ML19322C493

Application to PSC of CA for Authority to Reduce Electric Rates & Charges Under Energy Cost Adjustment Clause Included in Electric Tariff

ML19322C493
Person / Time
Site:	Diablo Canyon, Crane
Issue date:	06/06/1979
From:	Della Santa B, Furbush M, Ohlbach R PACIFIC GAS & ELECTRIC CO.
To:
References
TASK-TF, TASK-TMR NUDOCS 8001170821
Download: ML19322C493 (73)

Text

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O BEFORE THE PUBLIC UTILITIES COMMISSION OF THE STATE OF CALIFORNIA FTLED 1

Appilcotion of PACIFIC OAS AND ELECTRIC COMPANY for 1 JUN 61979 Authority to Reduce its Electric Rates and Charges under I APPLICATION the Energy Cost Adjustment Clause included in its Electric )

TorlW.

I NO. 5 8 91 i (Electric)

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1 i

O A P P LIC ATI O N Malcolm H. Forbush Robert Obiboch Bernard Della Santo 77 Boole Street son Francisco, California 94106 Attorneys for PacMc Gas and Electric Company d(

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3 8061170[][

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1 BEFORE THE PUBLIC UTILITIES COMMISSION 2

OF THE STATE OF CALIFORNIA 3

4 Application Of Pacific Gas And Electric )

Company For Authority To Reduce Its

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5 Electric Rates And Charges Under The

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APPLICATION Energy Cost Adjustment Clause Included

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6 In Its Electric Tariff.

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NO.

(Electric)

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7

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8 Because of a large decrease in the amount of 9

expensive low sulfur fuel oil it will need for power plant 10 operations when its nuclear units at Diablo Canyon become 11 operative, PACIFIC GAS AND ELECTRIC COMPANY (PGandE) respect-12 fully requests authority to decrease its electric rates and 13 S

charges under the Energy Cost Adjustment Clause (ECAC)

O 14 included in PGandE's electric tariff.

PGandE proposes that 15

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this rate decrease be made effective on the dates when 16 Diablo Units 1 and 2, respectively, became commercially 17 aperative and concurrently with corresponding base rate 18 increases under the adjustment procedure proposed by PGandE

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19 in a companion application filed today.

pa 20 It is expected that Diablo Canyon Unit No. 1 will

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21 become commercially operative during the latter part of Er 22 1979.

If that date for Unit No. 1 is December 1, 1979, the 23 base rate adjustment will amount to an increase of 0.2743 24 cents per kilowatt hour on jurisdictional sales for the 25 first 12 months of operation, which amounts to an increase

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26 of about $155.7 million, or 6.7 percent, annually.

If Unit

1 No. 2 becomes commercially operative on August 1, 1980, the 2

adjustment for Unit No. 2 will be an increase of 0.2102 3

cents per kilowatt hour for the first 12 months of its 4

operation, which amounts to about $122.4 million, or 5.1 5

percent, annually.

The proposed ECAC rates, which reflect 6

the lower fuel costs resulting from displacement of higher 7

cost fossil fuel electric generation by lower cost nuclear 8

generation, will decrease PGandE's electric revenues in an 9

amount sufficient to offset the proposed increases in PGandE's 10 base electric rates to cover the costs of owning and operating 11 Diablo Units 1 and 2.

12 I

13 BACKGROUND 14 On December 23, 1966, PGandE filed Application No.

15 49051 requesting the Commission to iss'te a certificate of 16 Public Convenience and Necessity for the construction of 17 Unit No. 1 at Diablo Canyon Nuclear Generating Station.

18 After 20 days of hearings, the Commission issued Decision 19 No. 73278 authorizing construction of Unit No.

1.

Since 20 that cime, PGandE has gone through many years of regulatory 21 proceedings at all levels of local, state and federal govern-s 22 ment to obtain the necessary permits and licenses to operate 25 the Diablo Canyon plant.

Final hearings on the issuance of 24 an operating license for Unit No. 1 before the Atomic Safety 25 and Licensing Board (ASLB) began in December 1978 and concluded h'

26 on February 15, 1979.

T

' /3 1

Diablo Canyon was not included in PGandE's 1978 or 2

1980 test year general rate cases (Application Nos. 57284 3

and 58545) since the Commission indicated that it wished to 4

consider this matter in a separate proceeding.

In Decision 5

No. 86281, the Commission excluded construction work in v

6 progress (CWIP) from rate base.

In so doing, it stated that 7

the timely inclusion in rate base of significant additions 8

to plant was a subject not well suited to current ratemaking 9

procedures.

The Commission, therefore, proposed that the 10 addition of Diablo Canyon be considered in conjunction with 11 an ECAC proceeding at the appropriate time.

12 In a companion application, PGandE is proposing 13 the establishment of an electric base rate adjustment proce-14 dure wit'h a balancing account and rate adjustments to go 15 into effect on the commercially operative dates of Unit 16 Nos. 1 and 2 in order to cover the cost of owning, operating, 17 and maintaining the units.

The details of the proposal are 18 set forth in that application.

The offsetting ECAC rate 19 reduction proposed herein is contingent upon Com!Eission 20 authorization of the base rate adjustment procedure.

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22 REASONS FOR THE ENERGY COST ADJUSTMENT.

23 Electric. power generated from Diablo Canyon will 24 be less expensive to produce than that generated by the 25 conventional steam electric plant which burns fuel oil.

The first unit of the hlant, operating at 65% capacity factor,

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26 1

will produce electric power at approximately 33 mills per 2

kilowatt hour which will be the lowest cost of any thermal 3

plant on PGandE's system.

For the second unit, the cost 4

will be approximately 27 mills per kwh.

5 When Unit No. 1 becomes operational, PGandE can 6

reduce the load on some of the relatively less efficient 7

generating units in its system and reduce its fuel oil 8

requirements.

For a 1084 megawatt unit operating at 65%

9 capacity factor, the annual savings in fuel oil would be 10 9.6 million barrels.

At a cost per barrel of $17.00, there 11 would be a $164 million reduction in fuel oil cost.

The net 12 reduction in fuel cost would be $125 million assuming nuclear 13 fuel costs of 6.2 mills per kilowatt hour.

In addition, 14 with operation of this unit, PGandE will not have to rely on 15; purchases of expensive power from other sources to meet its 16 load requirements.

The resulting lower energy cost means 17 that PGandE can pass this decrease along to its electric 18 customers through a reduction in ECAC rates.

