Text

Responds to NRC Re TMI-1 Restart Proceeding & Forwards Second Info Request on Board of Public Utils Docket 804-285 to Appear Before Board
	ML19330C421
Person / Time
Site:	Crane
Issue date:	08/05/1980
From:	Sweeney L; JERSEY CENTRAL POWER & LIGHT CO.
To:	Vollmer R; Office of Nuclear Reactor Regulation
References
	NUDOCS 8008080361
	Download: ML19330C421 (77)
	v • d • e

_

1 Jersey Central Power & Ught Company Madison Avenue at Punch Bowl Road Mornatown, New Jersey 07960 (201)455-8200 i

August 5, 1980 Mr. Richard H. Vollmer Director, Three Mile Island-2 Support Office of Nuclear Reactor Regulation U.S. Nuclear Regulatory Co::: mission 7920 Norfolk Avenue Bethesda, Maryland 2001h Re: !~BC Docket No. 50-289 - TMI-1 Restart Proceeding

Dear Mr. Vollmer:

By your letter dated September 21,1979( to R. C. Arnold, and Mr. J. C.

Petersen's data requests sent to C. W. Smyth on November 9,1979. you requested ue to keep the NRC informed of significant regulatory developments affecting the GPU Companies. Accordingly, the enclosed material (8 copies) has been sert for that purpose.

Very truly yours, 0

cuwueLu Lawrence E. Sweeney Rate Department rc Enclosure ec:

L. F. Centieu (w/o ene)

M. Kar?cvics (w/ene)

J. C. Petersen (w/ene)

THIS DOCUMENT CONTAINS POOR QUAUTY PAGES 8003060 N Jersey Central Power & bght Company is a Memcer of the General Puti;c Ut;tities System

r i

g

.y

.t BEFORE.

THE

~ 5 BOARD OF PUBLIC UTILITIES OF NEW JERSEY

)

.In Re:

Notice of. Jersey; Central Power.

BPU Docket No. 804-285 and Light Co. of Requested Interim

)

OAL Docket No. 3518-80 and. General Increase in Electric

)

Rates

)

-)

SECOND INFORMATION KEQUEST OF THE FEDERAL EXECUTIVE AGENCIES ^

DELLON E. C0KER Chief, Regulatory Law Office U.S. Army; Legal Services Agency

.JALS-RL 2891 5611 Columbia Pike Falls Church, VA. 22041 For

-THE SECRETARY OF DEFENSE ERNEST C. PEARSON Trial ~ Attorney-Of Counsel s

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t

1 BEFORE THE BOARD OF PUBLIC UTILITIES OF NEW JERSEY

)

In Re:

)

Notice of Jersey Central Power

)

BPU Docket No. 804-285 and Light Co. of Requested Interim

)

OAL Docket No. 3518-20 and. General Increase in Electric

)

Rates

)

_)

SECOND INFORMATION REQUEST OF THE FEDERAL EXECUTIVE AGENCIES COMES NOW th'e Secretary of Defense, through duly authorized counsel

- and on behalf of the consumer interests of the United States Department of Defense and All Other Executive Agencies of the Federal Government, and hereby_ requests the applicant, Jersey Central Power and Light Company to provide the following information no later than two weeks following receipt of.this request:

4

,3

Please provide a copy of all data requests submitted by other 1.

parties to this proceeding and the Company's responses t,o these data requests.

Please provide a copy of the Company's FERC Form Nos. I and 12 for 2.

the years 1977, 1978 and 1979.

Please provide a map and one-line diagram of the Company's electric 3.

system.

Please provide a copy of the Board of Public Utilities Order in 4

Docket No. 801-45.

resale rate Picase provide a copy of the Company's most recent 5.

filing to the Federal Energy Regulatory Commission.

Picase provide any corrections, additions or revisions made to the Company's (9+3), 1980 Budget. Also provide work papers, supportive 6.

add or revise the Original (9+3),

data and studies used to correct, 1980 Budget.

The Please provide a complete allocated cost of service study.

allecated cost of service study should contain a detailed itemization 7.

of service, including, but not limited of the components of the cost operation and maintenance expenses, depreciation expenses, taxes other than income taxes, other operating expenses, income taxes, to:

plant in service, working capital, construction work in progress, The allocated cost other rate base items and return on rate base.

of service study should also contain the amount of each of the components of the cost of service allocated to each rate class, the allocation factor) and all the basis for such alloation (i.e.,

work p pers and supporting documentation thetefor.

2

- =

=

u

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~

Please provide the following items for the test year and all work 8.

papers and supporting documentation therefor:

~

,, 1.

Monthly energy usage by rate class.

2.

Monthly noncoincident peak demand usage by rate class.

3.

Monthly coincident peak demand usage by rate class.

4.

Demand loss factors at the primary and transmission levels by rate class.

5.

Energy loss factors at the primary and transmission levels by rate class.

6.

Customer weighting factors by rate class.

Please reconcile the information on Exhibit JC-101, Schedule 5, 9.

page 1, with that on Exhibit JC-203, pages 7 and 8.

Please reconcile the information on Exhibit JC-101. Schedule 1, 10.

page 1, with that on Exhibit JC-203, pages 9 and 10.

Please reconcile the revenues on Exhibit JC-101, Schedule 1, page 1, 11.

with those on Exhibit JC-203, page 5.

Please provide a detailed breakdown of the income deductions for 12.

income taxes on Exhibit JC-203, page 6.

13.

Please provide estimated balance of accumulated deferred income taxes (Accounts 281, 282 and 283) as of Dc:cmber 31, 1980.

14.

With respect to transmission plant, please provide a description and supporting work papers of the f acilities classified as " production related", " bulk power", "subtransmission" and " distribution".

15.

With respect to distribution plant, please provide a description and supporting work papers of the facilities classified as " production related" and " transmission".

16.

With respect to Cencral Plant, please provide a description and supporting work papers of the facilities classified as " transmission and distribution related".

Please provide all supporting work papers and justification for the 17.

Co'mpany's cash working capital allowance.

Please provide for each item in the allocated cost of service study 18.

y the justification for the allocation factor utilized.

3 tv I

19.

Please provide a detailed discussion of the reason for each normalizing adjustment made to the Company's Budget.

20.. Please provide the work papers and justification for the percentage"

figures under Column 4 of Exhibit JC-203, page 7.

21.

Please provide a copy of any studies undertaken by the Company related to the Rate Standards and considerations set forth in the Public Utility Regulatory Policies Act.

Please provide a discussion of the Company's methodology for choosing 22.

the rate of return for each customer classification.

23.

Referring to Exhibit JC-201, Schedule 3, please provide explanations and any work papers indicating how the unit prices indicated in Column 5 of each sheet of Schedule 3 were determined.

24.

Referring to the bottom of page 6 of the testimony of Mr. Eugene Carter, please explain how it was determined that a late payment charge should be applied to all General Service customers, with other rate schedules being exempted from the late payment charge.

25.

Please determine how the late payment charge rate of 2% per month was determined.

26.

Picase provide any and all studies, data or information which led to the determination of including a late payment charge applicable to General Service customers.

27.

For each rate schedule (including General Service and all other rate schedules), please provide the number and amount of late payments associated with each customer class.

The data should be for the most recent 12-month period for which data is available.

28.

Referring to page 12 of Mr. Eugene Carter's testimony, Mr. Carter states "the proposed rates and rate structures reficct the blending of several f actors and dif ferent weights given to each: cost-of-service, value-of-service, and essential human needs." With regard to that statement, please provide the following:

The definition of "value-of-service",

a.

b.

The definition of " essential human needs".

Please indicate how " cost-of-service" is quantified.

c.

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i 1

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i d.

Please indicate how "value-of-service" is quantified.

~

c.

Please indicate how "escential human needs" are quantified.

f.

Please state the "different weights" which are given to each factor.

g.

Please provide an explanation indicating how the weight to be given to each factor was determined.

Respectfully submitted, dh LLON E. C0KER Chief W

W5

~

ERNEST C. PEARSON Trial Attorney Regulatory Law Office U.S. Army Legal Services Agency JALS-RL 2891 5611 Columbia Pike Falls Church, VA 22041 For THE DEPARTMENT OF DEFENSE e

5 s

m_

e, o

CERTIFICATE OF SERVICE fSI I, the undersigned, do hereby certify that I have this day of August mailed, postage prepaid, a copy of the foregoing Second Information Request of the Federal Executive Agencies on all parties, C.-

s ERNEST C. PEARSON S

l A

~...

y July 24, 1980 JERSEY CENTRAL POWER & LIGllT COMPANY Responses to Rate Counsel Data Requests y

BPU Docket No. 804-285

\\

)

Response #

Description RCR 1 Ef fective Total Company Manning Level by function, by month for the test year - Also included is the estimated manning level for O&M.

RCR 2

'The 1979 Kwasha Lipton Report which determined the pension expense for the year.

RCR 3 A schedule from kwasha Lipton estimating 1980's pension expense.

RCR 4 A comparison of pension costs 1980 vs 1979.

RCR 5 An analysis of GPUSC charges for 1977, 1978 & 1979.

RCR 6 The service agreement between JCP&L and GEUSC.

RCR 7 The calculation of income taxes associated with TMI 1 & 2 7m for the test year.

U RCR 8 Analysis of the charges to account 557 for 1977, 1978, 1979

& 1980.

