e), and the average monthly coincident peak (CP) must be reported as Purchases on page 401, line 10. The demand in cottsm (f). For att other types of service, enter total amount in cottan (h) mus. be reported as Exchange NA In cottans (d), (e) and (f). Monthly NCP demand is the Received on page 401, line 12. The total amotnt in coltan maxim a metered hourly (60-minute Integration) demand in a (1) must be reported as Exchange Delivered on page 401, month. Monthly CP demand la the metered demand chring the line 13.

hour (60-minute integration) in which the supptler's 9. Footnote entries as required and provide explanations system reaches its monthly peak. Demand rep.rted in following all required data, j l

POWER EXCHANGES COST / SETTLEMENT OF POWER W3W* "'IntiPeF' 9 :M 2 ' 9 :1" '' "N >**'" **sihana

( of $ L g ]S) Line No.

(g) (h) (1) (J) (k) (t) (m)  ;

375 $7,125 $7,125 1 4,800 89,750 89,750 2 1,313 12,960 29,495 42,455 3 0 37,860 0 37,860 4 572,949 (1,150) 12,681,603 12,680,453 5 6

7 8

9 10 11 12 13 3,015,332 0 0 125,460,067 46,543,717, 0 172,003,784 14 FERC FORM No.1 (REylSED 12-90) PAGE 327.2

Na#up N'e N kompany *!I ujk)P20hT*InaAResu$ Yb I Y'*

mission Oh31I96

" " " '*P '*

Dec. 31, 1995 4, ,

EEng1 ram!bohrNrN!! M7eeth) *

1. Report all transmission of electricity, f. e. wheeling, 4. In colunn(d) enter a Statistical Classification code provided for other electric utilities, cooperatives, based on the original contractual terms and conditions samlefpalities, other put:!Ic authorftles, qualifying of the service as follows:

['

P facilities, non-traditional utility supptfers and ultimate customers. LF for long-term firm transmission service. "Long term"

2. Use a separate line of data for each distinct type of means one year or longer and " firma means that service transmission service involving the entitles ilsted In cannot be interrteted for economic reasons and is cituun (s), (b) and (c). Intended to remain rettable even under adverse con-

3. Report in coluun (a) the company or pubtle authority ditions. For all transactions identified as LF, provide that paid for the transmission service. Report in in a footnote the termination date of the contract calumn(b) the company or public authority that the defined as the earliest date that either buyer or energy was received from and in column (c) the company setter can unilaterally get out of the contract.

or ptelle authority that the energy was delivered to. I Provide the full name of each company or pubtle SF - for short term firm transmission service. Use this l authority. Do not abbreviate or truncate name or use category for all firm services, where the duratlon I scronyum. Explain in a footnote any ownership Interest of each period of consnitment for service is less than in or affillation the respondent has with the entitles one year. .

Listed in cottans (a), (b) or (c).

i N En INMl'#' oon$ f oEl'#' i #'

1 Middleboro Municipal (1) Middleboro Municipal OS 2 Nepool ENV/LF PTF various Units / Companies Nepool ENV/LV-PTF (Fed District) OS 3 Pascoag Fire District NYPA Hydro (PASNY) Pascoag Fire District OS 4 New England Power Company various Units / Companies New England Power (Tiverton) LF 5 Hudson Light & Power Taunton Municipal Mudson Light & Power OS 6 MWEC NYPA Hydro (PASNY) Ig4WEC (Piddleboro & Taunton) LF 7 graintree Electric Department Taunton Municipal graintree Electric Department OS l

8 Mingham Municipal Lighting Plant Tamton Municipal Hingham PMnicipal Lighting Plant OS 9 N Attleboro Electric Department Tamton Municipal N Attleboro Electric Department OS 10 goston Edison Company Pilgrim ! Middleboro Municipal 05 l

11 ALTRESCO ALTRESCO Come Electric & Cambridge Elec OS 12 Mass Power Mass Power Coninonwealth Electric OS j 13 Tomton Municipal Lighting Plant Various Units / Companies Tamton Mmicipal Lighting Plant OS 14 Maine Electric Power Co Not Applicable (2) Not Applicable 05 15

^ 16 TOTAL 17

• M TERC FORM NO.1 (REVISED 12-90) PAGE 325 -

s

h:

Nogany E Mon R bon 3 6 D n'hudng N N} ekbekN'aNhh!N OS - for other transmission service. Use this category as identified in colmn (d), is provided.

only for those services which cannot be placed in 6. Report receipt and delivery locations for att single the above-defined categories, such as att nonfirm tran- contract path, " point to point" transmission service.

smission service, regardless of the length of the In column (f), report the designation for the substa-contract. Describe the nature of the service in a tion, or other appropriate identification for where energy was receivM as specified in the contract. In footnote.

colunn (g) report the designation for the substation, AD - for out of-period adjustment.Use this code for or other appropriate identification for where energy a for service was delivered as specified in the contract, any accounting adjustments or "true-ups provided in prior reporting years. Provide an explana- 7. Report in colmn(h) the rasnber of megawatts of bitting tion in a footnote for each adjustment.

demand that is specified in the firm transmission service contract. Demand reported in colum (h) must

5. In column (e), Identify the FERC Rete Schedule or Tariff Nueer. On separate lines, list att FERC rate be in megawatts. Footnote any demand not stated on a schedules or contract designations trxier which service, megawatts basis and explain.

TRANSFER OF ENERGY T r

)

N e2 0 0 14,507 1 40 Various ;oints Wareham St Sub 0 0 0 2 FPC #2 Various Points Various Points 0 0 17,769 3 64 Various Points Mass /R1 LIne 0 0 81,306 4 Various Points Tiverton Tap O 0 4,801 5 Hudson, Ma. 0 14 Various Points 55,073 6 0 0 83 Various Points Various Points 0 0 9,602 7 60 Various Points E Braintree, Ma.

0 0 2.881 8 78 Various Points Hingham, Ma.

0 0 9,602 9 72 various Points N Attleboro, ma.

0 0 4,687 10 84 Various Points Auburn St sub 0 0 437,210 11 106 various Points High HILL Sub 0 0 375,275 12 107 Various Points High Hitt Sub 0 0 0 13 F rc C2 Various Points Taunton Sub 0 0 0 14 FPC #16 Various Points Not Applicable (2) 15 0 1,012,713 16 l

17 l

PAGE 329 FERC FORM NO.1 (REVISED 12 90)

I lon 3 e , 995 TRANSMISSION OF ELECTRICITY FOR OTNERS (Accomt 456)(continued) 1 ', q (Including transactions referred to as " wheeling")

8. Report in column (1) and (j) the total megawatthours shown on bitts rendered to the entity listed in column ,.; I received and delivered. (a). If no monetery settlement was made, enter zero

9. In coluun (k) through (n), report the revenue anomts ("0") In column (n). Provide a footnote explaining the ,

as shown on bitts or vouchers. In colum (k), provide - nature of the norunonetary settlement, including the '

revenues from demand charges related to the bitting amount and type of energy or service rendered.

demand reported in colum (h). In colum (L), provide 10. Provide total amounts in coluun (1) through (n) as the revenues from energy charges related to the amount of test line. Enter " TOTAL" in column (a) as the last energy transferred. In colum (m), provide the total line. The total amounts in columns (1) and (j) sust be l revenues from att other charges on bills or vouchers reported as Transmission Received and Dettvered on page rendered, including out of period adjustments. Explain 401, lines 16 and 17, respectively.

l In a footnote att components of the amount shown in 11. Footnote entries and provide explanations following  ;

cotuun (m). Report in column (n) the total charge att required data.

REVENUE FROM TRANSMIS$10N OF ELECTRICITY FOR OTHERS l Demand arges harges Ener Lg

^

othe herges Tota ($)

0 0 $74,259 $74,259 1 0 0 165,767 165,767 2 0 0 24,178 24,178 3 0 0 154,854 154,854 4 0 0 34,368 34,368 5 0 0 119,818 119,818 6 0 0 34,404 34,404 7 0 0 10,321 10,321 8 0 0 68,736 68,736 9 0 0 13,718 13,718 10 r 0 0 606,220 606,220 11 0 0 1,489,376 1,489,376 12 0 0 11,456 11,456 13 0 0 19,881 19,881 14 15 0 0 2,827,356 2,827,356 16 17 2

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.< Pega 328 Lino 17 Column A >

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., NOTES:

S (1) 115KV Radial, Maine Yankee, Vermont Yankee, Enron, EUA, & NU  !

