ML19332A275

Forwards Responses to NRC 790921 & 1109 Requests for Info Re Significant Regulatory Developments Affecting General Public Utils Companies in Restart Proceeding.Federal Executive Agencies & Rate Counsel Data Requests Encl

ML19332A275
Person / Time
Site:	Crane
Issue date:	09/05/1980
From:	Sweeney L JERSEY CENTRAL POWER & LIGHT CO.
To:	Vollmer R Office of Nuclear Reactor Regulation
References
NUDOCS 8009110394
Download: ML19332A275 (25)

Text

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THIS DOCUMENT CONTAINS P00R QUAllTY PAGES Jersey Central Power & Ught Company Madison Avenue at Punch Bowl Road Morristown, New Jersey 07960 (201)455-8200 September 5, 1980 Mr. Richard H. Vollmer Director, Three Mile Island-2 Support Office of Nuclear Reactor Regulation U.S. Nuclear Regulatory Ccemission 7920 Norfolk Avenue Bethesda, MD 2001h Re:

NRC Docket No. 50-289 - TMI-1 Restart Proceeding

Dear Mr. Voll=er:

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

Petersen's data requests sent to C. W. Smyth en November 9,1979, you requested us to keep the NRC informed of significant regulatory develop-ments affecting the GPU ccmpanies. Accordingly, the enclosed material (8 copies) has been sent for that purpose.

Enclosed please find responses to data requests as. fo11cvs:

- First Information Request of the Federal Executive Agencies No. 13

- Second Information Request of the Federal Executive Agencies Nos. 7, 8, 9, 10, 11, 12, 14, 16, 18, 20, 22, 23, 2h, 25, 26, 28 l

- Bate Counsel Data Request Nos. RD 2, 3, h, 5, 6, '

10, 11 l

Very truly yours, f0A.,M c

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Lawrence E. Sweeney re Enclosure ec:

M. Karlovicz (w/ene) j J. Petersen 9

D. Carroll (v/o enc)

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Responsa to Rate Counsel Request R.D. 3 8/22/80 (Carter)

O JERSEY CENTRAL POWER & LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80 Request No. R.D. 3:

Provide the bill frequency data for all classes for 1979, 1978, and 1973.

Response

Summary bill frequency data is readily available as follows:

12 Months Ending March, 1980, Docket 804-285 Exhibit JC-201 -

Schedule 3 12 Months Ending August, 1978, Docket 7610-1021 Phase II Exhibit JC-211 12 Months Ending December, 1975, Docket 7610-1021 Phase II Exhibit JC-204 Detailed data back to January,1975 is available for inspection and copying at the Jersey Central Rate Department, Morristown, Pa.

Data prior to 1975 compatible with current day rate structures is not readily available.

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Rssponsa to First Info.

Request of F.E.A. No. 13 8/22/80 (Carter)

Page 1.of 2 s

JERSEY CENTRAL POWER & LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80 Request No. 13:

a. Provide a worksheet shor:ing fuel expenses allocated to tariffs for the year ending June 30, 1980, similar to that in the attached GSA/D0D 5.1 (Inclosure 2).

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b. Provide a statement of fuel expenses allocated to tariffs (cost of service study) through June 1980.

c. Provide an explanation and quantification of the differences proposed.

Response

We have not allocated any expenses to tariffs for the year ending June 30, 1980.

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(~T Fuel expenses for the year 12/31/80 were used in this rate case N/

and allocated within the Cost of Service Study, Exhibit JC-203 as shown on page 9.

The fuel expenses as allocated to rate classes are attached as page 2 of this response.

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O E*1 JERSEY CENTRAL POWER 8 LIGitT COMPANY ALLOCATED PRODUCTION (FUEL) EXPENSE FOR 12 MOHTils ENDINGt 12/31/80 RATE FUEL NORMALIlED ECR PURCHASED DEFERRED TOTAL TARIFF REV. EQUIVALENT POWER (DE)

ENERGY PROD-FUEL (1)

(2)

(3)

(4)

(5)

(6)

RESIDENTIAL HD Ulf 101219353.

9110566.

4244096.

-8535459. 106038557.

U:lCONT 16531871.

1488003.

657102.

-1394072.

17282903.

TOT ELEC 47336170.

4265141.

1885517.

-3995903.

49540925.

CONT WH

14226445, 1280496.

444171.

-1199664.

14751448.

TOT RES 179363839, 16144207.

7230886. -15125099. 187613833.

GENERAL SERVICE SECONDRY 150849757.

13577707.

5369418. -12720610. 157076272.

PRINARY 48491827.

4364660.

1459154.

-4089139.

50226502.

T R Alls 61435576.

5529702.

1775878.

-5180638.

63560519.

TOT GS 260777160. 23472069.

8604450. -21990387. 270863292.

LIGilTIMG GL 410341.

36934.

5269.

-34603.

417942.

SL 3082211.

277424.

38247.

-259912.

3137971.

101 LIG 3492553.

314358.

43516.

-294514.

3555913.

TOT RET 443633551.

39930634.

15878853. -37410000. 452033038.

RESALE 10722449.

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390673.

~ 0 11113122.

TOTAL CO 454356000.

39930634.

16269526. -37410000. 473146160.

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Rasponse to Sacond Info.

Request of F.E.A. No. 18 8/22/80 (Carter)

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JERSEY CENTRAL POWER & LICHT COMPANY BPU Docket No. 804-285 l

OAL Docket No. 3518-80 i

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Request No. 18:

Please provide for each item in the allocated cost of service study the_ justification for the allocation factor utilized.

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Response

t See attached " Descriptive Analysis of Cost of Service Study."

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DESCRIPTIVE ANALYSIS OF C052 0F SERVICE STUDY I.

GENERAL A.

Overview In a fully allocated cost of service or rate of return study, many informed technical and engineering type judgements must be made as to methods of allocation. The judgements used in this cost audy are considered to be the most reasonable and supportable thinking currently possible. The primary purpose of this fully allocated rate of return study is not to show the absolute return a rate class vould achieve if served as though it were a separate company, but rather to indicate the relative earnings position of the different rate classes within the company.

B.

Functionalization of Accounts Ihe beginning point of the cost of service study is to identify i

the rate base and ext.ense components as they relate to the Company 4

functions of:

(1) production, (2) transmission, (3) distribution, (4) customer accounting, and (5) general. This structuring assures, for instance, that distribution plant investment will not be charged to the rate base of transmission custo=ers not utilizing such facilities.

The functionalization of the accounts into these functions is made for the "per books" data plus each individual nor=alization adjust-ment, and is not subj ect to allocation judgement.

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Classification of Accounts The second step of the study is to determine which Company variable (i.e. demand, customers, or energy) most closely correlates with each rate base and expense item. Thus, each item may be allocated to the rate classes on the proportion of the variable which best relates to that item. An example of this would be the bulk power system. It is sized to meet system demands; therefore, it is classified as coin-cident demand related. This means all customers who use the bulk power facilities are allocated a portion of that cost in relation to their 60-minute coincident demand responsibilities.

D.

Basic Dependency Methodology It is most reasonable to assume that all production and transmis-O sion plant-in-service does not vary directly with customers, but does have a correlation with demand and energy requirements of the customers, and is therefore considered ' to be demand and/or energy dependent.

However, distribution plant contains items which are both demand and customer dependent, but does not correlate with energy. General plant, present to support the production, transmission and distribution plant, is apportioned on the ratios that exist for the composite of the production, and/or transmission and distribution plant. Intan-gible plant, assumed to be related to all other plant is therefore apportioned on the dependency ratios that exist for the compocite of all production, transmission, distribution and general plant.