RCR 9 An analysis of overtime payroll for 1977, 1978 & 19 7 ').

RCR 10 An analysis of coal, gas and nuclear fuel costs for first

(

six months of 1980, actual vs. budget.

RCR 11 The budgeted cost of fuel oil purchases for the test year by type of oil by month.

RCR 12 The calculation of the effective cost of short term debt for the first six months of 1980.

RCR 13 An analysis of Plant in service at 12-31-80.

RCR 14 An analysis of Plant Held for Future Use at 12-31-80.

RCR 15 An analysis of the cost of oil purchased by type for the first six months of 1980.

RCR 16 Schedule of '.etentions & Liabilities 1979 & 1980.

RCR 17 Schedule of. Accounts Payable Balances 1979 & 1980.

f i

RCR 18 Schedule of Materials & Supplies balances *1979 & 1980.

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November 16, 1979 Cost and Accounting Committee Jersey Central Power & Light Company

[

Madison Avenue at Punch Bowl Road l

Horristown, New Jersey 07960 i

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Gentleaen:

The following report sets forth the results of our 1979 actuarial valuation of the Company's pension plans. It serves the purpose of analyzing the experience of the plans during 1978, comparing the plans' assets and liabilities as of January 1,1979, determining the appropriate charges to 1979 P&L f or pension expense, and describing various alternatives for the amounts to be contributed to the trust funds for 1979.

A brief sunmary of the principal results of the valuation (all plans combined)

(

is set forth below, together with the results of the 1978 valuation to f acil-itate comparisons k

i f

1978 Valuation 1979 Valuation

{

A. Coverage at January 1:

3 1.

Number of members:

k (a) Active.

3,518 3,694 1,

(b), Retired or terminated...

716 749 (c ) To t al...........

4,234 4,443 i'

2. Covered payro 1........ $65,587,245

$ 73,571,456 B. Punded status at January la e

1. Actuarial reserve f

requirement

$96,048,380

$106,593.913 1

2. Valuation assets...

$62.290.813

$ 67. 788.748 A

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3. Unfunded............ $33,757,567

$ 38,805,165 C. Pension expense for year:

E t

1. Current service cost.

r

$ 2,692,156 3 3,096,884

2. Prior service cost.

$ 3.444.165

$ 3.926.473 j

3. Total............. $ 6,136,321 4 7,023,357 p

1 1

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Kwesha Upton Cost and Accounting Committee f

Jersey Central Power & Light Company k

Page 2 The cost of the plans has increased by about $887,000, increasing f rom 9.4%

i of covered payroll in 1978 to 9.5% in 1979. De unfunded has increased by about $5,048,000. An explanation of these changes is as fo11 cuss o

r f

h Pension Expense Unfunded t

1. Increase due to salary

$486,000

$1,479,000 increases.

2. Increase due to investment

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experience (as measured on

[

a 5-year average basis) being less favorable than

$268,000

$2,9 77,000 8% assumed rate.........

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3. Increase due to plan

$201,000

$1,568,000 amendments.

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4. Decrease due to f avorable

($ 25,000)

($ 282,000) actuarial experience.

I

5. Decrease due to amortization n

0 (S 694,000) of unfunded r

6. Decrease due to funding

($ 43.000) 4 0

j t

of book reserves.

$887,000

$5,048,000

7. Total increase.........

L i

This report does not reflect any intended transfer of f unds f rom the reserves i

held on the books of the Company to the trusts under the plans. 'Although any

{'

such transfer will be considered as contributions for tax purposes, they will not af fect the amounts charged to P & L.

I This valuation reflects the 62/30 early retirement amendment ef fe ctive

[

January 1,19 79.

The assumption as to the number of employees retiring early g

has been updated to reflect the anticipated ef fect of this amendment. nis j

valuation does not reflect the Voluntary Accelerated Early Retirement Program.

l 7

b In our opinion, the actuarial assumptions and methods used are, in the f

aggregete, reasonable (taking into account the experience of the plans and reasonable expectations) and, in combination, of fer our best estimate of anticipated experience under the plana. Particular attention, however, should be paid to cost changes f rom wage and salary increases and invest-ment return dif f ering f rom the assumed rates. Although the assumed rates Of Pay increases and investment return represent our best estimate of the

f

+

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gwsshs Upton V

Cost and Accounting Committee Jersey Central Power 6 Light Company Page 3 i

average rates which will prevail over the long term future, we do not expect that these rates will be experienced in every year. llence, increases and f

decreases in cost are inevitable from year to year due to fluctuating economic Similarly, if increases in cost due to greater than assumed pay :

conditions.

to see offsetting increases continue over the long term, we would expect decreases in cost due to greater than assumed investment return, but such

~

of f setting decreases will not necessarily come about concurrently with the I

increases.

I The pension expense of $5,962,659 for the Plan for Retirement Annuities is l

composed of $3,650,302 f or bargaining employees and $2,312,357 for non-bargaining employees.

/

I As reported by Opinion No. 8, we have determined the unfunded portion of the actuarially computed value of vested benefits to be $585,923 as of January 1 19 79.

The valuation was performed by this firm on the basis of employee data and hm asset information supplied by the Company as of January 1, 1979.

Except as noted in this letter, the valuation was based on the 'same actuarial methods procedures, and assumptions as were used in the prior year's actuarial valuation and reflects the same plan provisions as were reflected in that valuation. We regard the actuarial methods, procedures and assumptions used in the valuation as reasonable and in accordance with (1) generally accepted actuarial principles and practices as prescribed by the American 1

Academy of Actuaries, (2) the provisions of Section 412 of the Internal Revenae Code and (3) the requirements of Opinion No. E of the American Institute of C.P.A.'s.

Respectfully submitted, Kwasha Lipton k, 7 7 k. Ob N M d

WC/vf t

,O '

Q V~

q n

r

~

?

i Kroehe Upton f *.

s~'

I(*.'

Jersey Centret Power 6 Lisht Ceepony Penelon Plane i

m,.., 8...,t.

Plea for supplemental Fxecutive b

8sttroment Peneton Fenelon i

Annuttles Plan Plane

M i

k A.

Coverage et Janvery 1. 1979

[

1 Itueber of participnetes 3.694 1.117 0

3.694 (e) Active I

I (b) Settred or tereinsted.

749

_ 178 181 749 vested

{

(c) Totet...........

4.443 1.293 101 4.443 p

2.

Annual payroll for active

$13.511.456

$24.792.206 0

0 13.S74.436 e

perticipante s

F

~

5.

Funded statue of plane et January 1. 1979:

1 Vested benefits onlys (e) Actuartet ty computed value 4

856.409.478

$ 4.976.894 92.397.197 5 63.783.369 of vested benefits e"

(b) Velvettoa essete s (t) Asset e et.erhet...

s68.527.450

$ 4.907.565 st.792.248 s 6s.221.265 i'

(tt) 1 year s u rene (1

576.87qi s

41. n2n.

s 4t 4_n (s

4)a. SIS)

[

edjust.ent.

s (1:1) Totet........

861.000.500

$ 4.949.46 3

$1.838.705 8 67.788.748 7

0 0

27.431

$ 558.492 9

583.923 (c) tecese of (e) over (b)

O 2.

All benefttes (e) Actuartet reserve require-893.641.00$

$10,5$1.711

$2.397.197

$106.193.913 ment...........

168.000.580 3 4.949.443 11_.814,705

$_67.789244 (b) Valuation essete (e) 17nfunded er unprovided,..

$12.644.423

$ S.602.248 9 558.492 8 38.n05.465 C.

Pension esponse for 1979:

$ 2.837.288 259.596 8

0 9 3.096.884 1.

Currest service rest.....

Y 2.

Prior service cost 8.3.125.371 9

713.A70 9

87.232 1 3.924.473 (25 year fundtas).

3 Totet.............

0 3.962.659 8

973.466 s

87.232 8 7.02).317 D.

Vertone contributtec pasei-bt11ttee for 1979:

1.

P6L c ha rg e...........

9 1.942.459 9

973.466 8

87.232 8 1.023.311 2.

Meeleus tes deductible 0 8.174.731 6 1.553.748 8

89.418 8 9.819.957 l-teatributton..........

3 Nintees tse deductible coe.

l tributtee required by i

Sectlee 612 of the laterne!

8 S.523.204 0

6 27.383

$ S.532.671 F

nevenue Cede *e.

k.

k

1ecludes New Jersey Power 6 Lleht Esecutive peneton Flee. for which penelon esponse to 438.490.

!l

- As?' tes paynest se 12/31/19. Seuld be decreeeed by se teterest credit if perment made before !!/3t/79.

d,.

PV i

i

K seha Lipton f;

(3 ;.

h b

Jersey Central Power & Light Company Penaton Plans Y

{

gre Sieet - As of January 1. 1979 k

Flan for Supplemental Executive Pession Plans t

Settrement Pension Jersey New h

Annuttles_

Plan Central Jersey a

Assets A.

Assets se reported by Company

)

$60,705. 290

$ 3.433,533 i,

1..

Cost volum 5

2.

Market value................

$61,663,099

$ 3,385,071

$1.129,544 728,707 f

)

8.

Adjustment to accruel bests:

1 f

0 0 $

0 0

1.

Contributtons receivable A

($

201,652)

($

74,862) $

0 0

2.