(2) Per MEPCO Participation Agreement effective 6/20/69, Montaup participates in the interconnection between Wiscasset, Maine and Keswick. Revenues or charges are ,

based upon "line use revenues" vs "line expenses" and l are unpredictable. Ducing 1995 Montaup-received both-revenues and charges'.

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ssion 3 D , q TRANSMISSION OF ELECTRICITY SY OTHERS (Account 565) ..

(Including transactions referred to as " wheeling")

1. Report all transmission, f.e., wheeting, of elec- colum (f), provide the total of att other charges on tricity provided to respondent by other electric utili- bills or vouchers rendered to the respondent, including ti:s, cooperatives, municipalities, er other pubtle any out of period adjustments. Explain in a footnote all authorftles during the year. conponents of the amount shown in colunn (f). Report in

2. In cotlan (a) report each company or pubtle autho- colunn (g) the total charge shown on bills rendered to the rity that provided transmission service. Provide the full respondent. If no monetary settlement was made, enter zero name of the company; abbreviate if necessary, but do not ("0") in cotum (g). Provide a footnote explaining the truncate name or use acronyms. Explain in a footnote any nature of the nonmonetary settlement, including the amount ownership interest in or affiliation with the transmission and type of energy or service rendered.

service provider. 6. Enter " TOTAL" in column (a) as the test line. Prov{de

3. Provide in column (a) subheadings and clessify trans- a total amount in cottans (b) through (g) as the test line.

nission service purchased from other utilities as: "Dett- Energy provided by the respondent for the wheeler's vered Power to Wheeler" or " Received Power from Wheeler." transmission losses should be reported on the Electric

4. Report in columns (b) and (c) the total megawatthours Etergy Account, page 401. If the respondent received power reestved and delivered by the provider of the transmission from the wheeler, energy provided to account for losses service. should be reported on line 19. Transmission By others

5. In colunns (d) through (g), report expenses as shown Losses, on page 401. Otherwise, tosses should be reported on bitts or vouchers rendered to the respondent. In cottan on line 27, Total Energy Losses, page 401.

(d), provide demand charges. In colum (e), provide energy 7. Footnote entries and provide explanatfons following charges related to the anotat of energy transferred. In all required data.

TRANSFER OF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS

( k ons) oE' k s Ns C s sfo (a) e; kg 1 Maine Yankee Atomic 7,083 5214,235 S214,25 2 V:rmont Yankee Nuclear 86,817 60,549 6J,549 3 Boston Edison Company 493,443 18,790 18,790 4 Northeast Utilities 164,793 52,036 52,036 5 Maine Electric Power 310 310 6 NEP00L ENV/LV PTF 582,676 582,676 7 New England Power 17,045 187,827 187,827 8 surlington Electric 20,719 179,918 179,918 l f i o 1 10 0 11 TOTAL 789,900 0 0 0 1,296,341 1,296,341 l 12 0 13 0 14 0 15 0 16

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FERC FORM No.1 (REVISED. 12-90) Page 332 w

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< Paga 332 Linn 16 Column a >

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Megawatthours s Received Maine Yankee (1)

Vermont Yankee (1)

Boston Edison (1)

Northeast Utilities (1)  :

Maine Electric (2) (3) l NEPOOL (2) i New England (1) -

'. Burlington Electric (1)

(1) These MWH are already included in total Purchased Power (page 327A) t (2) MWH not available - only transmission charges apply {

(3) Per MEPCO Participation Agreement effective 6/20/69, i

Montaup participates in the interconnection between Wiscasset, Maine and Keswick, New Brunswick. Revenues or charges are based upon "line use revenues" vs "line expenses" and are unpredictable. During 1995 Montaup received both revenue (acct 456, P330) and charges above.

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1 P e W Page 332 Footnote.1 f

k R Yssion 3 oc 3,  : .: c MISCELLANEOUS GENERAL EXPENSE 5 (Account 930.2)(ELECTRIC) , .i gne Desegtion gt ~

! -1 Irukastry Association Dues $119,330 .

2 Nucteer Power Research Expenses 3 Other Experleental and General Research Expenses Nk WO Eh $ N !icf N sY N I!d k N YIle!'$h*t E Ae

'b o h'I! E sY'G!'o k a b t N I kess*!kat Eh k k N s N k t E E r of I$ N S 6

7 EUASC 156,648 8 CANAL 2 36,428 9 EMPLOYEE TRAINING 51,628 10 MILLSTONE 3 13,056 .

11 MISCELLANEOUS 410 12 SEABROOK 25,733 13 CORP & FISCAL EXPENSES 100 .

14 15 16 17 'y -

18 19 20 l

21 <

22 23 24 25 l 26 27 28 ,*

30 ,

31 1 32 ,

33 34 .

35 .

36 II i::

38 39 40 41 42 4 43 44 .

45 [j; 46 TOTAL $403,333

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FEEC FORM NO.1 (ED.12-94) Page 335 Tf.~

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mpany g 3 DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Accounts 403, 404, 405)

(Except amortfration of acquisition adjustments)

1. Report in section A for the year the amounts for: classifications and showing a composite total. Indicate (a) Depreciation Expense (Accomt 403); (b) Amortization at the bottom of section C the manner in which colmn cf Limited Ters Electric Plant (Account 404); and (c) balances are obtained. If everage balances, state the Amortitation of Other Electric Plant (Account 405). method of averaging used.

2. Report in section B the rates used to compute amortl* For coltsms (c), (d), and (e) report avaltable informa-ration charges for electric plant (Accounts 404 and tion for each plant subaccount, account or functional 405). stata the basis used to cospute charges and classification listed in column (a). If plant mortality wh:ther any changes have been made in the basis or studies are prepared to assist in estimating average rates used from the preceding report year. service lives, show in colmn (f) the type mortality

3. Report all available information called for in section curve selected as most appropriate for the account section C every fifth year beginning with report year 1971, and in colunn (g), if aYallable, the weighted everage reporting annually only changes to colmns (c) through everage remaining life of surviving plant.

(g) from the couplete report of the preceding year. If conposite depreciation accountirrJ ls used, report unless conposite depreciation accounting for total depre- avaltable information cetted for in otumns (b) through stable plant is f ollowed, list nunerically in colmn (a) (g) on this basis, each plant st& account, account or functional classiff- 4. If provisions for depreciation were made during cation, as appropriate, tt, which a rate is applied. the year in addition to depreciation provided by applica-Identify at the bottom of section C the type of plant tion of reported rates, state at the bottom of included in any subaccounts used. section C the amoets and nature of the provialons In col e n (b) report att depreciable plant balances to and the plant items to which related.

which rates are applied showing subtotals by functional A. Stamary of Depreciation and Amortization Charges Functional Classification Total Lg E (e)

(a) (o) fc) kd5 1 Intangible Plant 0 2 Steam Product Plant 4,292,239 4,292,239 3 Nuclear Production Plant 10,157,387 11,924 6,813 10,176,124 4 MydrsulIc Production Plant--Conventional 0 5 Hydrautic Productton P1 ant--Punped Storage 0 6 Other Production Plant 183,341 183,341 7 Transmission Plant 1,271,662 1,271,662 0

8 Distribution Plant 9 General P1 ant 417,949 417,949 I-0 10 Conrnon Plant- Electric j 11 TOTAL $16,322,578 $11,924 $6,813 $16,341,315 B. Basis for Amortization Charges NUCLEAR INCLUDES $737,374 DECOM GENERAL INCLUDES $224,970 EUASC l l

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, FERC FORM NO.1 (ED.12-88) PAGC 336 NEXT PAGE IS 340

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PARTICULARS CONCERWING CERTAIN INCOME DEDUCTIONS AND INTEREST CHARGES ACCOUNTS glve W 3e hW4e ir.JMM aa tiet a

to N M ar ti, R M he5ef i:**grea*t W . W 5 charges accounts. Provide a sthheading for each account grouped by classes within the above accounts, and a totet for the account. Additionet coluuns may be (c) Interest on Debt to Associated Compentes (Account added if deemed appropriate with respect to any account. 430) -- For each associated company to which Interest on (a) Miscellaneous Amortization (Account 425) - Des- debt was Incurred during the year, Indicate the amount  ;

cribe the nature of items included in this account, the and Interest rate respectively for (a) advances on notes,  !

contra accomt charged, the total of amortization charges (b) advances on open accomt, (c) notes payable,(d)  !

far the year, and the period of amortle.ation. accounts payable, and (e) other debt, and total Interest. l (b) Miscellaneous Income Deductions -- Report the Explain the nature of other debt on which interest was '

nature, payee, and amount of other income deductions for Incurred during the year.

th3 War as re@lred by Accomts 426.1, Donations; 426.2, (d) Other Interest Expense (Accomt 431) -- Report  :

Life Insurance; 426.3, Penettles; 426.4, Expenditures for particulars (deteits) including the ' amount and interest l EE!!'"OthPMWcf*thPWorPW:f.1 '' * * '"'** *"'" * * " " * "-  !