All production and transmission operating expenses, excluding fuel and purchased power are considered to vary with the production V

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l 3-I and transmission plant, and are therfore given the same demand de-pendency. Fuel and purchased power, however, which most closely correlate with energy requirements are considered energy dependent.

Production and transmission maintenance expenses are considered variable on a short term basis and, therefore, energy would appear to be the most reasonable allocation method, in that a save re reduction of energy without changes in demand or customers would most likely cause some reduction or postponement of those variable expenses. Distribution operating and maintenance expenses contain items which depend individually on demand and customers, and are therefore allocated as the corres-ponding plant. Customer Accounting and Sales Expenses are considered to be dependent upon customers. Administrative and general expenses are considered to be dependent upon demand, customers and energy in the same proportions as the composite of all other operating expenses, excluding fuel and purchased power.

j II. iLLOCATION OF RATE BASE ITEMS TO RATE CLASSES A.

Plant In Service 1.

Production and Bulk Power Traasmission Plant:

All production plant-in-service items are considered to most nearly correlate with the coincident demand and energy of the System, and therefore, such investment items are allocated to each rate class on the basis of each class contribution to the System demand or energy requirements at the generation level.

The system demand could be an annual or seasonal peak, or, to t

l prevent undue bias towards any seasonal class, on a combination l

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2.

Sub-Transmission Plant:

Sub-transmission plant-in-service items are not considered to vary with the coincident demand of the System. In actuality, it varies with the local coincident demand for each specific geographic area of transmission plant. Geographically sectionalized demands, however, are not available, and thus the most reasonable alternative is through the use of proportions established through the sum of the rate class maximum demands at the generation level.

3.

Distribution Plant:

By analyzing the various items of distribution plant, it can be reasonably determined that certain. investments are uniquely customer related, such as services, meters, installations on customer premises, and street lighting and traffic control signals; in that they correlate much more with customers than with demand or energy.

Items such as station equipment and storage battery equipment,, aowever, relate entirely to demand rather than customers or energy. The remaining items, which do not appear related to energy, do have some correlation to both demand and customers, and l

therefore, without more deiinitive analysis, is considered to be equally dependent upon the two.

These dist ibution plant items are not directly allocated from the dependency modes to the rate classes, however, because the distribution plant consists of both primary and secondary investment items. This plant is therefore

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separated, utili:ing engineering studies, so that the investment O

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. O related only to secondary service is not included in the race base for primary service. Land and land rights, structures and improvements, station equipment, storage battery equipment and leased property are felt to serve both primary and secondary customers, and are therefore allocated on the primary level, while installations on customer premises and street lighting and signals are entirely for use by the street lighting rate clascas.

The remaining distribution plant items have been analyzed in a pole study which resulted in the following breakdowns: poles, towers and fixtures, 62.0% primary, 38.0% secondary; overhead conductors, 67.4% primary and 32.6% secondary; underground conduit, 40.4% primary and 59 6% secondary; underground conductors, 53.9%

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primary and 46.1% secondary; and line transformers, 2.49% primary and 97.51% secondary. Thus, while each distribution item may be demand or customer dependent, each also has a portion which relates to either the total distribution level (both primary and secondary), or only to the secondary level. Each of these portions l

are then allocated to the rate classes on proportions which either include all distribution rate classes, or those which only include secondary rate classes. An item then, such as overhead conductors,

-t a is dependent on demand and customers, and found to have 32.56% of its total related to secondary service, has 55.9% of the portion allocated to the rate classes on the basis of the proportions of the secondary rate classes sum of class demands, and the remaining 44.1% of the portion allocated to the rate classes on the proportion

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.. i remaining 67.44% of the demand and customer components of this item are then allocated on distribution proportions (which include both secondary and primary rate class data).

4.

General Plant:

General plant is applicable to all customers, and there-fore, allocated to the rate classes on the rate class proportions derived from their share of production, transmission and distri-bution plant.

5.

Intangible Plant:

Intangible plant is handled in the same manner as the general plant.

B.

Other Rate Base Items 1.

Accumulated Depreciation:

Accumulated da.preciation consists of production, transmission, distribution and general components, with each split between demand and customer dependencies on the same proportions as the respective plant-in-service groups. The transmission plant, thus considered to be entirely demand dependent, makes the transmission accumulated depreciation also entirely demand dependent.

2.

Plant Held For Future Use:

Plant held for future use is handled in the same manner as accumulated depreciation.

3.

Construction Work in Progress:

Construction work in progress is handled in the same manner as accumulated depreciation.

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Customer Advances:

this account is related to distribution customers and allocated as distribution plant.

.5.

Nuclear Fuel and Provision for Amortization of Nuclear Fuel:

These accounts are considered to be 100% energy dependent and are allocated on the energy requirement proportions of each rate class at the generation level.

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6.

Working Cash on Operation and Haintenance Expenses:

The working cash, which represents a percentage of the operation and maintenance expenses in each rate class, is allocated to the rate classes on the proportions of total oper-ation and maintenance expenses for each rate class.

7.

Fuel Stock Inventory:

fuel stock inventory is considered 100% energy dependent, with such portions allocated to the rate classes on the same proportions used for nuclear fuel.

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Materials and Supply Inventory:

l This item is related to the total transmission and distribution l

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plant, and is therefore split to demand and customer dependencies in the same ratio as the sum of that plant. These dependencies are i

then allocated to the rate classes in the same manner as transmission and distribution plant components.

9.

Compensating Bank Balances:

This item is related to total plant-in-service and is therefore split between demand and customer dependencies in the same ratio as the total plant-in-service.

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Unamortized Investment Tax Credits:

This item is related to the original plant-in-service, and is therefore split between demand and customer dependencies in the same ratio as the original plant-in-service.

11.

Accumulated Deferred Income Taxes:

This item, as well as its adj ustment, is' split between demand and customer dependencies in the same ratio as original plant-in-service, with such components allocated to the rate classes on the same proportions used for the original plant components.

12.

Other Deferred Credits:

This item, as well as its adjustment, is plant dependent and therefore spread to the rate classes on the proportions of original

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plant items.

III. ALLOCATION OF EXPENSES TO RATE CLASSES A.

Operating Expenses 1.

Production Operation Expenses:

All production operation expenses, except fuel and pur-chased power, are plant dependent, and are therefore allocated to the rate classes on a production plant basis.

Fuel and most l

of the purchased power however, being energy dependent, are allocated to the race classes on the proportions of rate class energy requirements at the generation level. The portion of purchased power considered demand related is allocated as coin-cident demand.

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2.

Transmission Operation Expense:

All transmission operation expenses are considered to be demand dependent, similar to transmission plant-in-service, and are allocated to the rate classes on the same proportions used for transmission plant-in-service.

3.

Distribution Operation Expense:

The investigation of the distribution operation expense items shows over-head lines, and underground lines essentially are plant dependent. Load dispatching and station expense appear to be entirely demand related while street lighting, meters, and installations on customers premises appear to be entirely cusotmer dependent. Rents are considered to be customer dependent.

Miscellaneous, supervision, and engineering are related to the total of the other distribution operation expense.

Each of these distribution expenses, similar to the dis-tribution plant-in-service items, are also further proportioned

,i as being necessary for secondary service, or for the combined i

primary and secondary service. Load dispatching, station expense, miscellaneous distribution expense, and rents, are considered to i

relate to both primary and secondary customers while street lighting expense is directly assigned to the street lighting rate class. The remaining items, either through separate analysis or relationship to the plant accounts are split to primary and secondary.

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Customer Accounting and Sales:

All customer accounting and sales expense accounts are l

considered to be entirely customer dependent and therefore allocated to the rate classes on the weighted customer propor-tions derived for customer accounting and sales..