Transfer due free (to) other compantes 3 Transfer due for Executive Pension Plans f

(a) 1977 mortality espertence........

71,076 0 ($

72,414) 1.338 (b) 1978 mortality expertence........

($

5,073)

,8 0 $

6,133

($

1,060) 7 4.

8enefits due and unpaid...........

0 0 $

0 0

($

135,649)

($

74,862) ($

66,281) 278 5.

Het adjustment f

C.

Adjustment to reflect unrealised appreciation

(

(%

[

(deptactation) on five-year everage market l

v:*.:.e me thod.

($

526,870) 41,898 28,239 18,218 0

$ 1.597.356 0

f 0

D.

Reserves held on Company books f

E.

Valuation assetet (A2 + d 5 + C + D ].......

$61,000,580

$ 4.949,463

$1,091.502 8

747.203 i

f Actuarial Lta% tittles A.

Actuartal reserve requir s-ent s

$16,663,663

$ 1.843,84J

$1,403.980

$ 993,217 1.

Battred members....

2.

e ru tna t ed-ve st ed membe rs..........

534,344 150.895 0

0 h

3.

Active members...............

$76,446,998 8 8.556,973 0

0 4.

Total....................

$93,645,005

$10.551.711

$1,403,980

$ 993,217 j

8.

Unfunded or unprovided..............

832,644,425 8 5,602,248

$ 312.478

$ 246,014 C.

Liabilittee...................

$61,000,580

$ 4.949,463

$1,091,502 8 747,203

(

i 3

s i

t F

G *:

l I

T

~

~~~~~'~m"*"-~

" ~ ~ - - - " " '~~ "

Y.

5.

Jersey Central Power & Light Company Pension Plans 6

Receipts and Disbursements - Year Ended December 31, 1978 Plan for Supplemental

_ Executive Pension H an Retirement Pension Plan Jersey New Annuities Trust Reserves Central Jersey A.

Valuation assets as of

$56,055,023

$2,014.064 $2,129,808

$1,243,344

$ 848,574 January 1, 1978 B.

Receipts for year 1.

Contributions:

(a) Company..........

$ 5,104,103

$1,495.888 ($ 532,452) 37,887 30,895 764,628 0 $

0 0

0 (b) Employee (c) Total...........

$ 5,868,731

$1,495.888 ($ 532,452) 37,887 30,895

($

230,199)

($

74,862) $

0 3,587 ($

1,016) 2.

Transfers...

w

- 3.

Inves tment earnings:

$ 3,692,662

$ 169,457 $

0 77,225 49,323 (a) Interest and dividends

($

296,018)

($

13,247) $

0

($

6,981) ($

4,385)

(b) Realized gains (losses)

(c) Unrealized gains (losses) based on five-year average market value method....

($ 1,568,798)

($

11,798) $

0

($

52,051) ($

32,539)

$ 1,827,846

$ 144,412 $

0 18,193 12,399 (d) Total earnings

$ 7,466,378

$1,565,438 ($ 532,452) 59,667 42,278 4.

Total receipts

$ 2,520,821

$ 227,395 $

0

$ 211,509

$ 143,649 C.

Benefit payments for year.

D.

Valuation assets as of

$61,000,580

$3,352,107 $1,597,356

$1,091,502

$ 747,203 January 1, 1979 s

.m m oo -

= n - w --

~~r

~ m-Jersey Central Power & Lighe Company

(*

Pension Plans 1

Participation Information - Year Ended December 31. 1978 C

?.o*

Terminated Survivors Active Vested Retired Receiving Employees Employees Employees Payment Total

~

PRA SPP PRA SPP PRA SPP PRA SPP PRA SPP A.

Number at beginning of year...

3,518 1,029 69 17 555 117 92 22 4,234 1,185 B.

Additions:

1.

New members........

+306

+87 0

0 0

0

+306

+87 2.

Pickups...........

O M8 0

0 0

+48 3.

Transfers in

+4

+14 0

0 0

0

+4

+14 4.

Total added.........

+310

+149 0

0 0

0

+310

+149 C.

Deletions and transfers between categories:

1.

Retirements:

-10

-2

-3 0

+13

+2 0

0 0

0 (a) Normal (b ) Ea r l y..........

-18

-9 0

.0

+18

+9 0

0 0

0

-11

-4 0

0-

+11 4

0 0

0 0.

(c) Disability 2.

Deaths

-9

-6 0

0

-35

-5

-1 0

-43

-11 3.

Survivors becoming eligible

- for a benefit.

0 0

+4

+4 4.

Terminations of employment:

-22

-8

+22

+8 0

0 0

0 J

(a) With vesting (b) Without vesting.....

-50

-18 0

0 0

0

-50

-18 5.

Transfers out

-14

-14 0

0 0

0

-14

-14 6.

Other deletions.

0 0

7.

Net deletions and transfers

-134

-61

+19

+8

+9

+10

+5

+4

-101

-39 between categories 3,694 1,117 88 25 564 127 97 26 4,443 1,295 D.

Number at end of year.

I

~

g:*

9 y

~O v

~

CPU SYSTEM COMPANIES

'I Proieeted Company Pension Costs for 1980. 1981, and 1982

~ 1hamber Plan f or Supplemental Executive Testal -

of Annual Retirement.

Pension Pension As %

Baployees Payroll Annuities,

Plan Plan haount of Pay l-1979 3694

$ 73,571,456

$ 5,962,659

$ 973,466

$ 87,232

$ 7,023,357 9.55%

JERSET CENTRAL:

1980 3645

$ 78,200,000

$ 6,676,100

$1,036,600

$103,706 4 $ 7,816,400 10.00%

1981 3655

$ 84,382,400

$ 7,064,300

$1,066,400

$ 98,400 A) $ 8,229.100 9.75%

l

~ 1982 3670

$ 91,020,300

$ 7,576,900

$1,097,200

$ 98,300La) $ 8,772,400 9.64%

o 1979 2768

$ 51,395.472

$ 4,742,948

$ 767,997

$ 90,977

$ 5,601,922 10.90%

MET-ED 1980 2828

$ 56,398,000

$ 5,381,103

$ 860,200

$107,400

$ 6,348,700 11.26 1981 3024

$ 63,804,700

$ 5,805,300

$ 901,500

$102.100

$ 6,808,900 10.67%

1982.

3084

$ 69,663,200

$ 6.228,900

$ 937,100

$102,000

$ 7,268,000 10.43%

1979 4234

$ 76,785,424 S 7.164.158

$1,043,924

$ 90,030

$ 8,298,162 10.81%

PENELEC 1980 4047

$ 79,177,600

$ 7,805.500

$1,141,200

$108,600

$ 9,055,300 11.44%

1981 4070

$ 85,734,600

$ 8,258,800

$1,180,500

$102,700

$ 9,542,000 11.12%

1982 4343

$ 97,329,300

$ 8,993,500

$1,240,500

$102,500

$10,336.500 10.62%

$ 1,861,491 9.60%

CPU SERVICE CO.

1979 822

$ 19,396,016

$ 1,399,597

$ 461,894

$ 2,127,700 9.62%

1980 884

$ 22.111,800

$ 1,610,900

$ 516,800

$ 2,342,200 -

9 43%

1981 932

$ 24,828,000

$ 1,785,000

$ 557,200

$ 2,612,700 9.23%

1982 1004

$ 28,299,900

$ 2,005,700

$ 607,000 1979 i!*L8

$221,148,368

$19,269,362

$3,247,281

$268,289

$22,784,932 10.30%

TOTAL I

1980 11404

$235,887,400

$21,473,600

$3,554,800

$319,700

$25,348,100 10.75%

h 1981 11681

$258,749,700

$22,913,400

$3,705,600

$303,200

$26,922,200 10.40%

4 1982 12101

$286,312,700

$24,805,000

$3,881,800

$302,800

$28,989,600 10.12 g

j i

October 31, 1979 y

4 84';& 9

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t-g. e yt t v fid/2 - 6 ts N. GPU SERVICE CORPORATION 80 Pine Street l q New York, N. Y. 10005 e l STANDARD FORM OF SERVICE AGREEMEt:T l-j May 3, 1971 Is - i To JERSEY CEGTRAL POWER & LIGilT COMPANY Madison Avenue at Punch Bowl Road Morristotin, New Jersey 07960 GPU Service Corporaticn (hereinaf ter called Service ' Company) is a compcny engaged in the rendering of services to 1 i companies in the General Public Utilitiec Corporation holding-g company system. The organ 1:ation, conduct of business and method i - of cost allocation of the Service Company are designed to meet the requirements of Section 13 under the Public Utility Holding i i Company Act of 1935 and the rules and regulations promul ated 9 j thereunder to the end that services performed by the Service Company for said associate companies will be rendered to them at i cost, fairly and equitably allocated. Services will be rendered by Service Company only upon receipt from time to time of specific or general requests therefor. Said requests may always be modified I l-or' cancelled by you at your discretion. The parties hereto agree f as follows: i I 1. Service Company agrees to furnish you upon the terms and conditions herein set forth such of the services desevibed in i f Schedule I hereto as you may from time to time request. Service i company will also furnish, if available, such services not described in Schedule I as you may request. I

y i,. a. p M 7 .s ] y e% .,:2. Service Company has and wil1 mal'ntain a staff ~ . w.z ~ . jf trained and experienced in..the'designi construction, 6peration, 4}f ~ 3; il L / maintenance:and management of public, utility properties. In

[

addition to'the. services of its own staff, Service Company will, di ~ ' L} --after. consultation with you:concerning services =to be rendered -.pursuan't to your request,(arrange for services of non-affiliated t 7,...li j. . t [ .}~ ^ experts andlconsultiints. .j .z., {.- ;) r-y 3.-All'of the services rendered under this ' agreement i q I, , j- ~ will be at actual cost thereof. Direct cha.ges will be made for l_ i l- .I' j i- -: service's where a' direct allocation fof cost is possible. The 4 - al - r i 'i [ me'thodsiof determining.such' costs and the allocation thereof ' ~ ' .s. t are set forth in Schedule II hereto. ~These' methods are reviewed i l .l s annually and more ' frequentlyj - if appropriate. Such methods may } 'i i i be modified or changed.by Service Company without the necessity I 2 'l .of an amendment of this agreement provided that in each instance l .all services rendered hereunder will be at actual cost thereof, a-l .-fairly.and' equitably allocated, and$all in accordance with the ~ ~l l , requirements of the Public Utility Holding Company Act of 1935 .I ~,; ' and'the7 rules and regulations and orders thereunder. You will -be advised from time to time of any material changes in such I' methods. .-) - 4. - Bills will be rendered as soon as practicable af ter .the close of each month'and will be payable within ten days after . receipt. This agreement may be terminated at any timo by either .1 party giving at least thirty days' written notice to the other + t of such termination'as at the end of any month. '5'. This ' agreement will be. subject to termination or -t. ~ w. .. w-s y/- 4 y T 4 f .r <3

e 't 'J modification at any time to the extent its performance may con-flict with any federal or state law or any rule, regulation or t order of a federal or state regulatory body having jurisdiction. The agreement shall be subject to approval of any federal or state regulatory body whose approval is a legal prerequisito to i its execution and delivery or performance. i i GPU SERVICC CORPORATION By / President Accepted May 3 1971 JERSEY CENTRAL POWER & LIGHT COMPANY By rj- / i. v President 4 I s'%y ' a/ e 4 0 g. s L

p, y c - w' ,3 j-h, . ~.

-.. + ~

cC ^ SCIIEDULE I i ,A. s y7 e t - t.DescriptionL of Services' whic ara.. s-f 4- -available from1 GPU SERVICE CORPORATION.J s ,: 0 w a

{_ -