Lg Ig gt h # E t N ey'o M @ fatt River 6,800 3 Mittstone 3 780 4 seabrook 2,431 5 Misc 2,380 3 6 TOTAL-426.1 12,391 7

l 8 Account 426.3 PENALITIES I

9 Mass Dept of Revenue 3,716 l 10 EUASC 770  !

11 Haupton NH proporcy tax 357 12 Misc 34 13 TOTAL 426.3 . 4,877 14 ,

15 Account 426.4 CIVIL T POLITICAL EXPENDITURES 16 seabrook 2,550 17 Mittstone 437 18 EEI Lobbying 563 .

19 TOTAL 426.4 3,550 20 21 Account 426.5 OTHER 22 Canal (6,505) ,

23 Millstone 3 12,616 ,

24 Misc 15 25 TOTAL-426.5 6,126 26 27 Account 431 OTHER INTEREST EXPENSE 28 M14 sales Credit 18,438 29 M14 Reftmd Provision 61,612 30 short term Debt Bank Notes 160,998 o 31 Co.mittment Fees 31,502 32 IRS Interest Adjustments (215,309) 33 Key Executive Life Insurance 9,850 C' 34 '~

Conservation & LM Normallration 94,589 35 PCAC Normalization 171,626 36 EUASC Attocated 245,374 - '

37 Miseettaneous 18,012 s.

38 TOTAL-431 5 M ,692 39 -

N h FERC FORM No.1 (ED.12 87) PAGE 340 Next Page is 350 p.

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h*"(M l g l sa 0 t2 fRgrt Year cf Report k rty$

R.su mission 13 96 Dec., 31,1995 u E,::' <

REGULATORY C0091]S$10N EXPENSES (~,

1. Report particutors (details) of regulatory consnission ex. 2. In coltsans (b) and (c), Indicate whether the expenses ,

penses incurred during the current year (or incurrow 's previous were essessed by a regulatory body or were otherwise incurred years, if being amortised) relating to formal cases before a by the utility. +

regulatory body, or cases in which such a body was a party.

Dee g tion A ses ed tg En es Total De erred L{ne Eo! c a' cE{pN !No'6 U ty IMIe 1 o year (a) (b) (c) (d) (e) 1 Moss Dept of Public Utilities 2 Special Assessments 1994 (43,354) (43,354) 3 o 4 FERC Order 472 1995 180,705 180,705 5 TERC Order 472 1996 63,600 63,600 6

7 Seabrook 144,875 144,875 8

9 M14 Rate case 469,598 469,598 10 11 Miscellaneous 13,926 13,926 12 13 14 15 16 iT 18 19 ..

20 6 21 l 2 i 23 24 ,,

25 as :a i 27 28 29 y;:

30 31 g. ,.

32 33 -

34 35 i.;

30 G l 37 l 38 . . .t 39 p,d 40

• 41 42 ,l' .' . ,

43 2 44 45 j 46 TOTAL $200,951 5628,109 5829,350 0 ,r((,i FERC FORM No.1 (ED. 12-90) Page 350 l I

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.e< R 1on 96 ,

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C REGULAYORY COMMISSION EXPENSES (Continued)

3. show in column (k) any expenses incurred in prior years 186.

which are being amortized. List in colunn (a) the period of 5. List in column (f), (g), and (h) expenses incurred during t, amortization, year which were charged currently to income, plant, or other

4. The totals of coluuns (e), (1), (k), and (t) inust agree accomts.

t:lth the totals shown at the bottom of page 233 for Account 6. Minor items (less than $25,000) may be grot 4=d.

EXPENSES INCURRED DURING YEAR AMOR11 ZED DURING YEAR

'; CHARGED CURRENTLY TO gegg yg geferr%g Department Accomt Amount E N Year Ljne*

(f) g) (h) (1) (J) (k) (t) 1 Electric 928 (43,354) 2 3

Electric 928 180,705 4 Electric 928 63,600 5 6

Electric 928 144,875 7

)

8 EtectrIc 928 469,598 9 10

, Electric 925 13,926 11 12 13 14 15 16 j 17 18 19 20 21 )

22 l 23 24 l 25 l 26 l 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 5829,350 r, 0 0 46 4 FERC FORM NO.1 (ED. 12-88) Page 351 NEXT PAGE IS 354

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"Y 0 Mion 13 96 3, 9 DISTRIBtlTION OF SALARIES AND WAGES iJ.b Report belou the distribution of total salaries and wages appropriate lines and cottanns provided. In detennining this for the year. Segregate asomts originally charged to clear- segregation of salaries and wages originally charged to clear-ing accounts to Utility Departments, Construction, Plant Ing accounts, a method of approximation giving stbstantistly Removals, and Other Accounts, and enter such amounts in the correct results may be used.

^

tg Classification Pg h r Totat

, (a) Dgfb*ago 1 ic) (d) _

j 1 Electric S2,749,519 l 4 Transmission 141,516l 5 Ofstribution l 6 Customer Accounts l

l 7 Customer Service and Informational l 8 Estes l l l

9 Administrative and General 137,527 l 10 TOTAL Operation (Enter Total of lines 3 thru 9) 53,028,562 11 Maintenance l

l 12 Production 1,424,362 j 13 Transmits}on 240,248j ,

l 14 Distritx,s'on l

15 Adninir/.rative and Generat l 16 TOTAL Maint. (Total of lines 12 thru 15) S1,664,610l i 17 Total Operation and Maintenance i 18 Production (Enter Total of lines 3 and 12) $4,173,881l '

! 19 Trarsmission (Enter Total of lines 4 and 13) $381,764l 20 Distribution (Enter Total of lines 5 and 14) 0l .

! 21 Customer Accounts (Transcribe from line 6) l

! 22 Customer Service and Informational (Transcribe from line 7) l j 23 Sales (Transcribe from line 8)

24 Adninistrative and General (Enter Total of lines 9 and 15) S137,527 .

! 25 TOTAL Oper, and Maint. (Total of lines 18 thru 24) $4,693,172 881,350 84,774,522 a j 26 Cas i 27 operation ~

! 28 Production- Manufactured Gas 1 -

i 29 Production- Nat. Gas (Including Expt. and Dev.)

30 other Gas Supply l j 31 Storage, LNG Terminating and Processing l 32 Transmission l l

33 Distributton l ,  !

j 34 Customer Accounts l D l q 35 Customer Service and Informational j 36 Sales l cz )

l 37 Aoninistrative and General l a

38 TOTAL Operation (Enter Total of lines 28 thru 37) l 39 Maintenance M j 40 Produc 'vy-Manufactured Gas 1

41 Production Natural Ces $ ,

42 Other Gas Supply b['

i 43 Storage, LNG Terminating and Processing 44 Transmission I 45 Distribution 46 Adninistrative and General j 47 TOTAL Maint. (Enter Total of 1ines 40 thru 46) i FERC FORM NO.1 (ED. 12 88) Page 354 -~

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. . - - . . . . _ - . _ ~ . - - - . - - . - - - - - - _ - . . - _ . _ . - - - - . . ~ - - - .- -. . -._.~_.. -.-.-

2-b onpany k'x A Res 0 at ssion 13796 t,x. 31,1995 DISTRIBUT!0W OF SALARIES AND WAGES (Continued)

Lg Classification Dgt(agoL Pg gr Total (a) [bF l Nc) l (d)

Gas j 48 Total Operation ard Maintenance j 49 Production +-Manuf actured Gas (Enter Total of lines 28 and 40) 0l 1