19 Under the existing ECAC, however, which is based 20 on balancing account accumulations and on historical relation-0 c

21 ships between fuel costs and related revenues, the lower

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22 fuel costs resulting from commercial operation of the Diablo 23 units would not be fully reflected in ECAC rates until 24 approximately a year after the units began operation.

25 PGandE proposes to pass the reduction through to its customers 26

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immediately upon commercial operation of the units to offset 2

the costs of owning and operating them.

3 III 4

ENERGY COST ADJUSTMENT RATES 5

Exhibit A, attached, includes each of PGandE's 6

present rates for electric service which are proposed to be 7

changed.

PGandE has included lifeline usage in the proposed 8

Diablo Canyon ECAC rate adjustment.

9 The proposed estimated net decrease of $155,758,000 10 for Unit No. 1 spread to jurisdictional sales, including 11 lifeline usage, results in a 0.2743 cents per kilowatt hour 12 decrease and the effect of the decrease on clascas is as

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13 follows:

14 COMMERCIAL OPERATION DATES OF DECEMBER 1, 1979, FOR UNIT 1 AND 15 AUGUST 1, 1980, FOR UNIT 2 16 Class of Service Revenue Decrease Percent b

17 (000's)

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18 Unit Unit Unit Unit No. 1 No. 2 No. 1 No. 2 19 RESIDENTIAL

$ 51,332

$ 40,609 7.3 5.6 20 SMALL LIGHT AND POWER 12,749 9,885 5.1 3.9 MEDIUM LIGHT AND POWER 36,490 28,936 6.1 4.6 21 LARGE LIGHT AND POWER 41,118 32,293 7.4 5.6 PUBLIC AUTHORITY 1,654 1,287 7.0 5.4 22 AGRICULTURAL 10,207 7,798 6.4 4.5 STREET LIGHTING 1,130 799 3.9 3.0 23 RAILWAY 686 526 8.2 6.3 INTERDEPARTMENTAL 392 305 6.0 4.6 24 TOTAL JURISDICTIONAL

$155,758

$122,438 6.7 5.1 25

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COMMERCIAL OPERATION DATES OF FEBRUARY 1, 1980, FOR UNIT 1 AND 2

OCTOBER 1, 1980, FOR UNIT 2 3

Class of Service Revenue Decrease Percent 4

(000's) 5 Unit Unit Unit Unit No. 1 No. 2 No. 1 No. 2 E

RESIDENTIAL

$ 52,590

$ 41,826 7.5 5.7 7

SMALL LIGHT AND POWER 13,015 10,125 5.2 4.0 MEDIUM LIGHT AND POWER 37,400 29,841 6.2 4.7 8

LARGE LIGHT AND POWER 42,079 33,183 7.5 5.8 PUBLIC AUTHORITY 1,691 1,318 7.1 5.5 9

AGRICULTURAL 10,379 7,950 6.5 5.0 STREET LIGHTING 1,127 799 4.0 3.1 10 RAILWAY 698 537 8.4 6.4 INTERDEPARTMENTAL 399 313 6.1 4.7 11 TOTAL JURISDICTIONAL

$159,378

$125,892 6.8 5.2 12 The proposed adjustment rates and the derivations 13 of each are included in Exhibits B and C, attached.

l 14 Iy 15 RESULTS OF OPERATIONS 16 Exhibit D, attached, shows PGandE's Electric 17 Department results of operations used by this Commission in p

18 Decision No. 89316, dated September 6, 1978, at present and

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19 at the base rates proposed on December 1, 1979, and August 1, 20 1980, if Diablo Canyon Unit Nos. 1 and 2 are commercially 21 operative on these dates.

2.'

y 23 TYPE OF RATE CHANGE SOUGHT 24 PGandE states that the proposed ECAC adjustment in 25 this application reflects and passes through to its customers 26 only the effect of anticipated decreased energy costs for 1

electricity furnished to its customers due to the commercial 2

Operation of. Unit Nos. 1 and 2 at Diablo Canyon.

3 VI 4

PACIFIC GAS AND ELECTRIC COMPANY 5

PGandE is, and ever since October 10, 1905, has 6

been, an operating public utility corporation, organized

'1 under California law.

It is engaged principally in the 8

business of furnishing electric and gas service in California.

9 It also distributes and sells water in some cities, towns 10 and rural areas, and produces and sells steam in certain 11 Parts of San Francisco.

12 PGandE's principal place of businecs is in San 13 Francisco, California.

Its post office address is 77 Beale

-14 Street, San Francisco, California 94106; its telephone 15 number is 781-4211; and its attorneys in this matter are 16 Malcolm H.

Furbush, Robert Ohlbach and Bernard J. Della Santa.

17 Communications regarding this application are to 18 be addressed to Malcolm H. Furbush at the above-mentioned 19 address.

20 A certified copy of PGandE's Articles of Incorpo-21 ration, amended to the date of this. application, is of h' "

22 record before the Commission in connection with PGandE's 23 Application No. 56435, filed April 27, 1976, and these

-24 Articles are incorporated herein by reference.

25

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1 Attached as Exhibit E are a balance sheet and a 2

income statement indicating PGandE's financial status as of 3

March 31, 1979.

4 Exhibit F, attached, shows for the year 1978 the 5

revenues, expenses, and rate of return, on a depreciated 6

basis, for all of PGandE's operating departments and for its 7

Electric Department.

8 The original cost of PGandE's electric properties, 9

together with the applicable depreciation reserve, consistent 10 with Exhibit F, is as follows:

11 Total Electric Plant

$5,773,748,000 12 Operative Construction Work in Progress 4,285,000 Total Operative Plant 5,778,033,000 14 Depreciation Reserve 1,741,729,000 16 A more detailed description of PGandE's electric 17 properties and equipment is included in PGandE's exhibits 18 filed with Application No. 58545, filed December 26, 1978, 19 which are incorporated herein by reference.

Ic 20 Incorporated by reference herein is a copy of if 21 PGandE's most recent proxy statement sec.t to its shareholders.

22 This proxy statement was filed with the Commission by PGandE 23 in Application 58798 on April 10, 1979.

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1 VII 2

STATUTORY AUTHORITY 3

This application is made pursuant to Sections 451, 4

454, 491 and 701 of the Public Utilities Code of the State 5

of Chlifornia.