5.

Administrative and General Expenses:

These. items are considered to follow the dependency ratios exhibited by the total production, transmission, distribution, and customer accounting expense items, excluding fuel and pur-chased power. The resulting demand, customer and energy compon-ents are then allocated to all rate classes on the demand propor-tions at the generation.evel, customer proportions of all rate i

j classes, and energy requirements proportions that exist at the generation level for all rate classes.

B.

Maintenance Expenses All production and transmission maintenance expenses, as prev-iously discussed, are allocated to the rate classes on energy require-ments proportions. Distribution maintenance expenses go to primary and secondary customers with th.e same type of analysis used for distribution operation expense.

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C.

Excenses Other Than Operation and Maintenance Expenses 1.

Depreciation Ocpense:

Depreciation expense has the same dependency ratios as the total plant-in-service. These dependency components se then allocated to the rate classes on the same proportions as used for the related plant.

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Investment Tax Credit:

This. item is considered to have the same dependency ratio as the total original plant with such components also allocated to the rate classes on the same proportions used for the original plant.

3.

Deferred Income Tax:

This item is separated into two portions, one is considered to have the same dependency ratio as the original plant, and the second is related to deferred energy and allocated as retail energy.

4.

Other Taxes - Revenue Related:

This item, and its adjustment, are considered to be entirely revenue related, and allocated to the rate classes on the tariff i

revenue portions.

5.

Other Taxes - Payroll Related:

Payroll and O&M expenses excluding fuel and purchased power, exhibit essentially the same dependency ratios, and this item is thus allocated to the rate classes on the same dependency ratio as O&M expenses, excluding fuel and purchased power.

6.

Other Taxes - Plant Related:

This item is considered to have the same dependency ratio as original plant with such components then allocated to the t ate classes on the same proportions used for the original plant.

7.

Federal and State Income Taxes:

These items, and their adj ustments are allocated to the rate classes on operating revenue proportions less income de-ductions.

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IV.

Allocation of Revenue Related Items To Rate Classes A.

Other Operating Revenues 1.

.The Service Application, Uncollectable Check and Meter Tampering Fees were considered custome related and allocated as the

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appropriate number of customers.

2.

'Ihe miscellaneous revenue is considered related to all rates and allocated to the rate classes on the proportions of rate base that exist for tariff revenues.

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Response to Sscond Info.

Request of F.E.A. No. 20 8/22/90 1

(Carter)

JERSEY CENTRAL POWER & LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No.'3518-80 Reques,t No. 20:

~Please provide the Work papers and justification for the percentage figures under Column 4 of Exhibit JC-203. page 7.

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Response

i See response to No. 10.

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Racponta to Sacond Info.

Request of F.E.A. No. 22 8/22/80 (Carter)

O JERSEY CENTRAL POWER & LIGHT COMPANY i

BPU Docket No. 804-285 OAL Docket No. 3518-80 Request No. 22:

Please provide a discussion of the Company's methodology j

for choosing the rate of return for each customer classification.

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Response

i The. Company does not choose a rate of return for each customer classification. However, cost-of-service and the resultant-return levels from each class of service at the proposed level of rates are one of the important guidelines upon which the soundness O

of the proposed rate design is evaluated. The resulting rates of return are deemed prudent and reasonable in light of having con--

sidered all factors.

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Response to'Sacond Info.

Request of F.E.A. No. 23 8/22/80.

(Carter)

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JERSEY CENTRAL POWER & LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80 4

Reqpest No. 23:

Referring to Exhibit JC-201, Schedule 3, please provide

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explanations and any work papers indicating how the unit prices indicated in Column 5 of each sheet of Schedule 3 were determined.

Response

Please refer to Exhibit JC-203, pages 11-13 which contain levelized unit costs for demand, customer and energy. This data is the starting point insofar as providing. ranges of reasonableness for

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developing a sound rate desiga, as proposed by JCP&L in this filing.

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Rasponse to Second Info.

Request of F.E.A. No. 24 8/22/80 (Carter)

JERSEY CENTRAL POWER & LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80 Request.No. 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 form the late payment charge.

Response

This concept was proposed in a prior JCP&L rate case and was supported by the Advocates expert witness.

It was not implemented due to the settlement nature of the case.

Our concern heightened as the prime interest rate began to increase rapidly in 1980 to unprecedented levels (ref. P. H. Preis data response RCR-12 shows that RCA funds cost 21.5% at the end of April 1980 - the time of the filing).

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The Company became increasingly concerned about the possibility of general service customers (the more. sophisticated customer) taking advantage of this source of interest free working capital without an associated late payment charge. Also, the NJBPU approved a late pay-ment charge applicable to general service accounts for Public Service Electric and Gas Co. at Docket 794-310, rates effective April 17, 1980.

I Recognizing Jersey Central's extraordinary financial condition due to the TM1 accident it was decided to request a late payment charge and make it applicable to general service accounts only.

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Responsa to Sacond Info.

Request of F.E.A. No. 25 8/22/80 (Carter)-

JERSEY CENTRAL POWER & LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80 Request No.'25:

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

Response

Reflects Jersey Central's cost of short-term credit at the time of the filing which was in excess of 21.5% on an annual basis (see response -

to Second Info. Request of F.E.A. No. 24).

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4 Response to Second Info.

Request of F.E.A. No. 26 8/22/80 (Carter)

JERSEY CENTRAL POWER & LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80 Request No. 26:

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

Response

Refer to response to Second Info. Request of F.E.A. No. 24.

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Request of F.E.A. No. 27

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JERSEY CENTRAL POWER & LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80

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Request No. 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.

Response

Data on a rate class basis regarding the number and amount of late payments is not readily available.

Investigation reveals that approximately 10,000 " reminder" notices are sent each month to customers in the residential class on the due date of the second of two consecutive months bills which are unpaid.

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Also, approximately 40,000 " delinquent" notices are mailed each month. These notices are mailed to-any residential customer who is three months in arrears and to general service accounts that are two months in arrears.

The above data suggests that approximately 3/4 of all delinquent bills are in the general service category.

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Implementation of a late payment charge should drastically reduce the number of delinquent accounts. After the fact experience will allow us to determine the magnitude of the reduction.

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Razponse to Second Info.

Request of F.E.A. No. 28 8/22/80 (Carter) q JERSEY CENTRAL POWER & LIGHT COMPANY

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BPU Docket No. 804-285

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OAL Docket No. 3518-80 Request No. 28:

Referring to page 12 of Mr. Eugene Carter's testimony, Mr. Carter states "the proposed rates and rate structures reflect tbs blending of several factors and different weights given to each?

cost-of-service, value-of-service, and essential human needs." With.

regard to that statement, please provide the following:

a.

The definition of "value-of-service".

b.

The definition of " essential human needs".

c.

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

d.

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

Please indicate how " essential human needs" are quantified.

e.

f.

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

g.

Please provide an explanation indicating how tha waight

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to be given to each factor was determined.

I Respense:

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A non-cost standard related to the intangible benefit of a.

having (or not having) any goods or service.

b.

The minimal amount of electricity and its costs related I

to supporting a "below standard" standard of living or operation of a necessary commercial / industrial operation.

c.

Please refer to Exhibit 3C-203.

d.

"Value" is not quantifiable since service to different classes of customers at the same time or to the same customer at different times is of different importance.

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why one must give weight to this element.

f.

There were no quantifiable different weights given to each factor.

g.

The weighting process involved a subjective and informed balancing of inputs to sound rate design involving cost-of-service, continuity of ratemaking, ease of

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understanding, essential human needs and value of l

service criteria.