(M i Nan 5b 0

j 51, other Gas Supply (Enter Total of lines 30 and 42) 0l

$$I' obi b 4 0 2 - 53 Transmission (Lines 32 and 44) 0l

! 54 Distribution (Lines 33 and 45) 0l

- 55 Custcener Accounts (Line 34) l l~ 56 Customer service and Informational (Line 35) l

} 57 sales (Line 36) 1 58 Administrative and Generat (Lines 37 and 46)

) 59 TOTAL Operation ar.d Maint. (Total of lines 49 thru 58) 0l l 0 60 Other utility Departments l l l- 61 Op3 ration and Maintenance l l 62 TOTAL Att Utility Dept. (Total of lines 25, 59, and 61) S4,693,172l 581,350l S4,774,522 i

63 Utility Plant 64 Construction (By Utility Departments) 65 Electric Plant 175,001l 9,030l 184,031 3

7' 66 Gas Plant l l 67 other l l 5175,001l $9,030l 5184,03) l 68 TOTAL Construction (Total of lines 65 thru 67) l 69 Plant Removal (By Utility Departments) 49,407 451l 49,858 70 Electric Plant 71 Gas Plant l 72 Other l

$49,407 549,858

j. 73 TOTAL Plant Removal (Total of lines 70 thru 72) $451)

{ 74 Other Accounts (Specify):

I 75 205,346 6,729 212,075

f. 76 Work orders (186) i 92,345 (92,345) 0 77 stores clearing (163) 5,215 (5,215) 0 78 Transportation Clearin9 (184) 299,169 299,169 79 other 80

. 81 l 82 l.

83 84 85 86 l 87

! 68 89

(( 90 91

[..

j 92

4. 93 I 94

$602,075 (590,831) 5511,244 k' 95 TOTAL Other Accounts 55,519,655 0 55,519,655 96 TOTAL SALARIES AND WAGES

l. FERC FORM NO.1 (ED. 12-88) Page 355 h'

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Year of Report 7 s pgt gs Date f Rgrt Dec. 31, 1995 g ggr{ ,

{ k A R su0m ssion 03/3796 1

ELECTRIC ENERGY ACCOUN7 d and ,

Report below the information called for concerning the disposition of electric energy generated, purchased wheeled during the year. "

" Qa$ 8**fb)"

Y 8*"Ib!

21 DISPOSITION OF ENERGY 1 SOURCES OF ENERGY  ;

2 Generation (Excluding station Use): M 20 Sygu tgggg N N N u b !$ f,f p! N*kI1.) 4,565,05 5

ge er 4

5 Hydro--Conventional 24 NgRgggegs 519,548 -

~~ --

25 Energy Furnished Without Charge

~

pE OkyN!ckE[Sk! ob!e) 8 (Less) Energy for Pu m ing **** '

2,091,9'3 ktInT N ru k *  ;

3,015,53T Nb IIquN lbtk N2h 5,107,305 10 Purchases 11 Power Exchanges: Mg 12 Received _

13 Delivered 0

14 Nst Exchanges (Line 12 minus line 13) _

15 Trtnsmission For Other (Wheeting) MM 16 Received ,

17 Delivered 0

$ffE*S$*Ns LN k[

19 Transmission By Other Losses

• 5,107,305

)

4ka id S MONTHLY PEAKS AND OUTPUT l

with the sales so that the total on Line 41 exceeds the l' 1, if the respondent has two or more power systems which

. amount on line 24 by the amomt of losses incurred (or are not physicatty integrated, furnish the recyfred infor-estimated) in making the Non-Requirements Sales For Resale.

motion for each non-integrated system. 4. Report in cotum (d) the system's monthly maxinum l

2. Report in cotum (b) the system's enert,y output for megawatt load (60-minute integration) associated with the l each month such that the total on line 41 matches the total net energy for the system defined as the difference between on line 20. colunns (b) and (c).

3. Report in colunn (c) a monthly breakdown of the 5. Report in colunnste) and (f) the specified Information

' Mon-Requirements sales For Resale reported on line 24 for each monthly peak load reported in colunn (d).

include in the monthly amounts any energy losses associated NAME OF SYSTEM:

Month Total Monthly Energy / o ssoc at bLosses EE"" Megawatts g e Instr. 4) Day ogonth H

gine o.

11 6P 64,410 765 January 458,983 6 TP 29 789 404,026 31,978 30 February 1 7P

57,352 708 March 441,777 5 11A 31 691 389,550 46,020 11A 32 April 1 661 383,4'f8 32,510 12N 33 May 861 20 33,948 34 June 409/>41 27 2P 45,449 931 July 473,810 2 2P 35 926 481,093 53,778 36 August 1 2P 27,427 734 37 September 340,004 30 6P 26,573 670 38 October 388,048 29 6P 55,668 759 November 430,397' 11 69 39 816 464,578 44,435

40 Decenter 5,107,305 519,548 41 TOTAL l

l Page 401 FERC FORM No.1 (REVISED. 12 90)

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0 a c bonpany L2j*k!AYResilimission 0h!'I DN3f96 Dec. 31,1995 d STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants)  ;.cr 4 3*Eid!!$$)nt.l!$m$$*'65!$

me an S

ri m, o,e,.ted as

'5!%i$

78 Eb"Mip"'4t"12 il st% ateq"" ' gsgd p~ pb p-3.r t $g <)' s"qm.ndL1 g minut

4. n i ptm bsp-not a..liebte, d

5. yne "51T o,es approx :,-}m: tm4ari-ate : nunIaer average t on of Mo,yees it.waskevatw.i ntt a! em.<=r '

• tv to l

Lg g Plant Name $ set Station Plant Names S set Station (3) 1 gn hagtgy, Internal contiustion, Gas steam (1) & (2) Internal conbustion hme, NTSO N N

• Conventionat Full Outdoor 3 Year originally constructed 1925 1970 4 Year Last Unit was Installed 1959 1971 InhPN$e*Ning*NMh* *"* I * #

194.00 42.40 6 N:t Peak Demand on Plant MW (60 minutes) 116 46 7 Plant Hours Connected to Load 7,774 247 8 Net Continuous Plant Capability (Megawatts) 9 When Not Limited by condenser Water 110 43 10 When Limited by Condenser Water 11 Average Ntaber of Epployees 12 N:t Generation, Exclusive of Plant Use --KWn 673,316,500 5,647,200 13 Cost of Plants Land and Larul Rights 657,787 0 14 Structures and Inprovements 14,118,348 21,465 15 Equipment costs 35,793.072 4,550,624 16 T:tal cost $50,569,207 54,572,089 ,

17 Cost per KW of Installed Capacity (tine 5) 260.6660 107.8322 <

18 Production Expenses: Oper. Supv. & Engr. 524,271 1,204 19 Fuet 14,951,614 328,139 20 Coolants and Water (Nucteer Plants Only) 21 Steam Expenses 1,004,452 16,737 22 Steam from Other sources 23 St:am Transferred (Cr.)

24 Electric Expenses 1,042,756 25 Ml;c. Steam (or Nuclear) Power Expenses 923,053 6,663 26 Rents 27 Attowances 4,062 28 Maintenance Supervision and Engineering 283,447 29 Maintenance of Structures 201,173 30 Maintenance of Botter (Or Reactor) Plant 1,333,771 31 Maintenance of Electric Plant 1,373,610 30,375 32 Maintenance Misc. Steam (or Nuclear) Plant 228,815 ._.,

33 Titat Production Expenses $21,871,024 5383,118 34 Expenses per Net KWh 50.0324 $0.0678 35 Fuel: Kind (Coat, Gas,0il or Nuclear) 011 (6) Coat Composite Oil bk hi!.5NsNc uchah-knb$ Barrels Tons (7) Darrels 37 Quantity (Units) of Fuet Burned 89,036 240,060 13,326 .