6 VIII 7

SERVICE OF NOTICE OF APPLICATION 8

In compliance with Rule 24 of the Commission's 9

Revised Rules of Practice and Procedure, a list of the 10 cities and counties affected by the proposed energy cost 11 adjustment is attached as Exhibit G.

The State of California 12 is the only state affected by the proposed decrease.

Within g-~s 13 ten days af ter filing this application, notice as provided

'A 14 in Rule 24 will be mailed to the appropriate officials of 15 all of the foregoing entities and to the parties of record 16 in PGandE's ECAC filing of April 28, 1978, Application No.

17 58033, and PCandE's pending general rate case, Application 18 No. 58545.

-b 19 IX 1

A' 20 ACCOMPANYING EXHIBITS

.L 21 PGandE's exhibits and prepared testimony in support 22 of this application accompany this filing with the Commission.

23 PGandE is now ready to proceed with its showing in 24 support of this application.

l 25 WHEREFDRE, PACIFIC GAS AND ELECTRIC COMPANY respect-

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26 fully requests the Commission to irrue appropriate orders:

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l l,

I

(3 1

1.

Authorizing PGandE as of the commercially 2

operative date of Unit Nos. 1 and 2 to file 3

and place into effect the proposed ECAC 4

adjustments set forth in Exhibit B attached, 5

contingent upon the establishment of a base 6

electric rate adjustment procedure as set 7

forth in the companion application filed 8

herewith.

9 2.

Finding that the authorized rates are fair 10 and reasonable, and justified.

11 3.

Granting PGandE such further and different 12 relief as the commission may find to be rN 13 proper.

U 14 Dated at San Francisco, California, this 6th day 15 of June 1979.

16 STANLEY T. SKINNER 17 STANLEY T.

SKINNER Executive Vice President 18 S

19 MALCOLM H.

FURBUSH S

MALCOLM H. FURBUSH f*

20 21 ROBERT OHLBACH ROBERT OHLBACH 22 23 BERNARD J. DELLA SANTA EERRARD J. DELTA SANTA 24 Attorneys for 25 PACIFIC GAS AND ELECTRIC COMPANY 77 Beale Street

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26 San Francisco, California 94106,

O 1

DECLARATION 2

I, the undersigned, say:

3 I am an officer of PACIFIC GAS AND ELECTRIC COMPANY, 4

the applicant herein, and I make this declaration as such on 5

behalf of said applicant.

I have read the foregoing applica-6 tion and know its contents.

It is true of my knowledge, 7

except as to those matters which are stated therein on 8

information and belief and as to those matters I believe it 4

9 to be true.

10 I declare under penalty of perjury that the fore-11 going is true and correct.

12 Executed at San Francisco, California, this 6th

's 13 day of June 1979.

i 14 I

15 16 STANLEY T. SKINNER Executive '.fice President 17 18 19 9

20 a

C 21 F

22 23 24 25

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EXHl817 A PRESENT RATES i

I OeM UN Pacide Gas and Electrie Company Revised Cal. P.U.C. Sheet No. 7059.E San Francisco, California Canceling Rensed Cal. P.U.C. Sheet No. 7055.E TABLB OP CONTENTS I

I The fellow!as listed tarif sheets costata the preliminary statement, all egee'.;ve rates, rulee and regulatiota and sample forma afeettag rateu and servios and taformation relattag thereto to effect on and after the date ladleated therece.

CeL P.U.C Shams No.

71dePhpe 4440-E TeWe of 8" 7059-E TeWe of Ceesesser-Schedale of ""-

7059 7058-E TeWe el Comesses-Contracts and Deviattoo=

7058-E TeWe of t' R=w 7058-E TeWe of Comammer -Sample W 7022-7021 E Preliminary Sesameessas Pass A (1) Territory Served by Company 6856-E (3) Desertation of Servloe 6282 E (3) Procedure to Obtata Servia=

6282-E (4) Estabitahment of Credit and C; ^ =

6282 E (5) General 6857-E (8) Mvice la C!tles and Towns Not Generally Served by the Utility 6857 E D) symbola 6857-E Part B-Energy Cost AdJ-70054964-6965 7032 E Part C-Tas. 3ange Adjusaneer Clane.

6822-E Service Area Map.

4532-5490-4524-4525-467146724674-E Sheste Dame Rats Area M-4119 E SCHEDULE OF RATES Ashedste Cal. P.U C No.

Tiefe of Sh e 5bese N..

GENERAL SERVIG A1 General Service 7033 E A-12 General Servlee-Demand Meter =d 70344006-E A 18 General Service-Demand Meter =d 7035-E A 15 General Servlee-Direct Curren*

7036 E A 18 Interruptible Primary Industrial Power 7037-6012 E A 23 General Service-Time Metered 7038 6364 E A41 General Power Servies 67464725-E OE,1 Outdoor Area Lightin!

7039-6750 E DOMESTIC SERVIG D1 Domestle Service TCM 7007-E ING Domeetle Servlee 7006 7009 E DE Service to Company Besplor===

4739 E DM Multi-Family Servt=

19417010 E DS MultiPanDy Servloe 1642 7011 E DT Multi Family Service-Mob!!ehome Park 79436996-E S11ENT AND HIGHWAY IJGDf!DeG 141 Street and Highway Lighting 7044-68724873-E LS4 Street and Highway Lighting 7012 70454876 E 148 Street and Highway Lighting-Electro 11er Meter Rate 7046-6878-E TC1 Traffle Contrei Servlee 7047-E POWER SERV 1G P4 O!! Refinery Electrie and Steam Servt&

70484959-E PA-1 Agricultural Power 7049-6043 E S1 Stand-by Servico 70504972-6973 E (continued) i Advice LetterNo. 735.E Issued by DateFiled Anril 13. 1979 Decision No.

W. M. Gallavan Effective Mav 15. 1979 Vice-President-Rates and Valuation Resolution No. E-1837

e is Pacifle Gas and Electric Ccmpany Revised Cal. P.U.C. Sheet No. 7058-E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 7054-N O

TABLE OF CONTENTS (Continued)

SCHEDULE OF RATES (Condnued)

EXPERIMENTAL SERVICE Schednig Cat P.U.C.

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No.

Tide of Sheet Sheet No.