3 f 1s .. Accounting and auditing . 4 9 3. 2 jf f t; t 1 The keeping of accounts and collateral activities, El !: 3 -- s including billing, payroll and customer relations; prepara - .l. 5 1 ' tion'ofl reports and preservation of. records, review of u. T: 1 ^ -internal controls and audits, preparation of statistical j ha'taand' reports-andanalyses.' 3 1 -4 ' g. [. i, it l. u m Constrdetion' and malintenance b + - v' * ~ !~, L, Assistance in ' the supervision of construction and a ! maintenance of' electric and steam utility properties and .]. = in obtaining,=and supervision of, non-affiliated contractors. i JWdn; 1 .i Corporate and coroorate records i iV - Cooperation with officers and counsel of associate companies on corporate matters, regulation, contracts, claims, litigation, securities transfer,' and preferred stock dividend, l I interest and sinking fund disbursements. Services in connec- -[ I i-tion with stockholders' and directors' meetings and keeping i of-corporate records. -n 1~ Data processing' ~ , -i: Maintenance and operatic of data processing center and i. equipment fot; accounting, engineering, administration and other functions, and' development of systems therefor. 1 .i'.. 'g-e r 4 4 1 ~

f'

~ e 9 .e 4 y -s e -

7, ~ - 7 = -:,J: + Q -Q. .<,. f lbedian servicos-

)- y Assistance in the design of,"and preparation of-.specifica-4

}. tions and standards for,' -steam'. hydroelectric, nuclear and -- i s

"'I 7

-1 t, t

other. electric generating transmission and ' distribution e

+ ' f acil'ities' ' technical advice, supervision, planning, research, Q 1 and testing of such facilities and of speciali::cd technical. i' equipment. Executive and administrative, consultation and services.in' management and administra- ' tion'of all_ aspects: of: electric and steam utility business. - a I i}. , j; Financing-J -: ~ ' Services in connection' with interim and permanent 1 financing of associate companies, determination of capital needs,-cooperation with officers and counsel.of associate companies on financing matters, including registration state - 11 ~ ments and regulatory' applications; cash management; budgeting; ,,_s / j. 1 '\\/. l preparation of financial and statistical reports. s ]' ' Insurance and emoloyee benefit progr'ams ~ 4

Development, ' placement and administration of insurance coverage and employee benefit programs, including group

~ , insurance,-pensions, hospitalization and similar programs; 't li -property. inspections and valuations for insurance.- I Operatiois ~ j Operating coordination and analysis,-maintenance schedule, i central ' load' dispatching ' communications for operations; .- i.: i .:+ - o } S-t- ~ l' ? 3 - ...pg -I ~ .y - r s 'q

Q' s e L -e , : t,.. N - j' tJ - V. 1.f>. PT -j+:- p-j,,P * ?. f* ,g ; } assisting -in' connection with regional power pools and planning et u., E1-77 glj organizations,1 1 9 y. -y

\\

f. 4

i-i

,'j iPersonnel j y-b,' ~ Assistance' relating to w&ge and salary administration,. [ t.. e. ,r l-L - < - 4 .[7., employment procedures and policies, employee training and i . n ',' c ^ ,y qy g-safety and1 recruitment. l ~ t -[ } i r I ublic information and rel'ations' i ~ / P i i c - }t, ' Services' relating.tv it. formation to and relations i h t a 1-with the public, including customers, security holders, t i -J'- j- ) I . : v employees,- financial analysts yrating agencies, investment, t i , 'j !G { j, 1 ll } l-i . firms and employees. 3 r j.i c .g [ '} Purchasinc and stores-4 -i 7 - s j i 1, ' Services with respect to purchase and storing of 4 ,s y; > + materials, supplies, equipment, and fuel (including nuclear. Lj fue l) '. / ,g. u-y bi-j s- .Raten and economic research ~ Review,; design, interpretation, enalysis and other I s'ervices reltcing to rates and rate structure; assembly of l -i '~ 1 data and coordination of presentation for rate proceedings; r ~ r ' preparation and review of economic and depreciation studies; . budget analyses. 'Research and development. Services relating'to research and development of j. .i' facilitics 'and usos ' involved in the conduct of electric ) -t

lS

-utility operations.

).!

- 3,' r 1 .s ? '{t

j. gy r.

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~ tSel**' coordination- ~. Q ; Oi%r g L.... , ( $' ' . _ ' ;c o-e O ]z < ;jj, ', r ,1 1 l'i - (- -industrial ~ sales of electricity with emphasis on improving 4,- l. . a )* . load factor t assisting local cdundunities-in. area. development h Qf i i~ ~_ fprograms coordination of advert,ising...-. L1 m' { 1 2-q. y a. y jj -l~ - 1 System Planning' and Develoo.nent ' t- ,s, -4s ' Planning and other services for supply of electric I .i power, and negotiation of.. contracts therefor; load and capacity - '+ ' forecasting; system and regional planning studies. ,) q c. Taxes- '/ e ~ Services re federal, state a' rid municipal' taxes, j ? n ~ ,b preparation of federal returns hnd. handling of federal i -t I

~

' return'audith'and claims. 1 r e p.., } - f- . Water Resource Develoonents [- Aissistance relating to the. evaluation and development ~ () 'ofwaterresourcesforhydroelektricand.other;uses;andin I e. .i. L the preparation of plans and applications relating thereto. g. . [ t- .l' ]- + i._. i 'i, t f ..'T.. z.ya. '~ j-al:, e + 4 e" g s ,s eA* 5= 3, j 4 [,.' -[' y f 4 / i .c i p-

7 e

( .p v i b' 4 f,- - I 4 S 4 ,p, .~I [. l. ir 1*- f L /._ m

. 2

m.. g O l '. N V i ' SCHEDULE II- -h. i,. 5 ;} w Deteraination of-Cost-bf Service .2Q ~. N ' _.4.%

jj

~'and Allocation,thereyf) - W + ... u u v %. p 1. . o u.2,,,,, at 1 .+ y; tL r vu%.m. , gQ; _ _2 Cost' of ~ service will be determiqed in accordance with N.,14. ., _- p . },,d ; l ;' ~ y 'f ' ' q d z 1 ' P; L 1 the Pub,lic Utility Holding Company, Act of 1935 and the rules and s 1.. wme -. e.> ;;r - ,.:M;.~.. s +ie. q. ry. ];'7.6 regulations' and orders thereunder, and wil-i.nincluda,.all. costs of .e. ' y, .I h. ?, t .. j doing business incurred by the Service Company. .?y - Records will be maintained 'for each Department and nW 'i'

f' 1

9. 3 '. j Division of.the Service Company in order to accumulate all costs }.. . + ' ?r m .4 s

b

.r..t.I 'of doing business and to determine the cost of service. These

r.

I ug" D., p. costsiwill'includd wages and salaries of employees and related {

,l' 0

- TM/ i l. ,I '. J ?.

V'i expenses such as insurance, taxes, pensions and other employee'

+ ~.KP O -welfare expenses, and rent, light,theat,' t'elephone, supplies, ~ q.r. i ~ 7;* 3- ., g s.. J and'other housekeeping costs. 'In addi lon, records will be

,i

,+ c, maintalhe'd'Tf general, administratNe expenses', which will include 3 %. 'q j ~ u;.f the costs of operating the Service Co"tpany, as' a corporate entity, i i

- V-+ y d

.r., ! Charges for.' services reridered and relht'ed expens,es and -() ' i, 4 - r-non'-personnel expenses (e.g., use of automotive equipment,[etc.); j, Y,- '

i. 'C /.

will be billed directly to the serviced companies, either indivie.- ~ t t u 9, - % %E ually or, when the services performed are for a group of companies, J O by means of an equitable allocation formula. w,. ., - y ' i,", Charges for services will be determined from the time _ y p-J' =t sheets of employees (other than secretaries, clerical and similar r. n employees,--the cost:of whose services will be treated as,a part g ? P

f. d; 7 4

q ~ ~ of general administrative expenses). l Records of such related t ' fre c ~ expens'esj an,d gen'eral administrak$ve' expe'nsEs'will be maintained l _..(- m. -gg.. 3 and subjected to periodic revieS _.x d 2 1? v - g p j. -".g.23 . w.+.g g. + t, A.<- j;3y. G' r v I, 1_ (. - f*% 4 .j. --g )4 v. g. nc, L t 4 4 e f a 2-s -. A. J. '-i..

V e y Out-of-pocket enp nsco ithich are 1.. curred for the I' 4

.f 4

- serviced companies will be billed at cost. Charges for non-i t personnel expenses,. such as for use of automobiles, will { i normally be computed on the basis,of costs per hour or por j nL1e. f

g.,

m i, 6 7"

: 5 j, 13.

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V 4 s - 9 6/30/80 (Preis) JERSEY CENTRAL POWER & LIGHT COMPANY DOCKET NO. 804-285 Rate Counsel Data Request: Provide explanation for number of tree trinsning crews reflected in. Normalisation Adjustment No. 5 (JC-101, Schedule 2 page 6). Also, pre >ide I correspondence: related to the Company's committment to the,NJBPU Staff regarding tree trinaning. Response: -See attached. l l' e s i A e I-. L

i t i JERSEY CENTRAL POWER & LIGHT COMPANY Tree Trinssint t- . The tree. trisuning adjustment in the rate case reflects the costs of ~ having 42 Distribution crews and 5 Transmission crews for the full year. This level -of crews would allow the Company to establish a regular mainten-ance tree trimming cycle and reduce customer outages - and improve system reliability. Over the_short run a total 47 crews would allow about a 6 year cycle. Ultimately the, cycle would be reduced to the optimum 4 years which allows a measure of preventive maintenance. Attached is a memo from the.BPU staff requesting information regarding the company's tree trimming policy. Also attached is the Company's response to that request. ? -1 a