38 A Heat C t.of{uelBurned B g *r* (b. of _

k e unik* nuc{eaf) # # 151,130 13,933 133,724 NoEP an! hur$n YE '** $17.260 $49.546 S23.531 40 Average Cost of Fuel per Unit Burned $16.216 $50.275 524.049 41 Avg. Cost of Fuel Burned per Million Stu $1.861 54.102 i 42 Avg. Cost of Fuel Burned per KWh Net Cen 50.720 S0.057 43 Average Btu per KWh Wet Generation 10,781.000 13,834.000 w

FERC FORM NO.1 (REV.12-95) Page 402 1 :?

h; O

0

'e N a'up $ N kompany ## '

F Y $I Y OfY'Icalk2) k j A Resu$smssion b

k*f31I968N Dec. 31, 1995 STEM ELECTRIC GENERATING PLANT STAT!STICS (Large Plants) (Continued) h cE!Ed owi

- " " N t,$ ti s$e!rnun$t aNu!b $

e,%e , s in_fk!c m: t-12.g,at:::p(.:r- ,atin s,,e,i e tain 644b

. o$'lk 4 S"fd, I#N gene kb

• 1. E!e!!,cotsgan; tt! ted S "o$$I*$hi aYA I t ts I ak ark *g a hk c t a ha" o

11. 'Is ** wIy*c  ! 'fSs *Sf'it enicY

[ nt 5t "g " a "equk t' *epo t asa! te ant. Hwevhfh"ag

• Plant Name: Sgrook#1 Plant Names nal #2 (4) Plant Names n #4 (5) (8) Lg Nuclear Steam Steam fully Contained Conventional Conventional 1970 1976 1975 3 1990 1976 1978 4 34.71 265.00 16.62 33 239 16 6 7,466 6, 734 2,150 7 8

33 292 16 9 33 290 10 902 4 5 11 243,206,{.g. 830,826,500 14,780,569 12

$97,471 0 0 13 59,328,487 8,216,152 616,842 14 130,015,981 60,620,676 3,387,258 15

$189,441,959 $68,836,828 54,004,100 16 5,457.8495 259.7616 240.9205 17 585,128 1,184,382 11,106 18 2,875,683 24,021,532 432,258 19 19,447 20 329,596 433,821 19,893 21 22 (76,521) 23 4,626 785,725 12,246 24 814,857 769,876 54,895 25 26 27 321,542 (179) 10,720 28 105,652 181,857 2,795 29 324,784 1,711,585 12,927 30 157,041 480,163 3,381 31 219,077 91,253 3,041 32

$5,757,433 s29,583,494 5563,262 33 S0.0236 $0.0356 $0.0381 34 Nuclear (9) O!L #6 Cil #2 Oil Composite 35 Grams 1100%) BARRELS Barrels Barrels Barrels ,

1,347,798 1,438,673 915,422 11,465 926,887 37 ,j 150,048 150,509 138,878 150,365

$16.702 517.054 522.327 $17.123 516.702 516.848 $22.139 $16.914 40 l 52.650 $2.665 $3.796 $2.678 41 '

50.029 $0.029 42 10,285.000 10,913.000 10,692.000 43 FERC FORM No. 1 (REV. 12-95) Page 403 gg3g l

e k i$.!or 3 96 e , 995 :c STEAM-ELECTRIC GENERATING PLANT STAil5 TICS (L.rge Pl.nt.) (Continued) .

'-[ p c-* g; e"yty,,gc.,g aww.

u.a er":a- ..m p

eg g.. ,,

'a-[,,,,6e..:en.it g".' #

,r. n.r9' er mq ri q p am Lra n.e.+

tm m,,.khwrgAgi-=3%,'atam 6tp. "iyk.. y:, 4 -

pS.,t et a.@,

mF f

11. m h :ili, e..lig: a pd.::!a:se,m a

h.n6 e

n,'Tg**tyA tshg"-%.gJ Plant Names M . ton. F3

. ':a.: Plant Name:

Plant Names a- '"*-

L Nuct..r fully cont.ined 1986 3 1986 4 50.24 47 6 7,094 7 8

46 9 45 10 368 11 321,528,929 12 546,618 13 51,953,921 14 124,998,866 15 5176,999,405 16 3,523.0773 17 823,370 18 1,621,678 19 85,566 20 369,639 21 22 23 168,949 24 1,134,889 25 26 27 305,604 28 323,922 29 1,205,733 30 504,820 31 10,852 32 56,555,022 33 50.0203 34 Nuclear (9) 35

~

36 Gram. (100%) ,

1,847,400 37 -

l 38 .

39 40 i 41 42 10,180.000

• 43 a-FERC FCTJi NO.1 (REV.12-95) Page 403.1

h j'* < Pcg3 403 Lins 43 Column o >

T Notes:

hy:

l Seabrook Unit No.1 1 ___________________

Seabrook Unit #1 is a jointly owned nuclear facility located in Seabrook, New Hampshire. Montaup's share is 2.89989%. The North Altantic Energy Service Corporation (North Atlantic), a wholly owned subsidiary of Northeast Utilities, is the ,

l. principal owner and operates the physical plant. Montaup  !

l Electric participates in both the operation and maintenance cost of this unit. Based upon financial reasons, most partic-ipants have different dates of commercial operation. Montaup date was August 19, 1990. Data presented herein represents Montaup Electric's 2.89989% share, except as noted. North Atlantic /Seabrook #1 is not required to submit FERC Form No 1 Millstone Unit No.3 Millstone Unit #3 is a jointly owned nuclear generating facility located on Long Island Sound in Waterford, Connecticut Montaup's share is 4.009%. Northeast Utilities is the princi-pal owner and operates the physical plant. Montaup participates in both the operation and maintenance costs of this unit.

Millstone Unit 3 was placed in service for commercial operation on April 23, 1986. Data presented herein represents Montaup's 4.009% share, except as noted.

, Canal Unit No.2 Canal Electric Company Unit #2 was placed in service for commercial operation on February 1, 1976. Canal Unit #2 is a jointly owned, fossil fuel, cycling generating facility located on the Cape Cod Canal in Sandwich, Ma. Montaup's share is 50%.

Although Canal Electric Company operates the physical plant, Montaup participates equally in the operation and maintenance costs for this unit. Data presented herein is Montaup's 50%

share, except as noted, the other 50% is reported by Canal on their FERC Form 1.

Wyman Unit No.4

- Wyman Unit #4 was placed in service for commercial operation on September 1, 1978. Wyman #4 is a jointly owned, fossil fuel, cycling generating facility located on Cousin's Island in Yarmouth, Me. For NEPOOL purposes it is known as Yarmouth #4.

Montaup's share is 2.6284%. (8) Central Maine Power Company is the principal owner and operates the physical plant. Montaup participates in both the operation and maintenance cost of this unit.

[i - (see next page) l s

a Page 402-403 Footnote.1 l

NOTES: '

s (1) Steam Units No. 1 2, 3, & 4 Somerset Station, retired as of March 1991. (values on line 5, column b)

(2) Steam Unit No. 5, Somerset Station, placed in Deactivated Reserve effective 1/25/94. (values in line 5, column a)

(3) Montaup owns and operates two identical units Nos. J1 & J2 (values in line 5, column c) ,

(4)' Canal Electric Company employs 122 people and operates two  !

i units. Breakdown for Unit #2 is not available.

(5) Employees are reported on page 402 of Central Maine Power  !

company's FERC Form 1 under W.F. Wyman Nos. 1, 2, and 3.  !

(breakdown not available) (values on line 1, column f)  ;

(6) Composite of No.2 Oil and No.6 Oil (values on line 36, column a) '

(7) Composite of No.2 Oil, No.6 Oil and Coal.

(values on line 37, column a) i (8) Montaup's share of Wyman #4 '

1.9618% Montaup '

.6666% Newport 2.6284% (values on lines 5 , 6, 9 and 12 column f) s-

Wyman's 100% values are shown on lines 7,38-44.

(9) Calculation for Seabrook & Millstone line 39 page 403 is (6.40 x 10^7 BTU /GR) & (6.04 x 10^7 BTU /GR) respectively. ,

t E

p

.=

Page 402-403 Footnote.2 Ei r2 s.

d

- t &

' I-t

,O (BLANK PAGE)

NEXT PAGE IS 422

f. "

f.

g. .

5 e

" !slon 3 ,

TRANSMIS$!ON LINE STATISTICS <

1. Report Information concerning transmission lines, cost of tion. If a transmission Line has more than one type of support- e lines, and expenses for year. List each transmission line ing structure, Indicate the alteege of each type of construction having nominal voltage of 132 kilovolts or greater. Report by the use of brackets and extra lines. Minor portions of a transmission lines below these voltages in group totals only transmission Line of a difforent type of construction need not for each voltage, be distinguished from the remainder of the line.