A 20A Experimental General Service Demand Metered 69024903-E A 20B Experimental General Service Time Metered 6904 6905 E A 20C Experimental General Service Time Metered 6906-6907 E A 20D Experimental General Service Time Metered 6909-6909-E AD Experimental Non Domestic Load Deferra! Service 7051 E DA Expertmental Domestic Air Conditioning Load Deferral Service 7056-E DC Experimental Dorpestic Controlled Load Service 7057 E PA-1K Experimental Agricultural Power Time Varying 70534790 E CONTRACTS AND DEVIATIONS Title of Sheet Cal. P.U.C. Sheet No.

L!st of Contracts and Deviations 6686-6763-6764-6687-49754688-6689-617641774690-6691-669246934 69447654 7664767 66934768-6700 6769477047714772-6960-6774-6707-6708-6775 E m

RULES Ru!e cal P.U.C.

No.

Tide of Sheet Sheet No.

1 L9finitions 6805 E 2

Description of Service 4954-2646-2755 2756-1067 6912 E 3

Application for Service 6276-E 4

Contracts 1069-E 5

SpecialInformation Required on Forms 6755 E 6

Estab11shment and Re-establishment of Cred!'

6756 E

?

Deposits 6185-E Notices 1073 E 9

Ren'eting and Payment of Bills 43 46-E 10 Disputed Bills 6757 E 11 Discontinuance and Restoration of Service 67584759-6760-E 12 Rates and Optional Rates 1077 E 13 Temporary Pervice 3196-E 14 Shortage of Supply and Latorruption cf Delivery 1079 E 14.1 Prohibitione and Curta!! ment Provisions 6938-6939-E 15 Line Extenaton=

1175 5788-53114789-4889 4690-3197 E 15.1 Underground Extensions W! thin New Residential Subdivisions and Residential Developments 5994-4550-E 15.2 Underground Extensions Within New Commercial and Industrial Developments _4892 4893 E 16 Service Connections and Facilities on Customer's Premises 4378-4374-4375-4379-4380-43814382-E 17 Meter Tests and Adjustment of Bills for Meter Error 2323-E 18 Supply to Separate Premises and Submetering of Electric Energy-70017002-E 19 (Not Used) 20 Replacement of Overhead With Underground Fact 11tles

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6915-6229-E (continued) m Advice Letter No. 735-E Issued by Date FiledApril 13, 1979 Decision No.

W. 3I. Gallavan Effective May 15, 1979 Vice. President-Rates and Valuation Resolution No. E-16J /

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PeelAs Gee and Eleotric Company Revised Cal. P.U.C. Sheet No. 6963.E San Fraamiseo, California Canceling Revised Cal. P.U.C. Sheet No. 6437.E PRELIMINARY STATEMENT (Continued)

PAF.T B Emergy Coet Adji-t Clause (ECAC) 1.

Applicabdity This energy cost adjustment clause applies to bills for service under applica.

ble rate schedules and under contracts subject to the jurisdiction of the Cali-fornia Publie Utilities Commission.;

2.

Bene Rates The base rates are the rates for electric service effective or. the effective date hereof.

3.

Base Weighted Rate for Fuel and Pur4== A Energy The base weighted rate for fuel and purchased energy included in Base Rates is $0.00000 per kilowatt. poor.

4.

Record Period The volumes of fuel and energy to be used hereunder for the Record Period are those s,etually purchased, consumed, and sold, as the case may be, during the twelve calendar month period ending at the end of the month prior to the month in which the filing date occurs.

5.

Revision Dates The Revision l>ates are July I and January 1 of each year. On such dates or as soon thereafter as the Commission may authorize, the Utility shall, in ae-cordance with the provisions hereof, piece into efect an increase or decrease in the Adjustment Rate then in efect to reSeet changes in the average cost of fuel and purchased energy and the Eureka Energy fuel service charge for projects approved by the California Public Utilities Commission. Unless otherwise authorised or ordered by the Commission, such increases or de-eresses shall be made not more than twice in any calendar year.

6.

Adjusanese Ras The amount hereunder to be added to or subtracted from each bill shall be the prodnet of the total kilowatt hours for which the bill is rendered multi, plied by the Adjustment Rate. The Adjustment Rate, to become efective for service on and after each Revision Date and continuing ti.ereafter until the next Adjustment Rate becomes effective in accordance herewith, shall be the algebrale sum of an Ofset Rate and a Balancing Rate, each multiplied by 1.01 (to adjust for franchise and uncollectible accounts expense) and carried to the nearest 90.00001 per kilowett hour. The Adjustment Rate applicable to each rate sebedule will be set forth on that rate schedule.

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(a) The Ofset Rate shall be the diference between the Current Fuel and Purchased Energy Cost per kilowatt hmr of sales, and the Base Weight-ed Rate for Fuel and Purchased Energy, as set forth in Section 7 below.

See last page for footnotes.

(continued)

Advice Letter No. 712-E leeued by DateFiled December 8,1978 Decision No. 88121 W. M. Gallavan Effective December 28, 1978 l

Vice-President-Rates and Valuation Resolution No.

Wm ~hg6WG f

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cseses

o. en Pacine Ons and Eleetrie Company R.. vise.1 i.d. I' l '.t!. Sheet No. 6%I E San Francisco. California e a.. < ' ice fi,!vi ed U.d. I'.l1 Sheet No. 61sE

=

PRELIMINARY STATEMENT (Continued)

PART B (Cont:nued) 6.

Adjustment Rate (Continued)

(b) The Ba'ancine Rate shall be an amount per kihmatt hour or -ab s n.

esaary to amortire the accumulated balance in fin Energy Cost adjust.

ment Account, included as a subaceount in CPIT Accounts Nus. 1%

and 253. The procedures for determining tb-11alanrine Hate and for maintaining the Energy Cost Adjustment Account are set forth in Sec.

tions 9 and 10 below.

(c) The rates determined above shall be further ad.insted to rettect the pr..-

visions of Section 739 ' f the Public l*tilities rude, relatine to lifehni o

rates, a implemented by the Cnmmiwinn.

7.

06 set Rate The Offset Rate shall be determined as (1) the amount of the Current Cmt of Fuel and Purchased Energy determined as specified in Section 8 l-low. less (2) the total Record Period reunues from the California Department of Water Resources under present contract %. all divided by (31 the Record Period kilowatt hours of total sales,' and then less (4) the Base Wrighted Rate for Fuel and Purebased Energy.

8.