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Responsa to Sacond Info.

Rtquest of F.E.A. No. 7 8/14/80 (Carter) 1

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JERSEY CENTRAL POWER & LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80 Request No. 7:

Please provide a complete allocated cost of service study. The allocated cost of service. study should contain a detailed itemization of the components of the cost of service, including, but not limited to:

operation and maintenance expenses, depreciation expenses, taxes other than income taxes, other operating expenses, income taxes, plant in service,

- working capital, construction work in progress, other rate base items and return on rate base. The allocated cost of service study should also con-tain the amount of each of the components.of the cost of service allocated to each rate class, the basis for'such allocation (i.e., the allocation l

factor) and all work papers and supporting documentation therefor.

Response

The above information is contained in the filed Cost of Service Study, Exhibit JC-203 (Carter).

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Responsa to' Sacond Info.

Request of F.E.A..No. 9 8/14/80 (Carter)

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JERSEY CENTRAL POWER 6 LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80 Request No. 9:

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

~

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

Response

Line JC-101 JC-203 No.

Schedule 5, P.1

$(000)

(1)

(2) 1.

Electrical Plant In Service

$1,543,588

$1,543,588 (P.7, L.32) 2.

Plant Held for Fut. Use

-5,876 5,876 (P.8, L.45) 3.

Nuclear Fuel 77,491 4.

Acc. Prov. Nuc. Fuel

(.42,330) 5.

Fuel Rel. Work Cap.

14,214 j}

6.

Total 49,375 49,375 (P.8, L.53) 7.

CWIP 278,190 278,190 (P.8, L.51) 8.

Total Additions 6,386 6,386 (P. 8, L. 59) 9.

Acc. Prov. for Dep.

(409,659)

(409,659) (P.8, L.38) 10.

Cust. Adv.

(994)

(994) (P. 8, L.52) 11.

Unam. Gain (6,633) 12.

Unam. Fed. Tax (638) 13.

Total (7271,1 (7,271) (P.8, L.62) z 14.

Cust. Dep.

(5,688)

(5,688) (P.8, L.61) 15.-

PA Gross Rec. Tax (7,265)

(7,265) (P.8, L.60) 16.

Working Capital l

17.

Fuel Rel.

14,214*

18.

Mat. & Supp.

12,286; 12,286 (P.8, L.54) 19.

Def. Energy 87,101

'87,101 (P.8, L.55) 20.

Working Cash 19,698 19,698 (P.8, L.63)

Total 133.299

• In Line 5 above.

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Response to Second Info.

Recuest of F.E.A. No. 10 Page 1 of 2 8/14/80 '(Carter)

JERSEY CENTRAL POWER & LIGh'T COMPANY-BPU Docket'No. 304-285 OAL Docket No.' 3518-80 Requese No.'10:

I Please reconcile the information on Exhibit JC-101. Schedule 1, page 1, with that on Exhibit JC-203, pages 9 and 10.

Response

Please see attached schedule. -

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Response to-Second Info.

Raquest of F.E.A. No.'11 8/14/80 (Carter)

JERSEY CENTRAL POWER & LIGHT. COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80 Request No. 11:

'Please reconcile the revenues on Exhibit JC-101, Schedule 1, page 1, with those on Exhibit JC-203, page 5.

- Response:

JC-101, Sch. 1 Base Revenues (Includes Misc.)

$ 724,310 j

Base Revenues (Forked River) 51,382 Fuel Clause Revenue 242,563 Total

$1,018.255 JC-203, Page 5 $(000)

Base Revenues S 771,099 (col. 2)

()

Rider CUR Firm Rev.

(347)

(note 1)

Energy Revenue 282,494 (col. 4)

Norm. ECA Rev.(1)

(39,931)

(P.9, L.2)

Misc. Revenue 4,939 (col. 10)

$jg 18 25i 0

Total 3

6-(1)An equal amount of $39,931 is added to ECA revenues and expenses to show effect of normalized sales.

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Response to Secone Info.

R Request of F.E.A. No. 12 8/14/80 (Carter)

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V JERSEY CENTRAL POWER & LIGHT COMPAhT BPU Docket No. 804-285 OAL Docket No. 3518-80 Request No. 12:

6 Please provide a detailed breakdown of the income deductions j

for income taxes on Exhibit JC-203, page 6.

.i I

Response

i A detailed breakdown does not exist for the income deductions j

used in the Cost of Service Study. They are calculated as follows:

Return less Income Tax times Effective Tax Ratio or:

1.

Return =

$170,206,071 1-4635 2.

Income Tax ($66,988,001) x 77,538,429

=

3.

Calculated Income Deductions =

$ 92,667,642 t

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Response to Sscond Info.

Rsquest of F.E.A. No. 14 8/14/80 (Carter)

JERSE1 CENTRAL POWER & LIGHT COMPANY BPU Docket No. 804-285 I

OAL Docket No. 3518-80 Request No. 14:

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

Response

Based on a 1975 study, the following percentages were used to classify the 1980 transmission plant:

Production Related Generation Step-Up Equip.

5.7151 Bulk Power 4

230/115 kV 43.2351 O.

Sub-Transmission 69/34.5 kV 45.5878 Distribution Related Under 34.5 kV 5.4620 J -

Total 100.0000 f

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Rasponca to Second Info.

Request of F.E.A. No. 15 8/14/80-(Carter)

/N JERSEY CENTRAL POWER & LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80 Reque," '~ 25:

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

Response

The following percentages were obtained from a 1975 study used to classify distribution plant:

Actual Bulk Power Sub-Trans.

1979 Total 230/115 kV 69/34.5 kV (1)

(2)

(3)

Acet. 360

$ 9,362,408 1.1692%

1.8569%

2,734,121 4.6966 5.5337 Acet. 361 s,)

Acet. 362 86,401,525 4.7756 5.1739 Acet. 368 120,581,457 6.6000 The above percentages were multiplied times the actual dollars in the 1979 accounts and the resulting weighted average percent applied to the 1980 total distribution plant of $627,035,000.

1979 resulting weighted averages as related to total distribution plant:

Bulk Power - 0.7262%

Sub. Trans. - 2.1223%

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Rssponse to Second Info.

Request of F.E.A. No. 16 8/14/80 (Carter)

JERSEY CENTRAL POWER & LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80 Request No. 16:

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

Response. '

An analysis of the following actual 1279 General Plant Accounts were used to split the 1980 data:

Line Transmission and-Prod. Trans.

No.

Account No.

Distribution Related & Dist. Relar.ed-Total (1)

(2)

(3)

(4) 1.

389 - Land & Land Rights

$ 1,966,542 S 1,966,542 r-2:

390 - Struct. & Imp.

22,962,710 22,962,710

(-)g 3.

391 - Office Equip.

3,859,744 3,859.744 4.

392 - Trans.-Equip.

3,145,947 3,145,947 5.

393 - Stores Equip.

$ 937,915 937,915 6.

394 - Tools, Shop 3,945,015 3,945,015 7.

395 - Lab. Equip.

1,072,796 1,072,796 8.

396 - Power Equip.

648,012 648,012 2,475,055 9.

397 - Comm. Equip.

2,475,055 224,711 224,711 10, 398 - Misc.

Total S34,409.998

$6.828,449

$41.238.447 Percent 83.4415%

16.5585%

100.0000%

i 1

Rssponse to Rate Counsel Request RD 2 8/21/80 (Carter)

Atj J

JERSEY CENTRAL POWER & LIGHT COMPANY Docket No. 804-285 i

Request RD 2: - " Provide a copy of all load research studies done for all clacsea for the past five years."