2. Transmission lines include att lines covered by the 6. Report in colums (f)and(g) the total pole miles of each definition of transmission system plant as given in the Uni- transmission line. Show in column (f) the pole miles of line form system of Accounts. Do not report sthstation costs and on structures the cost of which is reported for the line dest-expenses on this page, gneted; conversely, show in column (g) the pole alles of line 4 3. Report data by Indivichael lines for att voltages if so on structures the cost of which is reported for another Line, required tr/ a state commission. Report pole miles of line on leased or partly owned stru-

4. Exclude from this page any transmission Lines for which ctures in column (g). In a footnote, explain the basis of plant costs are included in Account 121, Nonutility Property. such occupancy and state whether expenses with respect to 5.Indic:te whether the type of supporting structure report- such structures are included in the expenses reported for the ko ['poTh(! hM MNNc"hD o DE51GNATION (I eM Type of N e a mmber

$b!ye *Sphase) Supporting repoh! cut"m$les) of g

7 operating Designed structure gture g gres Circuits (a) (b) (c) (d) (e) Y "*(g) (h) N j Somerset station various 115.00 115.00 pgg g 28.39 g 3

4 Bridgewater Substation Easton/Somerset 115.00 115.00 Steet Tower 11.69 2 5 H Frame Wood 0.25  ;

6 7 Titicut street Bridgewater Walpole 345.00 345.00 H Frame Wood 23.35 1 8

9 srldgewater substation Walpole 345.00 345.00 steet Tower 19.06 1 10 11 Titicut Street Bridgester Bridgeweter Stbstation 345.00 345.00 Steel Tower 4.52 1 12 13 14 15 16 17 18 19 20 21 i 22 23 24 25 -

26 27 &?

28

'e 29 30 31 32  %

33 N

36 TOTAL 141.05 40.08 18 y FERC FORM NO 1 (ED. 12-87) Page 422 G

ssion 3 9 ,

p Le TRANSMIS$10N LINE STATISTICS (Continued)

7. Da not report the same transmission Line structure twice. respondent operates er shares in the operation of, furnish a

., Report tower voltage Lines and higher voltage lines as one succinct statement explaining the arrangement and giving line. Designate in a footnote if you do not include lower particulars (detalts) of such matters as percent otaiership by voltage lines with higher voltage lines. If two or more trans- respondent in the line, name of co-owner, bests of sharing Lission line structures support ifnes of the same voltage, expenses of the line,and how the expenses borne by the respon-report the pole miles of the primary structure In coltsun (f) dent are accounted for, and accounts affected.Specify whether and th2 pole miles of the other line(s) in coltari (g). tessor, co-owner, or other party is an associated company.

8. Designate any transmission line or portion thereof for 9. Designate any transelssion line leased to another company which the respondent is not the sole owner. If such property and give name of lessee, date and terms of lease, annual rent

, is 100 ed from another coupany, give name of lessor, date and for year, and how determined. Specify whether lessee is an t:rms af lease, and amount of rent for year. For any transel- associated company.

salon line other than a teased line, or portion thereof, for 10. Sase the plant cost figures called for in coltsuns (j) to which the respondent is ni. ti.. sole owner but which the (1) on the book cost at end of year.

COSTOFLINE(incluEin coltaan (j) land, EXPENSES, EXCEPT DEPRECIA110N AND TAXES I

Sf 7 g tend rights, and clearing right-of-way)

. t:rkel Land Construction and Other Costs Total Cost Domi. tion Ehpe' es Maintenance Experses Rents Total Expenses No.

(1) (J) (k) (1) (m) (n) (o) (p)

Vertous $1,057,398 S3,861,505 54,918,903 S185,466 5225,945 S411,411 g

3

-795 ACSR 5485,656 S485,656 0 0 0 4 0 5 j 0 6 j 2335 ACAR $853,538 S2,590,205 S3,443,743 S1,192 $8,836 $10,028 7 0 8 2 1703 ACR $998,314 54,713,839 $5,712,153 S2,394 $10,816 $13,210 9 0 10 2 1703 ACAR 0 11 12 13 14

~

15 16 17 "l jg 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 N

.; S2,909,250 $11,651,205 514,560,455 . S189,052 5245,597 0 S434,649 36 FERC FORM NO. 1 (ED. 12-87) Page 423 NEXT PAGE IS 426

e sfon 13 , -

Sug5TATIONS *; :.

1. Report below the information called for concern- resale, may be grouped according to functional character,but Ing othstations of the respondent as of the end of the the ntaber of such substatfons must be shown. -

year. , 4. Indicate in coluus (b) the fmettonal character of each

2. 8 4 stations which serve only one industrial or stestation, designating whether transmission or distribution s,treet railway customer should not be !Isted below. and whether attended or mattended. At the end of the page,

3. 54 stations with capacities of less than 10,000 suunarize according to fmetton the capacitles reported for Kve, except those serving customers with energy for the individual stations in cottan (f).

Line Name and Location of St&statlon Character of Substation No. Primary secondary Tertiary (a) (b) (c) (d) (e) ,

1 samerset Attended 13.80 115.00 2 13.80 115.00 3 13.80 115.00 4 115.00 13.80 5

6 F lt 8fver Ms. - Hathaway st. Attended 115.00 23.00 7

8 Dighton, Ma. Trans/Dist Unatt 115.00 13.80 9

10 ,

11 Swansas, Ma. Trans/DIst Unatt 115.00 13.80 .

12 13 14 Bridgewater, Ms. (1) Trans/ Unattended 345.00 115.00 15 16 Whitman, Ma. - Auburn St. (1) Trans/ Unattended 345.00 115.00 17 [

18 19 20 ',

21 g,. ,

22 (1) These transformers are shown above at 100% rating

• 23 and are jointly owned (50% each) wf th the 24 Canal Electric Conpany.  ;).

25 '-

26 27 ,y.

28 tc.,

29 30 p, 31 l- l; >

32 D

33 34 i. :.

35 @

36 37 :g ,

38 (i$ '

39 40 fi' ,

t. .

FERC FORM NO. 1 (ED. 12-86) Page 426 -

(:l

=. - .-. . _ - - - . -.- - -- - -.- - - ~- - - -

• p{nOkinal '

O eh lI*e N konpany jk((JAResulmeission y

( $$o03f3f796Y'*Dec. 31,1995

(( " SuasTA110Ns (continued)

5. show in columre (1),(J),and (k) spectat equipment such of lessor, date and period of lease, and annust rent. For any as rottry converters, rectifiers, condensers, etc. and aux

• substetton or equipment operated other than by reason of sole ownership or tease, give name of co-owner or other party, ex-

[;; lliery epipment for increasing cepecity, H 6. Designate substations or major items of equipment leased plain bests of sharing expenses or other acco mting between fromcth:rs,jointlyownedwithothers,oroperatedotherwise the parties, and state amomts and accounts affected in respon-than by reason of sole ownership by the respondent. For dent's books of account. Specify in each case 4 ether lessor, any othstation or equipment operated under Leese, give name co-owner, or other party is an associated company.

W r of Ngr of CONVERSION APPARATUS AND SPECIAL EQUIPMENT YbT eNn*NU InSrE' TranNo!aers Type of Equipment Number of Units Tog o(gity Ni (f) (g) (h) (1) (j) 75.00 3 nore 1 69.00 1 none 2 69.00 1 none 3 50.00 1 none 4 5

40.00 1 none 6 7

33.60 1 none 8 9

to none 11 67.20 2 12 13 none 14 800.00 2 15 400.00 1 none 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38

• 39 40 Page 427 Next Page is 429 FERC FORM NO.1 (ED.12-95)

P a

e a ho@sny b 3 6 ENVIRONMENTAL PROTECTION FACILITIES

1. For purposes of this response, environmental protection or low sulfur fuels including storage and hardt-facilities shall be defined as any building, structure, Ing equipment eqJipment, f acility, or improvement designed and constructed (3) Monitoring equipnent sil:ty for control, reduction, prevention or abstement of (4) Other.

discharges or releases into the environment of gaseous, liqJid, B. Water pollution control faCllltiest or solid substances, hest, noise or for the controt, (1) Cooling towers, ponds, piping, peps, etc.

re&ction, prevention, or abatement of any other adverse Im- (2) Weste water treatment equipnent pact af an activity on the environment. (3) Sanitary weste disposal equipment

2. Report the differences in cost of facilities instatted (4) Oil interceptors for environmental considerations over the cost of alternative (5) sediment control facilities facilities nAlch would otherwise be used without envirorveental (6) Monitoring equipment considerations. llse the best engineering design achievable (7) other, tithout environmental restrictions as the basis for determining C. solid waste disposal costs: .[

costs without environmental considerations. It is not (1) Ash handling and disposal equipment Intended that speclat design studies be made for purposes of (2) Land tble response. Base the response on the best engineering (3) settling ponds Judgement where direct comarisons are not evaltable. (4) other.