Current Co.: of Fuel and Purchased Energy (a) The current cost of fuel and pureba. sed energy shall be equal to:

(1) The volumes of gas and of each type of oil and coal fuel used for electric generation in the Record Period," expressed in millions of Btu and the volume of geothermal and nucitar production in the Record Period, expressed in kilowatt hours, multiplied by the eur.

rent price of each as set forth below, plus (2) The total cost of purchased electrie energy as recorded in the Rec.

ord Period in CPUC Account No. 555, Purchased Power."' exclud-ing operation and maintenance payme cts. plux (3) The annualized Eureka Energy fuel service charge in edert on or before th filing date for projects approved by the Commission.

(b) Current prices shall be determined as follows:

(1) The current price of gas fuel shall be the average of each applicable gas rate schedule, expressed in cents per million Btu, in effect on or before the Revision Date, weighted by the quantity of gas used under each such gas rate schedule during the Record Perand.

(2) The current prices of oil and coal fuel shall be the current ascruge cost in dollars per million Btu of each type in inventory (CPIIC Ac.

count No.151, Fuel Stock) on the Bling date.

(3) The current prices of geothermal steam shall be the prices per kilo.

watt hour of geothermal plant output (including payments for ef.

fluent disposal) of steam producers efective for production on or before the Bling date.

(4) The current prices of nuclear fuel shall be the unit rates of amor.

tization, exprcssed in cents per kilowatt hour, of nuclear fuel as-semblies, including an allowance for salvage value, determined in accordance with CPUC Account No. 518, Nuclear Fuel Expense, and efective for production on or before the Bling date.

(5) Utility owned hydro generation shall be included at zero cost.

See last page for footnotes.

(continued) m Advice Letter No. 712-E Issued by Date Filed December 8, h Decision No. 88121 W. 31. Gallavan Effective December 28, 1978 Vice President-Rates and Valuation Resolution No.

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,=.en Pasios Gas and Blastria Company Revised Cal. P.U.C. Sheet Ns. 6945.E San Franoiano, California Canceling Revised Cal. P.U.C. Sheet No. 6337.E n

PRRNfMARY STATEMENT (Cousiused)

PART B (Ceesimmed) g The Balancing Rate per kilowatt hour sold shall be deteresined by dividing (1) the balance in the Energy Cost Adjustment Aseonat at the end of the latest available month at the time of the computation being saade under the provisions hereof, by (2) the Boeord Period kilowatt hours of applicable ju-rindietional sales.*

10. Emessy Cast Adjesameer Assemos Efective April 1,1976, the Utility shall maintain an Energy Cost Adjust-naent Aeeount. Entries shall be made to this secount at the end of each month as follows:

j (a) A debit entry equalto,if positive (credit entry,if negative):

(1) the actual fuel expense during the month for the generation of electricity, actual purchased energy expense during the month es.

cluding operation ar.d reaintenance payments and the Eureka Energy fuel service charge during the month for projects approved by & Co==imaion,less (2) & amount of revenue billed durity the month under the Osset Bete (not includmg the adjustament for franchine and uneollectible 1

aseonats expones),less (8) the assonat equal to the volume of energy sold dun'ag the month to which the Adjustament Rate is applicable multiplied by the Base Weighted Rate for Fuel and Purchased Energy, less (4) the amocnt of revenue billed during the month to the California De.

partament of Water Besources under present contreets, less O-(5) the amount of revenue,if any, billed during the month for the fuel and purchaamd energy component of inter eystem transactions based j

on incremental or replacement fuel costa, lesi (6) the recorded fuel expense during the month associated with fuel re-eeipts in payment for electrie service but not to exceed the expense for fuel actually need to provide such service.

(b) A credit entry equal to the amount of revenue billed during the month under the Balancing Bate (not ineluding the adjustment for franchise and uneollectible aseounts expense) if positive (debit entry,if negative).

(e) If the Utility resolves frosa any of its gas or goothermal or purehased energy suppuere cash refunds, inelndmg any associated interest, on and after the date this Ene. e Cest Adj==e===t Clause baaamas efective, the l

amount thereof associate ! sith sales of electricity shall be recented as a esedit to the Utility's Energy Cost Adjustment Aeoonnt. Cash refunds assseisted with parahaman of coal, oil, or nuclear fuel shall be recorded as a eredit to the appropriate inventory aeoonat. An appropriate ad-justment shall be made to redeet ar.y sale of fuel (d) A debit entry equal to 7/12 percent of the average of the balance in this seeount at the beginning of the month and the balance in this account after entries (a), (b) and (c) above, if average balance is debit (credit entry, if average balanee is credit).

see last asse for rootnotes.

(osattooed) r~

O DecisionNo.88121

..dvice Letter No. 712.E Issued by Date F.,ed December 8,1978 W. M. Gallaven Efective December 28, 1978 Vice. President-Rates and Valuation Resolution No.

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.in Pacifle Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7032-E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 63W

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6

.s.ooe no ass Pacific Gas and Electric Company Revised Cal. P.C.C. Sheet No. 6006.E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 4714.E O"

Schedule No. A 12 GENERAL SERVICE - DEMAND ME~ERED (Continued)

4. Voltase Discounes (1) When delivery hereunder is made at the same voltage as that of the line from which the service is supplied, or (2) when sufficient capacity is not available in distribution facill-ties e11 sting in the area to supply the customer's requirements, and the Utility has elected to supply service from a transmission !!ne for its operating courentence by means of Utility owned transformers on the l

customer's property, a discount of 4% when such delivery le made at 11 kT or abora and 3% when such 1

delivery is made at 2 kr to 10 kv inclusive, will be allowed on the above charges. including the minimum

)

charge, provided. however, the Utility is not requircel to supply service at a non standard voltare. When i

service la supp!!ed directly without transformattun from a transminston line of 60 kV or higher.t. disenunt I

of 55 will be allowed. The Utility retains the right to change its line vcitage at any time, after reasonable advance notice to any customer receiving a discount hereunder and affected by such chan;e. and such customer then has the option to chenge his system so as to receive service kt the new line voltage or to accept service t without voltage discount) through transformers to he supplied by I'tility.

]

5. Power Factor: When the billing demand has exceeded 400 kw for three consecutive months and thereafter until it has fallen below 300 kw for twelve consecutive months, bills w111 be adhtsted for bi-wetthted monthly average power factor as follows:

The total charge (except the minimum charge) for any month as computed on the above rates will be decreased or incrossed. roepectively, by 0.1% for each 1% that the average power factor of customer's loed in the month was greater or less than 85%, such average power factor to be computed (to the nearest whole.per cent) from the ratto of lagging kilovolt ampere hours to kilowatt hours consumed in the month, provideJ. however, that no power factor correction will be made for any month when customer's maximum demand was less than 10% of the highest such demand in the preceding eleven conths.