Response

One hardcopy of a voluminous report of the entire 1975-76 load research study of all rate classes is available for inspection (upon request) at the GPU Service Corporation building in Reading, Pa, A copy of the limited ongoing load research data is also available for inspection at the same location.

O This includes most primary and transmission voltage customers.

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i Response to Rate Counsel Requsst RD 4 8/21/80-(Carter)

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JERSEY CEhTRAL P0k'ER & LIGHT COMPAhi Docket No. 804-285 Request RD 4: "Please provide a complete presentation of test year rate base and operating expenses broken down by FERC accounts."

Response

Th test year rate base and operating expenses are allocated to each FERC account as listed on Exhibit JC-203 pages 7, 8, 9, and 10.

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Reaponse to Rate Counsel Rsquast No. 5 8/21/80 (Carter)

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' JERSEY CENTRAL POWER & LIGHT COMPANY Docket No.- 804-285 Request RD 5:

"In regard to rate base items referred to above, please provide a further break-down showing plant-in-service and CWIP and, in addition, the dollar amounts assigned to each functional level of the electrical system."

Response

A-detailed break-down of plant-in-service and CWIP assigned to each functional level is shown on Exhibit JC-203, pages 7 and 8.

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Responsa to Rate Counsel Request RD 7 8/21/80 (Carter)

Page 1 of 18 JERSEY CENTRAL POWER & LIGHT COMPAhT Docket No. 804-285 Request RD 7: "Please provide ' load curves for the system and for each customer class for the system peak day in each of the twelve consecutive months covered by the cost of service study."

Response

The system load curves for each month in 1979 are attached as pages 2-13.

The synthesized load curves for January, February,

()

July, and August, 1979 for the following rate classes are attached as pages 14-18:

RS No Water Heating RS All Electric GS Secondary GS Primary GS Transmission i

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Pags 2 of 2 Line JC-101 JC-203 O

No.

Schedule 1

$(000)

(1)

(2) 1.

Fuel

$165,340 2.

Purchased Power 289,016 3.

Total

$454,356

$454,356 (P.9, L.1) 4.

Deferred Energy (37,410)

(37,410) (P.9, L.4) 5.

Res. Cap.

15,986 16,269(1) (P.9, L.3)

Pavroll & Other O&M 6.

Payroll

$ 61,220 7.

Other O&M 87,307 8.

Total

$148,527 O&M Expense 9.

'rtod. Oper.

$ 30,124 (P.9, L.5) 10.

Prod. Maint.

23,053 (P.9, L.6) 11.

Trans. O&M 13,075 (P.9, L.10) 12.

Dist. Oper.

14,038 (P.9, L.22) 13.

Dist. Maint.

14,274 (P.9, L.33) 14.

Cust. Acet.

16,217 (P.10, L.34)

15. A&G 35,234 (P.10, L.39) 16.

Amor. of Prop.

2,512 (P.10, L.50) 17.

Total S148,527

()

18.

Depreciation

$ 53,412 19.

Decom.

1,275 20.

Total

$ 54,687

$ 54,687 (P.10, L.45)

Other Taxes 21.

Payroll Taxes 3,241 (P.10, L.46) i 22.

Plant Rel. Taxes 3,051 (P.10, L.47) 1 23.

Revenue Rel. Taxes 138,348 (P.6, L.15, Col.4) 24.

Norm. Rev. Tax (63) (P.9, Bottom) 25.

Total ($138,622 + $5,955)

.S144.577

_S144,577 l-26.

Income Taxes

$ 45,307 20,758 jj 622 l'.

301 27.

Total S 66,988

$ 66,988 (P.6, L.15, Col. 9)

]

28.

Deferred Income Taxes 1,145 (P.10, L.48) 1 29.

Energy Rel. Def. Taxes

. 17.362 (P.10, L.52) 30.

Total

$ 18,507

$ 18,507 4

31.

Inv. Tax credit

$(17,923) 32.

Amor. I.T.C.

(247) 33.

Total S(18.170)

$(18,170) (P.10, L.49)

(1) Includes $284(000) addition to consider Rider CUR as firm.

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e, Rasp:nza to Rcta Counnol Request RD 6 8/27/80 (Carter)

Page 1 of 2 JERSEY CENTRAL POWER & LIGHT COMPANY Docket No. 804-285 s

Request RD 6: "Please provide your most recent Cost of Service

~

Study and any underlying load research. Work papers supporting the Cost of Service Study should be provided as well."

Response

The most recent Cost of Service' is Exhibit JC-203 submitted in this case.

The underlying load research for each rate class was done in 1975 and 1976. This load data, supplemented with actual 1979 primary, transmission and resale load data, was used to construct the January, February, July, and August 1979 peak day demands by rate class.

The 1979 four month average demands were then ratioed to a normalized 1980 test year based on the ratio of normalized 1980 sales to actual 1979 sales. Those work papers showing the 1980/1979 growth factor ratio used is attached as page 2 of 2.

O

i t

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Rtcp:nza to Rate Countsl.

Request RD 10 8/27/80 (Carter)

JERSEY CENTRAL POWER & LIGHT COMPANY Docket No. 304-285 Request RD 10:

"With respect to demand losses:

Provide a statement and supporting studies which will explain how these are attributed to various voltage levels (e.g. Secondary, Primary, 138 kv, etc.) and/or to customer classes.

This response should state the magnitude of the losses assigned to each category and should laclude a system line diagram or flow chart as appropriate.

If demand losses are developed for the single annual peak, what figures are used for the monthly peaks in those months other than the annual peak month? Please explain the derivation of these non-peak figures."

Response

The loss factors used in Exhibit JC-203 were based on an engineering study performed ' for the calendar year 1978.

The primary and transmission loss factors developed in that detailed study were deemed reasonable for use in a 1979 demand study with'a minor modification to include a seasonal difference. The secondary loss factors were increased slightly to recreate the 1979 monthly system demands.

l The engineering study examines the transmission line losses and those losses associated with various trans-formers within the system. An Appendix is attached which shows an example of the various type of studies necessary to determine both demand and energy loss factors.

The magnitude of the losses and a flow diagram are in-cluded as Attachment A, pages 1-4.

The cumulative loss factors are listed in the Response-to the FEA Second Information Request No. 8 (4).

l l

G' f

o e

.4 APPENDIX C0NTENTS i

J 1

Bulk System Transformer Loss Analysis Speakez Program "Lces" Utilized to 2

Compute, Extract and Tabulate Primary Circuit Losses Using Existing Stored SCA Cases 3

Computation of Transformer Losses for Company-Owned " Customer Substations" 4 - - - - -

Tabulation of Transmission Sales (De-mand) at Time of System Peak 5

Summary of Energy.Cales by Voltage Class 6

Computation of Transformer Losses for o

Distribution Substations 7

Computation of 'Line Transformer. Losses Summary of Loss Values "For Rate De-

~

8 partment"-

er i

l-i I

. -. ~.,..-~

Stitibb&.:. :._.

J' APPENDIX #1 4

'IRANSFORMER, TRANSMISSION AND SUDTRANSMISSION kW LOSSES (7.978 SUMMER SYSTEM AND LOAD LEVEL)

LOSSES'(kW)

NORTHERN AREA l

A.

Transformers -

Iron 3,117 Copper- - - - - - - - 5,085 Total 8,202 B.

Transmission - - - - - -

~- 46,570 C..Subtransmission - - - - - - 33,560 TOTAL (NORTH)- - - - - - - - 88,332 SOUTHERN AREA A.

Transformers -

Iron 4,175 Copper- - - - - - --- 4,454 Total 8,629 B.

Transmission - - - - - - - - 5,930 C.