p -.. a. '-- ? 1 i..'.W; ~* R$b,fa,-. 's .0CI E 0%,1 Mi!!?CT[.Tru!3}fr3FU f DEPARTMENT CF ENERGY -l BOARD OF PUBLIC UTILITIES ~ t sco n4meno si.vo. October 18, 1979 Newanx. s tw seassy c7:o?. Re: Policy regarding tree trimming (M-51-79) R. M. Wij non, Senior Vice President Floyd C. Cnic, Senior Vice President Atlantic City 51cetric Company Operations 1G00 Pacific Avenue Rockland I;1cetric Company Atlantic City, :Icw Jerst, 08404 One Blue Hill Plaza i Pearl River, Now York 10965 / Donald L. Carcy, Administrator Regulatory Affairs Benjamin A. Pitts,.Goneral Manager Jersey Central Power & Light Company Sussex Rural Cicctrici Cooperativo !!adison Avenue at Punch Bowl Road 22 East Main Street Morristown, New Jersey 07960 Sussex, Ncw Jersey 07461 James R. T.acey, General Solicitor Public Scrvice Electric and Cas Co. 80 Park Place Newark, New Jctsey 07101

Dear Mr. Carcy:

The~ Board is concerned to sco that the electric utilitics under its jurisdiction are tuking appropriato measures to insure the public safety and to minimize the outagc.; where power lines are,invojved with trees and trce limbs, under normal conditions and during stormy weather. .i Will you please arrange for appropriate members of your staff to meet with the Board's staf f on November 0,.1979, at 10:00 a.m., at which time your staff should be prepared to present in full detail your company's policy on this matter. Will you kindly ask your staf f to preparc a written narrative for' presentation at the meeting. The narrativo should include a general discussion oC yo'ir enepany's pnt icy and ilsn includ.e, but. not ha li mi e.ed, i to,the following:

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a. l o:.'.' =.n .~. \\ 1 \\ o 2. I Your company's annual budget for tree trimming for the past three years and for the coming year, including the amounts l actually spent. The number of service interruptions or incidents affecting safety where safety, trees or tree i limbs were involved, by service area, district j or reglen,~ fcr the past three years and to date this year. The number of customer-hours of interruption time attributed to trees or tree limbs, for the past three years and to date this year. The 1cngth of primary or secondary lines which could be af fected by trees or tree limbs, by region, district or service area. The average restoration tire fcr outages involving trees or tree limbs for the past three years and to date this year. The procedure used by your company to roccive, evaluate and respond to reports of outages or unsafe conunions involvino t.:.eu or tree 112.s. The number of man-hours devoted to tree trimming as a routine maintenance matter for the past three years and to date this year. In addition, please include an explanation of your company's policy for coordinating with local officia1n to roccive information about the nature, extent and duration of power outages in general in their particular community. Very truly yours, 4 Myy& - CS/cw Ch o r J c e. Shopd. f, Chief Bureau of Engineering Operations

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E 1_ n ) Jersey Central Power & Ught Company h ,b,y, j Madison Avenue a. Punch Bowl Road 4" r Momstown New Jersey 07960 (201) d554200 November 7,1979 Mr. Charles Sheppa, Chief Bureau of Engineering Operations Board of Public Utilities 1100 Raymond Boulevard Newark, NJ 07102

Dear Mr. Sheppa:

The following report concerning Jersey Central's Line Clearance Program is furnished in response to your inquiry of October 18, 1979. The main objective of the Company's Line Clearance Tree Trimming Program is to provide adequate clearance between trees and overhead conductors while at the same time preserving the symmetry of the trees as much as possible. To accomplish this, the Company employs the ser- ~~ vices of qualified line clearance contractors who operate under the-- direct supervision of the Operating Department and the Company's Forestry section. In April of this year, due to financial restraints, the number of tree crews was substantially reduced. Because of this, tree trimming priorities were redirected mainly toward 3-phase primary circuits. Single phase primaries and secondaries are presently being trimmed as needed, based on the number 'of inter.ruptions and customers involved. Data for this determination is taken from our computerized, tree report system. With respect to tree rem 9vals, if a municipal authority or an individual customer requests the Company to remove a tree that is posing a threat to our facilities, the Company may: After investigating and evaluating the condition, deenergize the conductors, remove the conductors, or top the tree down to a point where it can be safely removed by the requesting party or their contractor. For new private property extensions. 'it is the responsibility of the customer to provide adequate tree clearance prior to the installation of the line. l The Company's annual maintenance tree trimming budgets and actual expenditures for the past three years were: Year Budget Actual 1977 $2,090,934 $2,072,017 1978 2,731.700 2,922,100 1979 3,130,700 '1,307 624 (Estimated f Through Dec ember) The maintenance tree crimming budget for 1980 is $2,801,800. Jersey Central Power & t.ight Comoany c a Member of the General Puhic I Hetw*t Sm ,y-g

.m r i Mr. Charles Sheppa, Chief November 7, 1979 I I j The number of tree-related,qervice interruptions and incidents where t-trees and safety were involved for the past three years and to date are: 1 I Incidents Involving Se rvice Trees and Safety 1 Year Interruptions Injuries Fa talit ies j g 1976 2,812 3 1 s j 1977 1,710 4 l 1978 1,996 1 1 i 1979 1,255. l Customer hours of interruption time attributed to trees for the past three years and to date this year are: I Customer Hours Year of Interruption I i 1976 574,108.6 (Includes storms) 1977 131,352.4 (Includes storms) _. 1978 - - ~ ~ 329,390. 5~ (Tncludes ~ storms) 1979 149,666.0 (Excludes recent storms) The length of primary and secondary overhead lines that could be affected by trees in our service area this year is approximately 9,050 miles. The average restoration time for outages involving trees for the past three years and to date are's Average Restoration Year Time / Hours 1976 3.182 (Includes storms) 1977 1.573 (Iceludes storms) 1978 2.678 (Includes storms) 1979 2.327 (Excludes recent scorms) When a report is received by the Company of an outage or an unsafe condition involving trees, an Investigation Order is immadiately filled out. A supervisor or his delegate is then assigned to investigate the condition. Depending on the circumstances, the location may be recorded for future trimming, or a crew may be dispatched at once to remedy the situation. e

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-11 ..i w _. .w f , Mr. Charico Sh2pp3,- Chief i Novemb::r 7,1979 s y The average number of man-hours devoted to routine maintenance tree trinssing for.the past three years and to date are: .. f. Average Number - g Year of Man-hours -,I. i.. 1976 %92Q. - --- 1977 119,040 5-4, y 1 1978: 140,160 s 1979. -71,126 i ) 1 To facilitate and coordinate restoration of electrical service } during and after a storm, the Company activates a Storm Emergency Operating Plan. Cencrally, the policy states: That when the Company's operating facilities are disrupted to an extent justifying the declara-tion of an operating emergency, a Storm Emergency Center will be put N operation. It.will be manned by the following supervisors or their delegates: s' The Vice-President of F.ngineering and Operations will supervis,e, the restoration-progress and coordinate operations, such as shif ting l crews from less affected divisions to divisions in need of more help, and obtaining special equipment or outside crews if the need arises. e The Vice-President of Engineering and Operations, or his delegate, will also relay information of public interest to the delegate of the Com-munications Services Department. i The Manager-Corporate Communications, or his delegate, will receive all restoration reports f rom the divisions, coordinate these reports, and report to the Board of Public Utilities via the Administrator.of. Regulatory Affairs. , -.s The Director of Communications Services, or his delegate, will-direct and coordinate dissemination of information to various news - i ' media. The Director of Communications Services will also pass along information to other members of the Consnunications Services Department l wtio will work closely with the press on local coverage. The Director of Consnunications Services, oc his delegate, will reply to inquiries for Company-wide'information which can be expected f rom major news-papers, radio, television networks. and wire services. In addition, local civil defense'and police departa,ents are furnished with a list of local Company management. personnel and their unlisted tele-phor.e numbers to provide for a direct channel of communication regarding the nature, extent, and duration of power outages in their particular communities. g 9 w g .w yww -qpq er-.-+. m w g----w v9,w,y--p+w +-- -p.p y-yp-- q-yy-v,. sui y e gwmp9--w--,-t-.s-w-3'-sem+ gi -emi-gTr'w9ei-7