6. Contract: For customers who use service for only part of the year this sc.zedule is applicable only on annual contract.

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) VAdvice Letter No. 512.E Issued by Date Filed Seet. 16. 1975 Decision No. 84902 W. M. Gallavan Effective Scot. 21. 1975 Vice President-Rates and Valuation Resolution No.

i

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2

es-ease no. ase Pacifle Oas and Electric Company Revised Cal. P.U.C. Sheet No 7035.E San Francisco, California Canceling itevined Cal. P.U.C. Sheet No, tW77 "

Schedule No. A.13 GENERAL SERVICE-DEMAND METERED APPLICABILITY This schedule is applicable to polyphase alternating current service, except that this schedule is not applicable to service for which Schedule No. A.23 is applicable.

'ITRRITORY The entire territory served.

RA'ITS Per Month Demand Garges Per Meter First 1,000 kw of billing demand

$ 2,658.00 Over 1.000 kw of billing demand, per kw 2.12 Energy Garge (in addition to the Demand Charge):

ntst 100 kwhr per kw of billing demand, per kwhr

.01451 Next 200 kwbr per kw of billing demand, per kwhr

.00991 All excess, per kwhr

.00791 Minimum Charges The Demand Charge constitutes the h!!nimum Charge.

Adjustments:

The above base rates are subject to possible adjustment for voltage and/or power factor. In addition, bills for service willinclude adjustments, as specified in Parts B and C of the Preliminary Statement, as follows:

perkwhr Energy Cost Adjustment 8.01722 Tax Change Adjustment -

(.00071)

Tots!

$.01651 SPECTAL CONDITIONS

1. Maximum Demand The maximum demand in any month will be the maximum average power taken during any 80. minute intervalin the month, but not less than the diverstfled resistance welder load computed in accordance with Rule No. 21 provided, that in cases where the use of energy is intermittent or subject to violent fluctuations, either a 5-minute or a 15. minute interval may be used.

2. Billing Demand The billing demand to be used in computing charges will be the mean of the maximum demand as determined under Special Condition 1 above for the current month and the highest such demand occurring in the year ending with the current month, but not less than 1,000 kw.

3, Off. peak Demand: Any customer under a contract for service for a period of 5 years may, upon request, for billing purposes, have maalmum demands igno*4d which occur between 10:30 P.ht. and 6:30 A.M. of the following day and on Sundays and the following holidays: New Year's Day, Wash!ngton's Birthday, Memorial Day, bdependence Day, Labor Day, Veterans' Day, Thanksgiving Day and Christmas Day, as said days are specified in Public Law 90-363 (U.S.C.A. Section 6103).

4. Voltage Adjustment: The above charges are applicable without adjustment for voltage when (a) delivery is made at lean than 2 kv, or (b) when delivery is made by means of Utility owned transformers at a distribution voltage other than a standard primary distribution voltage, or (c) when delivery is made at a voltage that requires more than one stage of transformatiou from transmission voltage. When delivery is made at the standard primary distribution voltage at 2 kv or above available in the area from the Utility's distribution line or, where the Utility has elected to supply service at a standard primary d!stribution voltage from a transmission line, for its operating convenience, from Ut!!!ty. owned transformers on the customer's property, the above charges for any month will be reduced by 15d per hw of billing demand in the month. When delivery is made at tran3 mission voltage (60 kv and above), the above charges for any month will be reduced by 25# per kw of billing demand in the month. The Utility retalas the right to change its !!ne voltage at any time, after reasonable advance notice to any customer receiving a discount hereunder and affected by such change, and such rustomer then has the option to

~

change his fystem so as to receive service at the new line voltage or to accept service through trans formers to be supplied by Utility subject to the voltage adjustment above.

S. Power Factor: The total charge for any month as computed on the above rats will be decreased or increased, respectively, by 0,1*5e for each 1% that the aversas powwr factor of customer's load h the r

month was greater or less than 8 %, such average power factc1 to be computed (to the nearest whcte per cent) from the ratio of lagging kilovolt ampere hours to kilowatt hours consumcd in the month.

6. Voltage Service on this schedule will be supplied at the transmission or the primary dinribution available, or, at the option of the customer, at the secondary voltage available.

(continued)

^

Advice Letter No. 734.E Issued by Date Filed Aori1 13. 1979 Decision No.

W. M. Gallavan Effective May 15. 1979 Vice. President-Rates and Valnation Resolution No. E-1836 D]

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.ee Revised Cal. P.U.C. Sheet No. 7036-E Pacifle Ges and Electric Company Canceling itevised Cal. P.U.C. Sheet No. 6978-E San Francisco, California O

Celiadenla A.D GENERAL SERVICE-DIRECT CURRENT APPLICABlUTY This schedule is applicable to direct entrent lighting service including lamp socket appliances and, at the customer's option, to direct entrent service for power and heating alone or combined with lighting on the same meter. This schedule is applicable only to those establishments wkleh continued service ander this schedule on and after February 18.197L TERRITORY Certain downtown areas of San Francisco, Oakland and Stockton where direct cur-rent is available.

Per Meter Per Month RATES 31.75 Customer Charge:

Esursy Gerse (in addition to the Customer Charge):

.060 All kwhr. per kwhr Minimum Cherse: The Customer Charge, except where motors aggregating more than 5 hp are connected. In which case the total minimum charte will be $1.60 per month per bp.

Adjustments:

Adjustments, as specified in Parts B and C of the Preliminary Statement, will be added to each bill for service calculated at the above rates, including bills for mini-mum charges. Adjustment amounts are as follows:

per kwbr Energy Cost Adjustment 5.01722

(.00071)

Tax Change Adjustment 5.01651 Total SPECIAL CONDITION The maximum demand in any month will be the average kw delivery of the 15 minute interval in which steh delivery is greater than in any other 15-minute interval in the month. The billing demand to be used in competing charges will be the mean of the maxi-mum so determined for the current month and the highest such demand occurring in the year ending with the current month.

Advice Letter No. 734-E Issued by Date Filed April 13 3 1979

%J Decision No.