Subtransmission - - - - - - 26,920 TOTAL (SOUTH)- - - - - - - - 41,479 SYSTE!! TOTALS A.

Transformers -

t Iroc 7,292 Copper- - - - - - - - 9,539 Total - - - - - - - - - - - 16,831 B.

Transmission - - - - - - - - 52,500 C.

Sub' transmission.- - - - - - 60,480 CRAND TOTAL - - - - - - - -129,811 n..--

a

..'.:. :.ry:. -.

APPE!.' DIX #2 LOSS IS A PROGRAM P R OG R AM

. M

• AR R AY ( 1, 4 )

L D= AR R AY ( 1, 3 )

L I R=L l H IND Ex ( P EP TL I9 )

CCC= LI d( LU CS( L IB.GE. ' R '. ANU. L IR.L T. ' A 4 ') )

GET 'SCA3 GET SCA4 GET SCAS G ET SCA6 WIRE =KEPT(SCAIL)

FOR ! = 1, NO EL S ( CC C )

T = KLP T I OBJ ECT( CCC( !) ) )

P M=M000L C( T( 2,2),10000 )

I F( PM.GE. 3000. AN C.P 9.L T. 40 00 )KV=4.15 6 I F( PM.GE.4030. Af4 0.P M.L T. 500J )KV =4. 8

[ F ( P'i.GE. 7 000. A'i d.P M.L T. 80 C9 )KV= 12. 4 7 I F ( PM.GE. 913 0 )K V = 34. 5 EXECUTE (SCA3)

LO(I,1)=KV LO( 1, ') = SUNCOLS ( T ( !?! TE GER S ( 3,NORO WS( T I ),4 3 )

L D 8 '. 3 ) = S.J MCUL S ( T (, L 1 ) )

E NDL OOP 1 FOR ! = 1, 4 IF(I.EO.1)KV=4.156 IF(f.EO.2)KV=4.0 IF( 1.EQ.3 ) KV= L 2.47 IF( I. FC. 4 )K V = 3.4. 5 Y = LD( LOC S ( L u(,1 ).EQ.KV ) )

NUM=NGROWS(Y)

M(I,1)=KV M ( 1,2 )= SU'4 CPL S ( Y (,2 ) ) /NUM M( !,3 )= SUS COL S( Y ( 3 ) )/NUM M ( I,4 ) = SUM cCL S ( Y (, 3 ) )/ 5 0'dCOL S ( Y (,2 ) )

l M(!,5)=NUM l

E NDL OOP !

l S P AC 5.12 )

l VOLTAGE =Mt.1) l AVGL O AD=M (,2 )

l AVGLOSS ="(,3 )

LL RA T IO=MI,4 )

NOCE T S = M (, 5 )

l T ABUL AT E( VOL T AGE NOCKTS, AVGLOAD, A VGLlSS.L LRATI C)

SPACE (2)

CKTt;G=CCC l

KQ*LO(,2)

KW L S S = L O(, i l J

T ABUL AT E( CK Trio,K w,XWLO SS )

S P AC h( 2 )

'END l

'~$kb:%,'L:iv.4:

APPENDIX #3 A

SUMMARY

OF CUSTOMER SUBSTATION LOSSES Copper Tdtal Transformer Average Losses:

Nameplate -

Size Number

-Peak Load Demand VVA -

1.0 MVA 3

O.69 FM

.010 MW 3

1.5 8

0.49

.009 12' 2.0 2

1.00

.007 4

3.0 3

2.03

.028 9

3.75 2

1.99

.014 7.5 5.0 25 2.78

.269 130 7.5 7

5.48

.188 52.5 15 2

7.22

.047 30 12/20 2

10.25

.117 24 TOTAL............

0.689 FM 272 MVA Total Substation Demand at time of station peak 163.7 MW-

=

Total Substation Demand at time of system peak 127.9 MW

=

Adjusted Copper loss, demand at system peak = 0.689 MW, x (127 9)' = 0.42 FM (163.7)2 i

Iron Loss:

I (272 MVA) (0.13% 1o' ss) 0.35 FM x 8760 3100 MWh

=

=

(100)

Copper Loss (energy): 0.689 MW x 8760 x 0.35 2113 Muh

=

I

i i

t APPENDIX #4 Page 1 of 2 1978 TRANSMISSION SALES (MW) i.

(COINCIDENT -

[

CUST. NO.

8/17/78-1700 firs.-)

j 1

7.72 t

2 6.05 l

3 1,31 4

1.14 f

5 3.90 6

0,93 7

0.18 8

0.47 9

16.84 10 0.90 11 0.02 12 13 2.54 14 2.10 Central Division Subtotal- - - - - - - - - - - 44.60 15 2.00 16 1.05 17

.80 18 8.96 19

.03 20 21 2.52 22 15.60 23 24 4.05 25 3,09 l

26 1.26 27 2.06 28 1,09 Western Division Subtotal- - - - - - - - - - - 42.51 29 2.92 l

30 1.16 31

.32 l

32

.57 i

33

.72 34 1.58 35 4.84 36

.19 37

10. 3 5~.

38 1.27 l

39 4.47 40 3.83 o

~

7 APPENDTX #4 Page 2 of 2 1978 TRANSHISSION SALES (COINCIDENT -

CUST. NO.

8/17/78-1700 Hrs.)

1.05' 41 42 8.57 43 1.26 44 1.65 45

.82 Northern Division Subtotal 45.57 46 3.66 47 1.09 48 5.10 49 12.64 50 7.40 51 2.45 52 9.94 53 3.76 54 0.83 55 2.10 56 8.42 57

.64 Bay Division Sub to tal - - - - - - - - - - - - 58.03 58

.51 59 5.02 60 1.25 61 2.15 62

.19 63 2.72 Coast Division Subtotal - - - - - - - - - - - 11.84 1

64 11.84 65 3.23 66

.88 67

.60 68 6.05 i

Southern Division Subtotal 22.30 Boro of Madison - - - - - - - - - - - - - - - 15.0 Company, Total Transmission Sales at time of System Summer Peak: - - - - - - - - - - - - - - - - 240.0 MW

G; '~.';; :s.

u... -

- r ;.,.

~;-.

^-

APPENDIX #5

SUMMARY

OF SALES BY VOLTACE CLASS SAI.ES SECONDARY PRIMARY TRANSMISSION Aesidential 5,044,066 Primary Commercial 173,457 Primary Commercial Heat 76,602 Transmission Commercial 5,507 Transmission Commercial Heat 51,195 Secondary Commercial (Net) 3,088,752 Primary Industrial 1,022,025 Primary Industrial Heat 60,070 Transmission Industrial 1,566,883 Transmission Industrial Heat 36,169 Secondary Industrial 947,900 Lighting

- 87,266 Butler-92,586 Lava 11ette 11,537 Madison 69,924 Pemberton 6,530 Seaside Heights 25,116 REA 73,480 I

i TOTAL 9,167,984 1,467,923 1,803,158 TOTAL MWh - - - - - - - 12,439,065 MWh p

e

.t-

%Mia:wu %

.~..

APPENDIX #6 DISTRIBUTION SUBSTATION LOSSES TRANSFORMER LOSSES

• Average Iron

• Average Total *

• 12/20 MVA (19 samples) 15,202 Watts (0.127%)

77,605 Watts (0.65%)

7.5 MVA (18 sampics) 9,476 Watts (0.126%)

59,966 Watts (0.80*)

AVERAGE LOAD COPPER

• • COINC. COINC.

LOSS IRON LOSS SIZE FE CU PEAK PEAK

_PU.