.s - -, _ 3, Mr.'. Charles Sheppa, Chief-I -4'- November 7, 1979 .t: 6 i l' As I previously mentioneld, the number of tree crews was substantially reduced in April. However, on November 5, we initiated a recovery olan which provides for the addition of three maintenance tree crews each month ~ until September of 1980. ..By September, we will be staffed' with 45 etews, as compared to the 47. crews we had prior to April 9. 1979. Sincerely. }A f f / P. undrane Vice-President - Engineering and Operations dea t h** = -e

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I.- .s P I I i 6/30/80 (Preis) ' JERSEY CENTRAL POWER &' LIGHT COMPANY DOCKET NO. 804-285 Rate Counsel Data Request: Provide the Operating Income and Rate Base data associated with Three Mil'e Island #1 that is reflected in the filing. Response: See attached schedule. .1 ? 4 d Y ~ b = -. 4 ~ - ~. ~ _,. _ _,.... _,,,

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s_ _. _., tc ~ 6/30/80 (Preis) ~ -JERSEY CENTRAL POWER & LIGHT COMPA'"i . DOCKET NO.' 804-285 Rate Counsel' Data Request: Provid support for Pennsylvania Corporate Net Income Tax allo-cating' factor (JC-101, schedule 2, page 13).

Response

-i Attached are sample pages of the Pennsylvania Corporate Tax Report wherein the allocating factor is computed. Also attached is a more detailed schedule of the amounts shown on the sample form. a ~ 7 ? m E Y

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's 3 5' 6/30/80 (Preis) 6. JERSEY CENTRAL POWER & LIGHT COMPANY i. DOCKET NO. 804-285-a Rate Counsel Data Request: Provide updated actual vs. budget comparisons of energy costs in'the Exhibit JC-B format (Docket 801-45) through May 1980. Also provide ' budgeted energy costs for the remainder of 1980. ' Response: See. attached. ~ -a I f s t 0 4 ? ? f 9 -*d 1 6 y, a .'Y l . y ' (; 'l 4 5 k } e i 9 4 n.% a

7 -- e IRSEY CENTRAL power & LIGHT C9MPANY i Energy Cost Comparison, Actust vs. Forecast March 1990 l Actual Forecast incr.. Actual Over Forecast $000's Cwh Mills /Kwh $000's Gwe Mills /Kwh $000's C=h Mills /Kwh '? l Internal Ceneration Nuclear Oyster Creek' 3 (3) 730 185 3.9 $ (727) (188) (3.9) TMI-1 (2) (2) Total 3 (5) 730 185 3.9 (729) (190) (3.9) Coal i ~ Keystone 1 123 105 10.7 851 70 12.2 272 35 f 011 and Gas C11bert 1 527 '33 46.3' 1 414 32 44.2 113 1 2.1 Gilbert Combined Cycle 733 12 1 61.1 1 671 37 45.2 (938) i (25) 15.9 Seyrev111e 4 670 105 44.5 3 745 83 45.1 925 22 (.6) Werner 754 ~ 14 53.9 1 311 28 46.8 (557) (14) 7.1 Combustion Turbines 2 550 34 75.0 2 811 41 68.6 (261) (7) 6.4 Total 10 234 198 51.7 10 952 271 49.6 (718) (23) 2.1 Pumped Storage Yards Creek. (11) (8) (3) ) Total Internal Generation M 287 M M 468 M M) M) IL,9,, Interchanae and Other' Energy Purchased Interchange Purchased from PJM $23 602 429 55.0 $30 136 661 45.6 $(6 534) (232) 9.4 [. From CPU 902 14 64.4 674 27 25.0

228 J1,3,)

39.4 3 } Total 24 504 443 55.3 30 810 688 44.8 (6 306) (245)' 10.5 Interchange (Sold) To P,1H (424) '(2). (424) (2) To CPU O f l Total (424) -(2) 1 (424) (2) l .c Other Energy Purchased } APS & West; 11 286 348 32.4 734 32 22.9 10 552 316 9.5 Jamestown ' 197 8 24.6 154 6 25.7 43 2 (1.1) Ontario Hydro 1 997 63 31.7 972 28 34.7 1 025 35 (3.0) I l PP&L 2 359 ' 51 46.3 2 359 il 46.3 g Cleveland Electric 907 29 31.3 907 29 31.3 l Central Hudson . Total 16 746 499 33.6 1 860 66 28.2 14 886 433 5.4 e i i Total Energy Purchased (1et) $40 826 940 43.4 $32 670 754 43.3 $ 8 136 196 .1 R wanus from Sale of Waste Heat (235)' (68) (167) Total Eneroy Costs M W M $45 1% M $ 6 916 5 5.4. $51 951 l'163 44.7 $45 135 1 132 39.9 $ 6 916 31 4.C Total Sales J. <k' 6 8

7 i e JERSEY, CENTRAL POWE3 & LICHT COMPANY Energy Cost Comparison, Actual vs. Forecast April 1980 k. Actual Forecast Ince.. Actual Over Forecent $000's Cwh '. Mills /wwh $000's Cwh Mills /Kwh $000's Cwh Mills /Kwh i Internal Generation Nuclear Oyster Creek 8 (3) $ 1 486 379 3.9 $(1 47,8) (382) IMI-1 (2) (2) Total 8 -(5) 1 486 379 3.9 (1 478) (384) Coal Keystone 1 512 "151 J 10.0 909 74 12.3 ~ 603 T71 (2.3) 4 011 and Cas Gilbert 1 303 30 43.4 1 374 31 44.3 (71) (1) (.9) Tilbert Combined Cycle 124 1 124.0 1 657 36 46.0 (1 533) (35) 78.0 Sayrev111e' 3 313 80 41.4 2 726 60 45.4 587 20 (4.0) herner 114 1 114.0 297 6 49.5 (183) .J5) 64.5 Combustion Turbines 573 10 57.3 2 830 40 70.8 (2 257) (30) (13.5) Total 5 427 122 44.5 8 884 173 51.4 (3 457) (51) (6.9) Pumped Storage Yards Creek (13) (6) (7) Tttal Internal Generation $ 6 947 255 27.2 M 620 18.2 $(4 332) g) y Interchance and Other Energy Purchag interchange Purchased From PJH $.5 815 151 38.5 $17 146 376 45.6 $(11 331) (225) (7.1) From CPU 647 24 27.0 542 22 24.6 105 2 2.4 Total 6 462 175 36.9 17 688 398 44.4 (11 226), (223) (7.5) Interchange (Sold)'l f. To PJH (808) 1(15) 53.9 (808) (15{ 53.9 To CPU Total

(808)

(15) 53.9 (808) (15) 53.9 1. Other Energy Purchased APS & West < 6 555 213 30.C 734 32 22.9 5 821 121 7.9 Jamestown 242 10 24.2 154 6 25.7 88 4 (1.5) Ontario Hydro 2 255 64 35.2 972 28 34.7 1 283 36 .5. PP&L 1 561 34 45.9 1 561 34 45.9 Cloveland Electric 8 983 291 30.9 8 983 291 30.9 Central Hudson Total 19 596 612 32.0 1 860 ,66 28.2 17 736 546-3.8 Total Energy Purchased (Net). M 772 32.7 $19 548 464 M $ 5 702 g_ g) - Revenue from Sale of Waste Heat. (189) (69) (120) b 'T:tal Eneray Costs M 1_qn 31.2 $30 758 M84 29.4 M g) y TotalSah 10J0 W M $30 758 1 062 M M 2.5 g

t ~ 'l o i ? .k l .IRSEY CENTRAL POWER & t.!GHT C0ffANY Energy Cost Comparison, Actual vs. Forecast May 1980 Actual Forecast Ince.'. Actual Over Forecast g 1 $000's Gwh ; M111sNwh $000's Gwh MillsNwh $000's Own M111sNwh I s } Internal Genere' tion e' Neclear. 1 Oyster Creek 9 (3). $ 1 595 392 4.1 $(1 586) (395) (4.1) .THI-1 (2)> E (2) Total 9 ( 5) ?,' 1 595 392 4.1 (1 586) (397) (4.1) p Coal '6, Keystone 1 480 ' 146 10.1 1 695 139 1255 (215) 7 2.1 3 e 011 and Gas i~ f ] 4 Gilbert 1 291 29 44.5 1 431 32 '44.7 '(140) (3) (.2) Gilbert Combined Cycle 854 14 61.0 1 751 37 47,.3 (897) (23) 13.7 Sayreville 3 611 105 34.4 2 848 '61 4d.7 763 44 (12.3) Werner 328 5' 65.6 1 339 28 47.8 (1 011)~ '(23) 17.8 l Combustion Turbines, 1 264 19 66.5 3 000, 42

71. 4 (1 736)

(23) (4.9) Total 7 348 172 42.7 10 369 200 51.0 (3 021) (28) (9.1) Purped Storage Vards Creek (8) (5). (3) Total Internal Generation $ 8 837 30 5 M $13 659 J g M) ) g 4 ingehange and Other Energy Purchased Interchange Purchased "g from PJH $ 1 595 37 43.1, $11 743 257) 45.7 $(10 148) (220) (2.6) From GPU 976 28 34.9-1 125 48 23.4 (149) (20) 11.5 Total 2 571 65;:, 39.6 12 868 305 42.2 '.(10 297) (210) (2.6) p i Interchange (Sold) To PJM (3 263) (53) 61.6 (3 26,'3) " (53) 61.6 Ts CPU -l (154) (7) 22.0 154 7 (22.0) Total (3 263) (53)" 61'.6 (154) (7) 22.0 O(3109) 5) 39.6 E; I. Otter Energy Purchased i. APS & West-6 706 235 28.5 734 32 22.9 5 972 203 5.6 Jamestown ; 163 7, 23.3 154 6 25.7 9 ,1 (2.4) Ontario Hydro 2 564 69 37.2 972 28 34.7 1 592 41 2.5 i PP&L 1 315 32 41.1 1 315 32 41.1 3-Cleveland Electric 10 797 350 30.8 10 797 350 30.3 j. Central Hudson 739 15 49.3 739 15 49.3 . Total 22 284 708 31.5 1 860 66 28.2 20 424 - 642 3.3 j. Total Energy Purchased (Net) M 720 30.0 $14 574 344 - 40.0 $ 7 018 356 (10.0) Revenuet f rom. Sale of Wai.te Heat (272) (80) (l92)' .g,. ,. Q,,, Trtal Energy Costs," M ' LO,22 M ig8,,LJ1 l'090 'Z5.8 $ 2 604 ig,5) y 8 5 3- } . Total Sales M 916 _M $28 153 962 M > $ 2 004 g) y (,, d. y, 74 c r a L-

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,o; l ' JERSEY CENTRAL POWER & LIGHT COMPANY Oi1 Cost Comparison, Actual vs. B'udget ~ January - May 1980 -(000's) As Burned As Per % Incr., Delivered Budget Actual' Actual over Budget (Actual) January . Cost- $10 562 $11 936 13.0 $ 6 670 Gallons... 17 252 18 430 (0.7) 9 069 Cents / Gallon-61.22 64.76 5.7 73.55 $ per Barrel $ 25.71 $ 27.20 5.8 $ 30.89 -February Cost $10 044 $ 9 069 (9.8) $ 4 184 Gallons 16 153 13 561 (16.1) 5 267 Cents / Gallon 62.18 6.88 7.5 79.44 $ per Barrel $ 26.12 $ 28.09 7.5 $ 33.36 March -Cost S 9 883 $ 5 497 (44.4) $ 3 938 ' Gallons' 15 609 7 739 (50.4) 4 906 J Cents / Gallon 63.32 71'03 12.2 80.27 $-per-Barrel $ 26.59 $ 29.83 12.2 $ 33.71 April Cost' S-7 819 $ 1 190 (84.8) $ 3 037 Gallons 12 062 1:729 (85.7) 3 632 Cents / Gallon 64.82 68.83 6.2 83.48 $ per Barrel $ 27.22 $ 28.91 6.2 $ 35.06 May . cost $ 9 292 $ 3 659 (60.6) $ 2 292 -Gallons 14 241 5.207 (63.4) 3 035 -Cents / Gallon 65.25 70.27 7.7 75.52 $ per Barrel- $ 27.41 $ 29.51 7.7 $ 31.72 Five Month's' Ended May

Cost

$47 600 $31 351 (34.1) $ 20 121 Callons 75 317 46 666 (38.0) 25 915 l Cents /Callon-63.20 67.18 6.3 77.64 $ per Barrel. $_26.54 $ 28.22 6.3 $ 32.61 1 7 v a 1 +' -T-" w'rv-I-----e+w--ee + e 'W-w y 2 *-- w 1r

t \\ ij. r-6/30/80 ~ (Pre'is) S i~ JERSEY CENTRAL POWER & LIGHT COMPANY DOCKET NO. 804-285 4 l i ?: l . Rate Counsel Data' Request: Provide an update of Exhibit ~JC-B.4 from LEAC proceeding (Docket 801-45). Response: See attached. l

1 4-