W.M. Gallavan Effective May 15, 1979 Vice-President-Rates and Valuation Resolution.No. E-1836

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esCaos see, se4 Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7037.E San Francisco, Calif 0rnia Canceling Revised Cal. P.U.C. Sheet No. 6979.^

Schedule No. A.18 INTERRUPTIBLE PRIMARY INDUSTRIAL POWER APPLICABILITY This schedule is applicable to three-phase alternating current service for industrial customers with maximum demands of 5,000 kilowatts or more at standard voltages of 60,000 volts or higher to be supplied at the high voltage terminals of a sub-station to be owned or leased by the customer. Service under this schedule is supp!!ad if, in the Utility's sole judgment, there exists sufficient reserve and transmfesion margin.

TERRITORY The entire territory served.

RATE Per Meter Demand Charges Per Month On-Peak, per kw of Maximum Demand, but not less than 37.000 per month

$1.40 Off Peak, per kw of Maximum Demar.d in excess of the On Peak Demand

.35 Energy Charger All kwbr, per kwhr

.00329 Limitation on Charges:

The charges billed on the above rates shall not be in excess of those that would be billed under Schedule No. A 23 or its successor.

Adjusunents:

The above base rates are subject to possible adjustment for voltage and/or power factor. In addition, bills for service willinclude adjustments, as specified in Parts B and C of the Preliminary

,g Statement, as follows:

per kwhr Energy Cost Adjustment 8.01722 Tax Change Adjustment

(.00071)

Total 8.01651 SPECIAL CONDITIONS

1. Contracts: A contract will be required for a period of 10 years when service is first rendered under this schedule and for subsequent periods of one year thereafter, continuing unt!! cancelled by either party by written notice one year in advance of the end of the initial period or any subsequent period, provided, however, that if the customer requests a change at the end of the initial period or any subsequent period from service under this schedule to firm service, three years' written notice must be given.

Such contract will be on a standard form of the Utility regularly filed with the California Public Utilities Commission, in force at the time and applicable to service under this schedule.

2. Sfazimum Demand: The auximum demand in any month will be the average kilowatt delivery of the 30-minute intervalin which such average is greater than in any other 30-minute intervalin the month, but not less than 5,000 kilowatts, except that in any month during which curtallment has occurred, such maximum demand shall be reduced by multiplying same by the fraction which is the number of hours during which no curtailment occurs over the number of hours in the month. Such maximum demand shall be not less than the average load during said month.

3. Power Fector Adjustment: The total charge, except the minimum demand charge, for any month as computed on the above rate obstl be decreased or increased, respectively, by 0.1% for each one percent that the average power factor of customer's load in that month is greater or less than 85%. Such average power factor shall be computed (to the nearest whole percent) from the ratio of lagging kilovolt ampere hours to the kilowatt hours consumed in the month.

4. Of Peak Period: The hours from 10:30 P.M. to 6:30 A.M. and on Sundays and the following holl.

days-New Year's Day, Washington's Birthday, Memorial Day,Indepen.ience Day, Labor Day, Veterans' Day, Thanksgiving Day, and Christmas Day, as said days are specilled in Public Law 90-363 (U.S.C.A.

Section 6103).

(continued)

^

Advice Letter No. 734.E Issued by Date Filed April 13, 1979 l

Decision No.

W, M. Gallavan Effective May 15, 1979 Vice. President-Rates and Valuation Resolution No. E-1836 A-12 0

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l heine Gu aed Electric Company Revised Cal. P.F.C. Shnt No. 6012.E l

San Francisco. California Canceling Revised Cal. PE.C. Sheet No. 5990- E 1

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Schedule %. A.1s INTERRUPTIBLE PRIMARY INDUSTRIAI. POWER (Continued)

5. Certa:Laent: All electric power delivered hereunder shall be subject to curta!! ment s hen in the '

l UUlity's sole judgment its reserve. energy resources or transmission margin or any combination of these is needed to meet the demaads of its regular customers os Srm rates. or in the Utility's judgment there 1

la en actual or threatened need for such reserve or transmission margin. Customer, upon notice from the Utility, shall curtall his use of electric power.escept plant lighting. fire protection load, and other safety aad security load. to the estent requested by and as scheduled by the Utility. Curtailment shall be eff ected by customer (1) Imroediately upon request frose the Ut!!!ty in ca.ses of emergencies not reasonably pre.

dictable by the Utility and (2) in all other lastances on nouce as spectaed in the standard form contract.

Full curtailment shall att escoed 2.190 hours0.0022 days <br />0.0528 hours <br />3.141534e-4 weeks <br />7.2295e-5 months <br /> during any contractual year.

6. laterrupden: All electric power delivered hereunder except plaat lighting. Are protect!cn load. and other safety and security load, shall be subject to automatic interrupdon. The Utility shat! install and maintain a digital under-frequency relay (or relays) with adjustable contacts set to close at the Sched.

uled Trequency and the associated relay feellities ascessary la the sole opinion of the Utility to iriterrupt electric power automatically in the event of a reduction of frequency on the Utility's system to the Scheduled Trequency. lf more than one underfrequancy relay is required then the custorner chall pay the cost of the additional equipment.

In addition to or in lieu of Interruption of electric power at the Scheduled Frequency the t'tllity may require that electric power be interrupted automatically in the event of a reduction in voltage or in the event of such other operating condluons as may appear appropriate to the Utility from time to time After any interruption hereunder. the customer shall not resume use of electric poses except utson notice from the Ut.[11ty.

7. Scheduled Fr pancy: The Scheduled Frequency is 59.;$ herts (with a delay of $ cycles) until revised in accordance herewith.

Before December 1 of each year or more frequently a% changed conditions may require. the Sched.

uled Trequency (tacluding any delay) will be reviewed and changed as appropriate The Utility will Oy thereupon notify the California Pubite Utsitties Comtr.lation and all customera sersed hereunder of g

the revised Scheduled Trequency which shall become ellective on the Srst day of the second mouth immediately followits the date of such revision.

s. Ceaunuaicados: The customer shall provide to the Utility's spee!Sestions and at his sole expecie ex;lushe cocumunication channels to the Utility's Switching Center for the purposes of alertr.ing. tele.

metering. and sistaling If necessary to carry out the provisions of this schedule. the custormer may be required to lastall and malatatt at his sole expense a recording wattmeter. Utility shall base the raght to inspect and test relay facilities communication channel and wattmeter upor. reasonable notice to customer.