MW TOTAL MVA (f=0.847) 3 MVA 0.13 0.67 11

~ 2.45 2.08 0.69 0.106 33 5 MVA 0.13 0.67 46 4.02 3.40 0.68 0.735 230 7.5 MVA 0.13 0.67 200 5.77 4.89 0.65 4.267 1500 12 MVA 0.13 0.52 112 8.87 7.51 0.63 2.739 1344 30 MVA 0.13 0.52 2

14.85 12.58 0.42 0.055 60 OTHER (Assume 5 MVA) 0.13 0.67 8

3.43 2.91 0.58 0.905 40 8.79 MJ-3207'MVA x 0.35 x 8760

.0013 x

26,950 MWh 4.17 MW x 8760 = 36,521 MWh

.. g, 2180 MW (net system peak-area substations)

= 0.847 2574 MW (sum of non-coincident substation peaks)

• Ref.: Planning Report 78-05

. 445.tc s-APPENDIX #7 LINE TRANSFORMER' LOSSES REF FERC " Form 1" 1978 Page 447 LINE TRANSFORMERS i

NUMBER KVA' l

Beginning year 173,048 7,580,269 Additions 5,432' 286,263 Reductions 11,099 446,291 Year End 167,381 7,420,241 In Use 142,540 5,652,477 Iron Loss:

5,652,477 KVA x 4.4 Watts /KVA x 10'0 = 24.9 MW x 8760 217,870 MWh

=

COPPER LOSS:

-6 (2060 MW)2*

5,652,477 KVA x 12.7/KVA x 10 x

9.5 MW (5652 MVA)2 =

9.5 MW x 8760 x 0.3503

.29,250 MWh

=

i l

i l

(-

l

?

l l

• 2110 circuit peak 16is 50 MW circuit losses - 2060 MW NOTE: This is recognized to be high since the demand is later shown to be 1857 MW

- load + 9.5 losses = 1867 MW.

c,.. g... as.....

APPENDIX #8 Page 1 of 2 i

JERSEY CENTRAL POWER & LICHT-CO.

l f

1978 LOSS ENERGY APPORTIONMENT "AS REQUIRED BY THE RATE DEPARTMENT" i

'14 Sales Tx 1,803,158 Dx. 1,467,923 Bulk Sys:

52,449 Sec 9,167,984 Tx Losses:

463,200 i

Co 43,168 j

l Total 12,482,233 MWh 4.13%-

515,649 15 4 -

Less Tx'

- 1,803,158 x

4.13%

74,470 MWh I

Nec 10,679,075 MWh 441,179

+Xformer 69,684

+DX Line 153,470 10,679,075 MWh 6.22%

664,333 MWh Less DX

- 1,467,923 x

6.22%

- 91,318 Muh

+Xformer 247,120

+Sec Line 176,041 NET 9,211,152 MWh-10.81%

996,176 MWh TOTAL LOSSES 1,161,964 MWh 13,644,197-NSR.= Load + Losses

=

i

i.,,.p_.,

APPENDIX #8 Page 2 of 2 t

JERSEY CENTRAL POWER & LIGHT CO.

1978 LOSS DEMAND APPORTIONMENT "AS REQUIRED BY THE RATE DEPARTMENT" SUMMER PEAK i

SALES LOSSES I

Tx 240 Bulk 10

{

Dx 297 Tx 130 J

Sec.+ Co 1857 t

2394 MW 5.85%

140 MW 14.0 Less Tx

- 240 x.0585

=

NET 2154 MW 126 MW Xformer 14 l

DX Line 50 2154 MW 8.82%

190 MW t

- 26 Less DX

- 297 x 0.0882

=-

164 MW NET:

1857 MW Xformer 34 Sec.-Line 57 1857 MW 13.7%

255 FN I

t

.b

• JERSEY CENTRAL POWER 4. LIGHT CO Attachment A RETAIL COST OF SERVICE STUDY Page 1 of 4 f

{

DEMAND FLOUS DY VOLTAGE LEVEL I

0 FOR PEAK DAY 1/18/79 P

• s 2530000.

s,

. j.

• • • • • • • • • • • SALES **********

269575.

'.1 TRANSMISSION 230/34.5 KV

• • • • • • • • • • • LOSSES *********

134590.

2133834.

~

• • • • • • • • • • • SALES **********

190132.

PRIMARY 13.2/2.4 KV

• • • • • • • • • • • LOSSES *********

57225.

• • • • • • • E************

t 1886477.

• • • • • • • • • • • SALES **********

1746046.

SECONDARY

• • • • • • COMPANY USE *********

9724.

• • • • • • • • • • • LOSSES *******

• 1.30708.

l M************M******

TOTAL SALES 2205753.

LOSSES

-322324.

CO USE 9724.

TOTAL 2533000.

t L.

i JERSEY CENTRAL POHER & LIGHT RETAIL COST OF SERVICE STUDY;CO Attachment A DEMAND FLOWS BY VOLTAGE LEVEL Page 2 of 4

. -)

FOR PEAM DAY 2/14/79 2550000.

i i

J i

TRANSMISSION

• • • • • • • • • • • SALES **********

312637.

6 230/34.5 KV

• n * * * * *

• L O SSES * * * * * * * *

• i35651.

M l

• • • • • • • M************

I i

210971i.

• • • • • • • • • • • SALES **********

244354.

PRIMARY 13.2/2.4 KV

• • • • • • • • • • • LOSSES *********

56578.

I 1808779.

• • • • • • • • • • • • • • • • • • N*

}

• • • • • • • • • • • SALES **********

1675071.

SECONDARY

• • • • • • COMPANY USE *********

9951.

~

• • • • • • • • • • • LOSSES *********

123758.

• • • • M************%**

i TO TAL SALES 2232062.

LOSSES 315988.

CO USE 9951.

TOTAL 2558000.

i.

k k hd hd b kf "bh N fb hC$'.'f0 HT c o Ace =

• aac ^

L

,q.

DEMAND FLOUS DY VOLTAG2 LEVEL Page 3 of 4 FOR PEAK DAY 7/25/79 i

a e) t 1

1 2550000.

L

• n* n u n* SALES u n***n*

298c 8.

TRANS}!ISSION

[

230/34.5 KV

(

~

• • • • • • • • • • • LOSSES *********

140930.

f

\\'

• • • • • • • • • • M*********

e-2110651.

r.

~

('.

• • • • • • • • • • • SALES **********

230655.

PRDIARY

.P 13.2/2.4 KV

• • • • • • • • • • • LOSSES *********

57606.

t-1822390.

• • • • • • • • • • • SALES **********

1701128.

SECONDARY

• • • • • • COMPANY USE *********

4598.

• • • • • • • • • • • LOSSES *********

116665.

TOTAL SALES 2230201.

LOSSES 315202.

CO USE 4570.

TOTAL 2550000.

1 Attachment A JERSEY CEitTRAL POUCR & LIGHT CO Page 4 of 4

./

OETAIL COST OF SERVICE STUDY DEttAND FLOUS BY UOLTADE LEVEL FOR PEAK DAY G/i/7?

2700000.

f*****4*************

TRANS HSSION

• • • • • • • • • • • SALES **********

314755.

l 230/34.5 KV i

l t

• • • • • • • • • • • LOSSES *********

149221.

t i

l 2236024.

• • • • • • • • • • • • M*******

• • • • • • • • • • • SALES **********

232302.

l PRDfARY 13.2/2.4 KV i

• • • • • • • • • • • LOSSES *********

61027.

• • • • • • • • • • • • • u******

1942695.

l

• • • • • • • • • • • SALES **********

1803859.

1 SECO:iDARY

• • • • • • C0t1PANY USE *********

8371.