D. Noise abatement equipments Include in these differences in costs the costs or estimated costs of envirorsnental protection facilities in service, (1) structures constructed or modified in connection with the productlon, (2) Mufflers M transelssion, and distribution of electrical energy and shall (3) Sound proofing equipment be reported herein for att such erwironmental facilities (4) Monitoring equipment placed in service on or af ter January 1,1969, so long as it (5) other.

Is readily determinable that such faellities were constructed E. Esthetic costs:

tr modified for environmental rather than operational purposes. (1) Architectural costs At:o report similar expenditures for environmental plant (2) Towers '

included in construction work in progress. Estimate the cost (3) tJnderground Lines ef facilities when the original cost is not available or (4) Landscaping facilities are jointly owned with another utility, provided the (5) Other.

respondent explains the basis of such estimations. F. Additional plant capacity necessary due to Examples of these costs would include a portion of the costs restricted output from existing facilities, or addi-Ef t:lt smokestacks, underground lines, and landscaped substa- tion of pollution control f acilities, tions. Explain such costs in a footnote. G. Miscettaneous:

3. In the cost of facilities reperted on this page, include (1) Preparation of environmental reports an estimated portion of the cost of plant that is or will be (2) Fish and wildlife plants included in Accounts used to provide power to operate associated environmental pro- 330, 331, 332, and 335.

tection facilities. These costs may be estimations on a per- (3) Parks and related facilities centage of plant basis. Explain such estimations in a footnote. (4) Other. ,

4. Report all costs under the major classifications provided 5. In those instances when costs are composites of both f below and include, as a minlaum, the items listed hereunder: actual supportabte costs and estimates of costs, specify A. Air pottution control facilities in colum (f) tne actual costs that are included in . .

(1) Scrubbers, precipitators, tatt smokestacks, etc. colunn (e).

(2) Changes necessary to acconynodate use of 6. Report construction work in progress relating to en-envircccer. tally clean fuels such as low ash virorsnental f acilities at line 9.

gala e at Actual Cost Line Classification of Cost Add ons Reti ts nd Tear No. Adjgments

$327,150 559,411,556 M 9,247,542  ;.

Air Pollution Control Facilities S4,493,635 1

2 Water Pollution Control Facilities 626,245 78,187 23,372,837 22,920,027 Q.l 28,736 4,398,842 3,953,702 l 3 solid Waste Disposal Costa 474,128 370,836 370,836 4 Noise Abatement Equipnent f 16,154 16,154  !

Esthetic Costs 5 ~

22 2 26,326 6 Additional Plant capacity 1,216,239 1,216,239 7 MiseetLaneous (Identify signifIcent) 1,5 65

$434,075 588,812,790 587,724,500 ,.

8 TOTAL (Total of lines 1 thru 7) 55,595,595 485,011 1,176,189 1,176,189 R.

9 Construction Work in Progress FERC FORM No.1 (ED.12-88) Page 430

(. *

?!~ .

, .y .

inion 3' ,

ENVIRONMENTAL PROTECTION EXPENSES

1. Show below expenses incurred in connection with tion of pollution control equipnent,use of alternate en-the use of envircrunental protection facilities, the vironmentatty preferable fuels or environmental regula- )

cost of which are reported on page 430. Where it is tions of governmental bodies. Base the price of replace- '

necessary that attocations and/or estimates of costs ment power purchased on the everage system price of be made, state the basis or method used. purchased power if the actual cost of such replacement i

2. Include below the costs Incurred due to the power is not known. Price internally generated replace-operation of environmentet protection equipment, ment power at the system everage cost of power generated 1 facilities, and programe, if the actuel cost of specific replacement generation l

3. Report expenses under the sthheadings listed is not known.

6. Under item 8 Include ad vetorem and other taxes

]

below.

4. Under item 6 report the difference in cost be- assessed directly on or directly relatable to envirorveen-tween environmentally clean fuels and the alternettve tal f acilities. Also include inder item 8 Licensing and fuels that would otherwise be used and are avaltable simitar fees on such facilities, j for use. 7. In those Instances where expenses are composed of I

5. Under item 7 Include the cost of replacement power, both actual supportable data and estimates of costs, l p rchased or generated, to compensate for the deft- s,pecify in cottsuri (c) the actual expenses that are it? I ciein.vinoutputfromexistingplantsduetotheaddt- cluded in cotum (b). .

Lg l ClassiflglonofExpenses gt Actua]xpenses 1 Depreciation S2,622,018 2

Lgggtg gegrf ats, and Supplies Cost Related to Env. 59 '.53L101 3 Fust Related Costs 4 Operation of Facilities 13,303 .

6,652 5 Fly Ash and Sulfur Studge Removat 569,837 563,249 ,

6 Difference in Cost of Environmentally Clean fuels 2,163,838 3,932 f 7 Reptscenent Power Costs 56,008 8 Taxes and Fees 14,907 1,258 9 Administrative and General 22,355 11,039 10 Other (Identify significant) 11 TOTAL S7,086,857 $2.123,231 i

f.

l L

1. Page 431 Next Page is 450 FERC FORM No. 1 (ED. 12-88)

.e 1 .

INDEX 7 Schedule page N3. ... a se Accrued and pr opo l d t ax es . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

'ds 262-263 Ac cumut:t ed De f er r ed I nc ome T axes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 234 Accumut ted provisions for depreciation of 272-2n common utility plant ...................................................................................... 356 utilityplant............................................................................................. 219 ut i l i t y pl ant ( s umma ry ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 200-201 Advances f r an sesoc i a t ed c ompan i es . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 256-257 Attouences.................................................................................................... 228 229 Amortitation CIscellaneous ............................................................................................. 340 Ef nucleer fuGL ........................................................................................... 202-203 Appr opr i et f ons of R ot e i ned E a rni ngs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 118-119 Associated Compentes advances from ............................................................................................. 256-257 corporat i ons controt t ed by respondent . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 103 (ontrol over respondent ................................................................................... 102 Int: rest on debt to ....................................................................................... 256-257 Attestetton................................................................................................... 1 Botence sheet Comparative .............................................................................................. 110-113 notes to .................................................................................................. 122-123 Bonds ......................................................................................................... 256-257 Capit:tStock................................................................................................. 251 .

discount.................................................................................................. 254 CMpense ................................................................................................... 254 I ns t a t t men t s r ec e i ved . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 252

• ~-

premiums .................................................................................................. 252 resoquired ................................................................................................ 251 subscribed ................................................................................................ 252 Cash flows, statement of ...................................................................................... 120-121 cd Changes luportant during year ..................................................................................... 108 109 Construction overheads, electric ....................................................................................... 217 overhead procedures, general description of ............................................................... 218 wor k i n pr og r es s c ommon ut i l i ty pl ant . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 356 work in progress electric ............................................................................... 216 Work in progress other Lnllity departments .............................................................. 200-201 Contrzt  ; . .,

corporat i ons cont ro t t ed by respondent . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 103 over respondent ...........................................................................................