C (. l .I JERSEY CENTRAL POWER & LIGHT COMPANY Oil Cost Comparison,-Actual vs..B'udget January - May 1980 (000's) As Burned As. Per % Ince., Delivered Budget Actual Actual over Budget (Actual) January Cost $10 562 $11 936 13.0 $ 6 670

c. t Gallons 17 252

~18 430 (0.7) 9 069 Cents / Gallon 61.22 64.76 5.7 73.55 '$ per Barrel $ 25.71 $ 27.20 5.8 $ 30.89 February Cost $10 044 $ 9 069 (9.8) $ 4 184 Gallons-16 153 13 561 (16.1) 5 267 Cents / Gallon 62.18 6.88 7.5 79.44 $ per Barrel $ 26.12 $ 28.09 7.5 $ 33.36 March Cost S 9 883 $ 5 497 (44.4) $ 3 938 Gallons 15 609 7 739 (50.4) 4 906 Cents / Gallon 63.32 71.03 12.2 80.27 $ per Barrel $ 26.59 $ 29.83 12.2 $ 33.71 Aprit Cost $ 7 819 $ 1 190 (84.8) $ 3 037 Gallons 12 062 1 729 (85.7) 3 632 cents / Gallon 64.82 68.83 6.2 83.48 z$ per Barrel $ 27.22 $ 28.91 6.2 $ 35.06 May Cost $ 9 292 $ 3 659 (60.6) $ 2 292 Gallons 14 241 5 207 (63.4) 3 035 Cents / Gallon 65.25 70.27 7.7 75.52 $per;Bayrel $ 27.41 $ 29.51 7.7 $ 31.72 Five Months Ended May . Cost. $47 600 $31 351 (34.1) $ 20 121 Gallons: 75 317 46-666 (38.0) 25 915 Cents / Gallon '63.20 67.18 6.3 77.64 -$ per. Barrel $ 26.54 $ 28.22 6.3 $ 32.61- ~ 1 s a e.

-. r,

i .l 6/30/80-(Preis) ' JERSEY. CENTRAL POWER & LIGHT COMPANY -DOCKET-NO. 804-285 . Rat'e Counsel Data Request: Provide an actual ' s.. budget' comparison of 0 & M costs' for the v first -five m'onths of 1980 'and the budgeted data for the remainder of the year.

Response

Attached are Statements of Operating Income which detail Payroll and Other 0 & M by-function. .i 4 i 1 .l 4 3_ a.

a) v. IRSEY CENTRAL POWER.*. LNili COMPANY STATE E NT OF OPERAllNG INCOME ACIUAL VS BUDCEI. JANUARY - MAY 1980 ($000)- January 1980 February 1980 ' March 1980' Actus1 ' Budget Incr/Decr Actua1 Dudget iner/Decr Actual Budget iner/Decr-Revenues - 8ase 50 587 53 540 '(2 953) 51 447 52 075 (628) 49 752 48 274 ~ 1 478 ~ - Fuel Clause 13 654 14 786 (1 132) 14 366 14 355 11 21 647' 19 782 1 665 Total Revenues-64 241 68 326 (4 085) 65 813 66 430 (617) 71 399 68 056 3 343 . Operating Expenses Fuel 17 883 13 415 4 468 14 075 12 294 1 781 11 360 12 533' (1 173) Purchased Power & Interchange 38 313 43 302 (4 989) 40 164 40 023 141 40 825- -32 670 8 155 Deferred Energy (26 478) (24 904) (1 574) (23 300) (21 697) (1 603) (16 038) (11 442) .(4 596)- Reserve Capacity 211 380 (169) 276 399 (123) 212

419, (207).

' Payroll Production 1 764 1 913 (149) 1 932 1 912 20 2 251 -1 954 297 Iransmission 306 315 (9) 299 315 (16) 376 380 (4) Distribution 1 210 1 25,3 (43) 1 158 1 253 (95) 1 514 1 500 14 Customer Accounting 695 704 (9) 679 705 (26) 814 -865 (51) A&G 630 560 70 649 562 87 671 690 (19) . Total Payroll 4 605 4 745 (140) 4 717 4 747 (30) 5 626 5 389 237-Other 0 & H - Amort. Prope,-ty Losses 97 97 97 97 97 97 Production 4 655 3 598 1 057 4 601 4 196 405 5 095 3 862 1 233 Iransmission 655 843 (188) 660 707 (47) 729 724 5-Distribution 606 683 (77) 478 628 (150) 773 725 '48 Customer Accounting 472 532 (60) 410 536 (126) 472 555-(83) A&G 2 278 2 066 212 2 433 2 056 377 2 098 2 237 (139) Total Other 0 & H 8 763 7 819 944 8 679 8 220 459 9 264 8 200 1 064 Total 0 & H 43 297 44 757 (1 460) 44 611 43 986 625 51 249 47 769 3 480 Depreciation 4 917 4 914 3 4 914 4 914 4 914 4 914 Deconnissioning 130 130 130 130 130 130 Taxes Other Than income Tax 8 054 8 419 (365) 8 105 8 355 (250) 9 020 9 038 (18) Total Operating Expenses 56 398 58 220 (1 822) 57 760 57 385 375 65 313 61 851 3 462 Operating Ircome Bef ore Inc. Tax 7 843 10 106 (2 263) 8 053 9 045 (992) 6 086 6 205 (119) Ircome Iaxes: Federal (10 404) (10 033) (371) (10 058) (9 204) (854) (7 540) (5 339) (2 201) Other (166) (166) (163) (164) 338 338 Deferred Ircome Tax (Net) 13 111 12 278 833 12 399 10 84C 1 559 8 274 5 748 2 526 Investment Tax Credit (1 500) (1 500) (1 493)' (1 493) (1 493) (1 493) Amortaratnon of ITC (l18) (37) (81) (242) (38) (204) (125) (38) (87) Total Iecome Tax 923 708 215 442 105 337 (546) (1 122) 576 Net Utility Operating Ircome 6 920 9 398 _ (2 478) 7 611 _ 8 940 __ _ __ (1 329) 6 632 7 327 (695) .m... m.

_..= g.u. _..,..._..__..._._a__q o o, JERSEY CENTRAL F0WER & LICHT C0FPANY ~' STATEHt_NT Of C?ERAi!NG INCOHC ACTUAL VS BUDGET JANUARY'- MAY 1980 ($000) April 1980 May 1980 5 Honthe Ended May Actual Budget Incr/Dect Actual Budget Incr/Decr Actual Budget' Incr/Decr Revenues - Base 44 562 46 386 (1 824) 42 613 44 688 (2 075) .238 961 ~ 244 963 ~ (6 002)'- - Fuel Clause 22 305 18 716 3 589 20 231 17 037 3 194 92 203 84 676' 7 527 Total Revenues 66 867 65 102 1 765 62 844 61 725 1 119 331 164 329 639 1 525 Operating Expenses

Fuel 6 947 11 279 (4 332) 8 837 13 659 (4 822) 59 102 63 180 (4 078)-

Purchased Power & Interchange 25 250 19 548 5 702 21 593 14 574 7 019 166 145 150 117 16 028' Deferred Energy 3 295 628 2 667 1 882 293 ! 589 (60 639). (57 122) (3 517) Reserve Capacity. 209 323 (114) 275 691 (416) 1 183 2 212 (1 029) Payroll Production 1 836 1 632 204 1 949 1 602 347 9 732 9 013 719. Transasssion 334 315 19 312 315 (3) 1 627 1 640 (13) Distribution 1 282 .I 241 41 1 226 1 278 (52) 6 390 6 525 (135) Customer Accounting 678 - 70,5 (27) 693 705 (12) 3 559 3 684 (125). A&G 593 562 31 600 563 37 3 143 2 937 206 Total Payroll 4 723 4 455 268 4 780 4 463 317 24 451 23 799 652 Other 0 & H - Amort. Property Losses 213 97 116 214 97 117 718 '485 233 Production 4 541 2 805 1 736 3 568 2 403 1 165 22 460 16 864 5 596 Transmission '744 712 -32 713 746 (33) 3 501 3 732 (231) Distribution 612 294 318 694 669 25 3 163 2 999 164 Customer Accounting 385 537 (152) 940 537 403 2 679 2 697 (18) A&G 2 330 2 525 (195) 2 368 2 251 117 11 507 11 135 372 Total Other 0 & M 8 825 6 970 1 855 8 497 6 703 1 794 44 028 37 912 6 116 Total 0 & H 49 249 43 203 6 046 45 864 40 383 5 481 234 270 220 098 14 172 Depreciation 4 915 4 915 4 915 4 956 (41) 24 575 24 613 (38) Decommissioning 130 130 130 130 650 650 Taxes Other Than income Tax 8 989 8 801 188 8 703 8 556 147 42 871 43 169 (298) Total Operating Expenses 63 283 57 049 6 234 59 612 54 025 5 587 302 366 288 530 13 836 . Operating Income Before Inc. Tax 3 584 8 053 (4 469) 3 232 7 700 (4 468) 28 798 41 109 (12 311) Income Taxes: Federal (2 068) 1 357 (3 425) I 131 996 135 (28 939) (22 223) (6 716) Otter 8 8 Deferred income Tax (Net) (726) 141 (867) (30) 425 (455) 33 028 29 432 3 596 Investment 1as Credit 578 (1 493) 2 071 (3 639) .(1 493) (2 146) (7 547) (7 472) (75) Amortizotton of IIC (123) -(38) (85) (124) (38) (66) (732) (189) (543) Total Inco,e Tax (2 339) (33) (2 306) (2 662) (110) (2 552) (4 182) (452) (3 730) Net Utility Operat ang income _5 923 9 086 (2 163) 5 894_ 7 810 (1 916) 32 980 41 561 (8 581)

F 'O. ,ERSEY CENTRAL POWER & LIGHT COMPANY STATEMENT OF OPERATING INCOME PER BUDGET JUNE - DECEMBER 1980 ($000) June July August September October November December R; venues - Base 49 769 56 014 56 495 54 465 50 078 48 336 51 613 - Fuel Clause 17 931 19 688 19 764 25 490 23 231 24 307 27 476 Tttal Revenues 67 700 75 702 76 259 79 955 73 309 72 643 79 089 Operating Expenses- -Fuel: 14 709 16 242 16 348 15 517 15 073 14 274 13 988 Purchased Power & Interchange 17 163 21 644 22 132 15 666 17 034 19 061 26 201 Deferred Energy (1 594) (4 461) (4 732) 7 075 2 854 3 376 1 345 Reserve Cape ity 1 391 1 813 1 978 1 000 464. 517 51'1 'Pryroll ' Production -1 820 1 484 1 509 1 816 1 559 1 594 1 933 Transmission 380 315 315 380 315 335 402 Distribution' 1 493 1 221 1 226 1 490 1 221 1 296 1 576 Customer Accounting 865 705 70 5 865 705 74S 918 A&G 712 583 582 711 583 619 755 T tal Payroll 5 270' 4 308 4 33', 5 262 4 383 4 592 5 584 Other 0 & H - Amort. Property Losses 98 98 - 98 82 82 82 82 Production 2 460 2 285 2 242 2 503 2 499 2 343 2 478 Transmission 742 711 702 724 711 711 717 Distribution 732 648 671 783 727 764 871 Customer Accounting 553 535 540 552 534 529 544 A&G 2 465 2 358 2 277 2 417 2 311 2 207 1 973 Total Other 0 & H 7 050 6 635 6 530 7 061 6 864 6 635 6 665 Total 0 & M 43 989 46 181 46 593 51 581 46 672 48 455 54 294 Depreciation 4 956 4 956 4 956 4 956 4 956 4 956 4 961 . Decommissioning 130 130 131 131 131 131 131 Taxes Other Than Income Tax 8 724 8 910 8 935 9 675 9 310 9 424 9 848 Total Operating Expenses 57 799' 60 177 60 615 66 343 61 069 62 966 69 234 Operating Income Before Inc. Tax 9 901 15 525 15 644 13 612 12 240 9 677 9 855 Income Taxes Federst 1035 ~ 2 423 2 485 7 161 4 608 3 792 3 035 Other-1 Deferred Income Tax (Net) 1 255 2 452 2 569 (3 204) (1 135) (1 432) (666) Investment Tax Credit (1 493) (1 493) (1 493) (1 493) (1 493) (1 493) (1 493) AmJrtization of ITC (38) (37) (37) (39) (38) (38) (38) Total Income Tax 759 3 346 3 524 2 425 1 942 829 838 ._ Net Utility Operating Income 9 142 12 179 12 120 11 187 10 298 8 848 9 017 _}}

ML19330C421

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Dear Mr. Vollmer:

Dear Mr. Carcy:

Dear Mr. Sheppa:

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ML19330C421

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Dear Mr. Vollmer:

Dear Mr. Carcy:

Dear Mr. Sheppa:

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