\\

l

• L*******d*

LOSSES *********

130465.

i

• • • • • • • • • • • • • • • • k***

TOTAL SALES 2350914.

LOSSES 340713.

CO USE 8371.

TOTAL 2700000.

e Response to Rata Counsel Reauest RD 11

,j 8/27/80

.(Carter)

Page 1 of 2 JERSEY CENTRAL POWER & LIGHT COMPMY Docket No. 804-285 Request RD 11:

With - respect to energy losses:

Provide a statement and supporting studies which will explain how these are attributed to various voltage levels (e.g. Secondary, Primary, 138 kv, etc.) and/or i

customer classes.

This response should state the magnitude of the losses assigned to each category and should include a system-line diagram or flow chart as appropriate."

Response

The same study used for demand loss factors as described in response to RD 10, was used to develop the energy loss factors used in Exhibit JC-203.

The magnitude of losses and flow chart is attached as page 2 of 2.

The cumulative voltage loss factors are listed in the response to the F.E.A. Second Information Request No. 8 (5). The cumulative loss factors were multiplied by the normalized sales to develop normalized NSR's as shown in Exhibit JC-203, page 16 of 18.

l i

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l 1

l l

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I

JERSEY CENTRAL POWER & LIGHT CO RETAIL COST OF SERVIN TTUDY Page 2 of 2 ENERGY FLOWS BY VOLTAGE LEVEL FOR YEAR ENDED: 12,'31/79 13892125.

E k

• • • k*******

SALES **********

2009264.

TRANS!!ISS10N 230/34.5 KV

• • • • • • • • • • • LOSSES *********

550989.

11331932.

• • • • • • • • • • • SALES **********

1428358.

(

(

PRDIARY 13.2/2.4 KV

• • • • • • • • • • • LOSSES *********

222969.

9680605.

• • • • • • • • • • • SALES **********

9333427.

cot 1PANY USE *********

46534.

SECONDARY

• • • • • • • • • • • LOSSES *********

300644.

• • • • • MM****>********

TOTAL SALES 12770989.

LOSSES 1074402.

CO USE 46534.

TOTAL 13S92125.

Response.to Second Info.

Request of F.E.A. No. 8 (Carter) 8/27/80 Page.1 of 6 JERSEY CENTRAL 20WER & LIGHT COMPANY BPU Docket No. 804-285 OAL Docket No. 3518-80 Request No. 8:

Please provide the following items for the test year and al'1 l

work papers and supporting documer. cation 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 prinary and transmission levels by rate clase.

5.

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

46. Customer weighting factors by rate class.

Response

1 The monthly energy sales for the test year ended December 1980 are attached as page 3 of 6 This is from the Original 1980 Budget prior to normalization.

(

2.

This is not available for the test year. Page 4 of 6 contains the noncoincident demand for the two summer and winter months of 1979 which were used to con-struct an average noncoincident demand for 1980 as shown in Exhibit JC-203 page 15 of 18, columns 2, 3, and 4.

3.

This is not available for the test year. Page 5 of 6

(

contains the coincident demands for the two summer and j

winter months of 1979 which were used to construct an l

avestge coincident demand for 1980 as shown in Exhibit JC-203, page 15 of 18, column 1.

l l

l

Page 2 of 6 4.

The demand loss factors used in Exhibit J-203 are:

1/18/79 2/14/79 7/25/79 8/1/79 Secondary 16.59%

16.48%

16.26%

16.65%

a, Primary 8.51%

8.51%

8.82%

8.82%

l Transmission 5.60%

5.60%

5.85%

5.85%

4 5.

The energy loss factors used in Exhibit JC-203 are:

Secondary 9.62%

Primary 6.22%

Transmission 4.13%

6.

See attached page 6 of 6.

i e

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MONTELT DIBROT SALES B7 RATE CIASS TEST TEAR 1980 '

JAN 1980 FEB 1980 '

MAR 1980 APR 1980 MAT 1980 JUN 1980 JUL 1980 AUo 1980 SEP 1980 OCT 1980 R3V 1980 CEC 1980 TUTAL RES!!4NTIALs No-W 267 C17 668 245 238 386 235 117 526 216 682 685 201 551 053 223 598 580 295 569 231 302 774 A 8 277 035 875 217 832 255 220 193 476 - 250 465 R b 2 953 077 0:7-Uncoat

. L6119 000 43 422 000 bl 787 000 39 472 000 36 03b 000 37 647 000 42 062 000 42 315 000 41 059 000 36 510 000 38 762 000 L2 S S 0c0 L87 814 000 Tot Elee 217 682 000 210 575 000 167 082 000 133 040 000 78 766 000 57 176 000*

57 757 000 58 619 000 '

% 996 000 63 008 000 94 712 oco 168 IL6 000 1 363 559 000 Cos.t W A0 789 332 38 250 614 37 781 LTb 35 050 315 32 415 947 32 359 L20 35 284 769 34 195 352 31 792 125 31 7b5 745 33 288 526 37 194 356 k22 147 973 Tot h s 571 608 000 537 486 000 481 768 000 424 245 000 % 8 767 000 350 781 000 h30 673 000 437 904 000 408 883 000 99 096 000 386 956 000 498 451 000 5 226 618 000 :

CENDAL 3DVICE:

Seconlary 335 109 701 375 917 649 357 ok3 417 3412k5 026 325 703 800 349 765 408 378 729 895 378 497 413 372 980 663 - 345 128 233 361 535 765 387 945 027 b 155 Lo2 191 Primary 126 593 Sho 124 120 954 115 882 221 118 794 896 117 563 501 125 860 387

.126 769 911 125 8ko 606

.128 546 170 114 153 588 116 867 653 1A $44 260 1 b45 837 687 :

Transalaston 1k2 831 759 147 79k 197 143 25b 362 1kT $48 078 141 951 699

'163 249 205

.155 373 194 156 284 961 la 830187 170 885 179 161 617 582 176 373 713 1 871 794 116 Totti G.S.

654 535 000 4 8 133 000 ' 616 980 000 607 588 000 585 219 000 638 875 000 660 873 000 6(0 623 000 666 357 000 630 167 000 639 821 000 663 S63 000 7 673 034 000 LIGHT 1::32 OL 1 357 000 1 11% 000 1 102 000 927 000 817 000 124 000

.5 730 000 6 498 000 7 287 000 8 502 000 9 057 000

'9 772 000 90 208 000.

769 000 869 000 955 000 1 121 000 1 171 000 1 258 000 12 I M 000.

SL 9 460 000 7 986 000 7 930 000 6 730 000 6 012 000 5 244 000 Tot Lts 10 817 000 9100 OM 9 032 000 7 657 000 6 829 000' 5 968 000 6 499 000 7 367 000 8 2b2 000 9 623 000 10 228 000 11 030 000 102 392 000 Total Detall 1 236 960 000 1 194 719 000 1 107 780 OCo 1 039 490 000 9LO 815 000 995 624 000 1 098 045 000 1 105 894 000 1 083 482 000 988 686 000 1 03' 005 000 1 173 3kb 000 ' 13 002 OLb 000 '

T Ressle 31 327 000 29 041 000 24 004 000 22 611 000 20 988 000 23 907 000 27 509 000 28 525 000 25 634 000 22 3SS 000 25 139 000 27 639 000 308 712 000 -

~

Tota.1 C4.apazy 1 268 287 000 1 223 760 000 1 131 784 000 1 062 tot 000 961 803.000 1 019 531 000 1E25554000 1 13h 619 000 1 109 116 000 1 011 U k 000 1 062 144 000 1500 983 000'.13 310 756 c0 411 Sales Figures From Original 1980 Bu.1get 4

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