102 t ecur i ty ho l ders and vot i ng powers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 106-107 P Corpor: tion controttedby............................................................................................. 103 c; incorporated.............................................................................................. 101 CPA , bac kground I nf ormat i on on . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101 .ad CPA C:rtlfication, this report form ........................................................................... 1 11

~:

, . , . .s n.t FERC FORM NO.1 (ED. 12-93) Index 1 Q.

e.a

l IWDEX (Continued) p

q,

, Def;rred credits, other ............................................................................................ 269 debits, miscellaneous .................................................................................... 233 income taxes accumulated - accelerated amortization property ................................................................................... 272 273 Income taxes accumulated - other propcrty ................................................................. 274 275 I nc ome t ax es occumul a t ed - o t he r . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 276-2TT i ncome t axes occumul at ed - poll ut i on cont rol f ac i l i t i es . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 234 Definitions, this report form ................................................................................. til Depreciation and amortization af common utility plant ................................................................................... 356 cf electr{c plant ......................................................................................... 219 336 337 Direct!rs ..................................................................................................... 1 05 i D i sc ount on c ap i t a l st oc k . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 254 Olscount - premius on long-term debt .......................................................................... 256 257 Distribution of salaries and wages ............................................................................ 354-355 Dividend appropriations ....................................................................................... 118 119 E arn i ng s , R e t a i ned . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 118-119 E l ec t r i c ene r gy ac c oun t . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 401 Environmental protection cxpenses .................................................................................................. 431 430  ;

facilities................................................................................................

l Expenses clectric operation and maintenance ........................................................................ 320-323 i s t ec t r i c operat i on and ma int enance, s ummary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 23 unamortized debt .......................................................................................... 256 Extraordinary property losses ................................................................................. 230 Filing requirements, this report form ........................................................................, 1 11 General description of construction overhead procedure ........................................................ 218 General InformatIon ....................................................................... ................... 101 l l

Instructions for flting the FERC Form 1 ....................................................................... I-IV Generating plant statistics hydroelectric (large) ..................................................................................... 406-407 pumped storage (large) .................................................................................... 408 409 i smatt plants .............................................................................................. 410-411 steam-electric (large) .................................................................................... 402 403 Hydre-electric generating plant statistics .................................................................... 406-407 Identification ................................................................................................ 1 Important changes during year ................................................................................. 1D8-109 Income statement of, by departments .............................................................................. 114 117 statement of, for the year (see also revenues) ............................................................ 114 117 I deduct i ons , i nteres t on debt t o ass oc i at ed compani es . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 340 deduc t i ons , mi scel l aneous amort i zat i on . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 340 deduc t i ons , ot he r i nc ome deduc t i on . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 340 deduc t i ons , o t he r i nt e r es t c h arges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 340 I ne: rpo ra t i on i nf orma t i on . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101 I ns tt t t ment s rec e i ved on cap i t a t s t oc k . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 252 i

I I;

I t

l FERC FORM NO.1 ([D.12 95) Index 2

W d e ,I .i INDEX (Continued) .w . ei Schedute Pese N2. ,

Interest a i charges, on debt t o assoc i a t ed compani es . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 340

{

charges, other ............................................................................................ 340 charges, paid on tong term debt, advances, etc. ........................................................... 256-257 investments nonutility property ....................................................................................... 221 f subsidiary companies ...................................................................................... 224 225  ;

Investment tax credits, acew utated deferred .................................................................. 266 267 Law, excerpts applicable to this report form .................................................................. IV l Llst of schedules, this report form ........................................................................... 2-4 Long-term debt ................................................................................................ 256-257 ,

Losses . Extraordinary property ............................................................................... 230 l Motori:ts and og ptles ........................................................................................ 227 i Net ers and L l ne t rans f ormer s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 429 i r

Miscellaneous general expenses ................................................................................ 335

{

Notes ta betence sheet .......................................................................................... 122-123 t2 statement of chenees in financist position ............................................................. 122-123 -

j to statement of income .................................................................................... 122-123 ts statement of retained earn {nes ......................................................................... 122 123 ...

Nonutltity property ........................................................................................... 221 Nuclear fust materiets ........................................................................................ 202-203 Nuclear generating plant, statistics .......................................................................... 402-403 Nwber of E l ec t r i c Department Espl ayees . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 323 4 i

offIc:rs and officers' salaries ............................................................................... 104

)

Oper: ting expenses - electric ....................................................................................... 320-323  !

expenses - e t oc t r I c ( suuna ry ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 323 f

other ,

peId-In capita! ........................................................................................... 253 dona t i one rec el Ved f rom s t oc kh o l de rs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 253 ,

gains on resale or cancellation of reacquired capitat stock ........................................................................................... 253 ciscellaneous pald-in capitat ............................................................................. 253 re&ct i on i n par or s t a ted value o f capi t a l s t ock . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 253  ;

regulatory assets ......................................................................................... 232 regutatory iIabtLities .................................................................................... 278 overhead, c ons t ruc t i on - e l ec t r i c . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 217 Peaks, monthly, and output .................................................................................... 401 I i

Plant, Cannon utility ,

accumul at ed provi s i on f or deprec l e t i on . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 356  !

ecquisition adjustments ................................................................................... 356  :.1, l

citocated to utility departments .......................................................................... 356 coppteted construction not classifled ..................................................................... 356 i construction work in progress ............................................................................. 356 eRpenses .................................................................................................. 356 held for future use ....................................................................................... 356 in service ................................................................................................ 356 356 5[,

teased to others .......................................................................................... ,

Plant data .................................................................................................... 217-218 l 336-337 )

401-429 l

)

1 l

l FERC FORM NO.1 (ED.12-95) Index 3 D*

]

i p

r.'

s

2.

1. . gr l'

INDEX (Continued) l

. schedsta Page N3.

l m

i:b Plant - electric accumulated provision for depreciation .................................................................... 219 construction work in progress ............................................................................. 216 jf held for future use ....................................................................................... 214 l^

in service ................................................................................................ 204-207 i

l leased to others .......................................................................................... 213 l~ Plant - utility and accumulated provisions for depreciation

i. amort i zat i on and depl et i on ( suunary) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 201

\,

t Pollution control f acilities, accumulated deferred

! Incone taxes .............................................................................................. 234 L Power Exchanges ............................................................................................... 326 327 l- Premi um and d i scount on l ong t erm debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 256 P rem i um on c api t a l s t oc k . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 251 Propold taxes ................................................................................................. 262-263 P r oper ty - l osses , ex t r aord i nary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 230 Puuped storage generating plant statistics .................................................................... 408 409 l

Purchased power (including power exchanges) ................................................................... 326 327

Reac wired capital stock ...................................................................................... 250 P Reacquired long term debt ..................................................................................... 256 257 Rec

lvers' certificates ....................................................................................... 256-257 9 Reconcillation of reported not income with taxable income from Federal income taxes ................................................................................. 261 Regul

tory commi ss i on expenses def erred . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 233 Regulatory commission expensos for year ....................................................................... 350 351 R esearch, devel opment and demonst rat i on act i vi t i es . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 352-353 R:tained Earnings amortitation reserve Federal .............................................................................. U*

appropriated .............................................................................................. 118 119 statement of, for the year ................................................................................ 118 119 mappropriated............................................................................................ 118 119 Revenues - electric operating ................................................................................. 300 301 satories and wages

! directors fees ............................................................................................ 105 i distributlon of ........................................................................................... 354 355 cffIcars' ................................................................................................. 104 setes of electricity by rate schedules ........................................................................ .

304 sales for resato ............................................................................................ 310-311 sitvege - nueiear fust ........................................................................................ 202 203 Schedules, this report form ......................................................................... ........ 2-4 securities cxchange registration ..................................................................................... 250 251 holders and voting powers ................................................................................. 106 107 st:tement of Cash Flows ....................................................................................... 120-121 S t at ement of i ncome f or t he yea r . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 114 117 0 st:tement of retained earnings for the year ................................................................... 118-119 Steau-electric generating ptant statistics .................................................................... 402 403 stock liabttIty for conversion ................................................................................ 252 y thbst:ttons................................................................................................... 426 p supplies - meteriets and ...................................................................................... 227 i

FERC FORM No.1 (ED. 12-90) Index 4 O

.. h c::-

4 .

INDEX (Continued) ,4 Scheduls Page Nr. .

Tames N accrued and prepaid ....................................................................................... 262 263 ch;rged durino yeer ....................................................................................... 262-263 ,6 on (nease, de f erred and occuma l e t ed . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 254 i:' '

272-277  ;

reconcillation of net income with taxable income for ...................................................... 261 4 Transformers, line - electric ................................................................................. 429 Transelssion lines added during year ................................................................................... 424-425 lines statistica .......................................................................................... 422 423 cf electricity for others ................................................................................. 328-330 af electricity by others ..................................................................................- 332 Unemortiaed debt discount ............................................................................................. 256-257 debt esponse .............................................................................................. 256-257 preefunondebt........................................................................................... 256-257 Unr r vered Plant and Regulatory Study Costs .................................................................. 230 4

s.

?

s.

v s

4 s.

a

w. . .

-u b..

t v.

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1 l

.:e i,

1:

FERC FORM NO.1 (ED. 12 90) Index 5 t$

>e*