9. Capacity Availability: The total amount of capacity available bereunder is !!mited to a suaximum of 300.000 kilowatts of the Utility's reserve and transmissiot margin. The Utility will nottfy the Public Ut:lities Coc;t:ission of the State of California in writing whet the amount of capacity available here-under has been fully contracted for. Customers applying for service hereunder shen the capseity avail.

able has bee: fully contracted for aball be placed on a priority list according to the date of application a.nd shall be served when additional capacity becomes available.

10. Trartsinimien Service Facificies: The Utility wf!! at its expense furnish and install one overbesd span of transmission conductors and attach to the h!st voltage terrcinals of the substation structure to be os ned or leased by the customer. When the L*t!!!ty extends its electric transmission lines to serve the applicant's premises. the appI! cant shall advance to the Ut!!!ty the estImsted installed cost of the extenstor. and thereafter pay a monthl) ownershfp charge of 55 of such cost If such extension or any portion thereof is thereafter used to serve new, separately. metered pertnanent load for shich the Udllty s ould install all or a portion of the estetsloc at its espetse. a propertfonate share of the applicant's adsacce mill be refunded Where such refunds are made.the rnonthl) ownersh!r charge will be adjustel to (G of the unrefunded balance of the advance No refunds will be made in earess of the original advance.

l 1

V. Wee biter No. 512.E Issued by Date Filed Sept. 16, 1975 Deci6nn No. 5002 W. M. G al!n van Ehetive Sept. 21, 1975 Vice.Preshlent-Rates and Yalaation Rmintion No.

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Pacifle Oas and Electric Company Revised Cal. P.U.C. Sheet No. 703t'E San Francisco, Califernia Canceling itevised Cal. P.U.C. Sheet No. 620%

O Schedule No. A.23 GENERAL SERVICE-TIME METERED APPLICABILITY This schedule is applicable to polyphase alternating current service for all customers of record served under former Schedule A 14 on September 20,1975, to new customers thereafter whose maximum demand in any time period is 4.000 kilowatts or greater, and to existing cu.tomers served in accordance with any applicable General Service, Agricultural Power, Refluery, or Standby Service schedule, whose monthly maximum demand is 4,000 kilowatts or greater for 3 consecutive months. Any customer whose aggregate diversified monthly maximum demand at a single service location has fallen below 3,500 kilo-tratta for any 13 consecutive months may, at his option, thereafter elect to continue to receive service under this schedule or elect to be served under any other applicable schedule.

TERRITORY The entire territory served.

RA'ITsS Per Meter Per Month Period A Period B Customer Charge, 8715.00 8715.00 Demand Charge:

On Peak, per kilowatt of Maximum Demand

$ 4.30 33.80 Plus Partial Peak, per kilowatt of Maximum Demand 0.35 0.35 Plus Off Peak, per kilowatt of Maximum Demand -

No Charge No Charge Energy Charge:

On Peak, per kilowatt hour __.

$.01045 8.01045 Plus Partial Peak, per kilowatt hour

.00845

.00345 Plus Off-Peak, per kilowatt hour

.00645

.00645 Adjustments:

The above base rates are subject to possible adjustament for voltage and/or power factor. In addition, bills for service willinclude adjustments, as specified in Parts B and C of the Pre!!minary Statement, as follows:

per Itwhr Energy Cost Adjustment

$.01723 Tax Change Adjustment f.00071)

Total 8.01651 SPECIAL CONDITIONS

1. Time Periods:

Period A is applicable to meter readings from May 1 to September 30,inclustee, for the following hours:

On Peak 13:30 pm to 6:30 pm Monday through Friday, except holldays.

Partial Peak 8:30 am to 13:30 pm Monday through Frfday, except holidays.

6:30 pm to 10:30 p.m.

8:30 am to 10:30 pm Saturday, except holidays.

Off Peak 10:30 pm to 8:30 a.m.

Monday through Saturd ay, exc ept holf days.

l All day Sunday and holidays.

Period B to applicable to meter readings from October 1 to April 30, inclusive, for the following hours:

On Peak 4:30 pm to 8:30 pm Monday through Friday, except holidays.

Partial Peak 8:30 am to 4:30 pm Monday through Friday, except holldays.

8:30 p.m. to 10:30 pm 8:30 am to 10:30 pm Saturday, except holidays.

l Off Peak 10:30 pm to 8:30 am Monday through Saturday, except holidays.

All day Sunday and holidays.

(continued) m Advice Letter No. 734-E Issued by Date Filed Apri1 13,1979 Decision No.

W. M. Gallavan Effective May 15, 1979 j

Vice-President -Rates and Valuation Resolution No. E-1836

.A-14 30k N]J]

4

cx soa no.ase Pacific Gas and E;cetric Company Revised Cal. P.U.C.' Sheet No. 6864-E San Francisco, California Canceling Original Cal. P.U.C. Sheet No. 63J4-E Schedule No. A.23 GENERAL SERVICE-TIME METERED (Continued)

2. Holidays: Tbt holidays specified in this Schedule include: New Year's Day, Washington's Birthday.

Memorial Day. Independence Day. Iabor Day, Veterans' Day, Thanksgiving Day, and Christmas Day.

as said days are spect!1ed in Public Law 90 363 (U.S.C.A. Section 6103).

3. Maximum Demand: The maximum Nand la any month for each time period will be the toaximum average power taken during any 30-minute mterval in the month, but not less than the d! versified resistance welder lead computed in accordance with Ilule No. 2: provided, that in cases where the use of no9rgy is intermittent or subject to violent fluctuations. either a 5. minute or a 15. minute interval may be used.

4. Voltese Adjustmener The above charges are applicsble without adjustment for voltage when (a) deliver > is made at less than 2 ky, or (b) when delivery is made by means of Utility. owned transformers at a distribution voltage other than a standard primary distribution voltage, or (c) when delivery is made at a voltage that requires more than one stage of transformation from transmission voltage. When delivery is made at the standard prunary distribution voltage at 2 ky or abcVe available in the area from the 11tility's distribution line or, where the Utility has elected to supply service at a standard primary distribution voltage from a transmission line, for its operating convenience, from Utility owned transformers on the customer's property, the above charges for any month will be reduced by 15e per kw of maximum on peak demand in the month. When delivery is made at transmission voltage (60 kv and above), the above charges for any month will be reduced by 25e per kw of maximum on peak demand in the month. The Uti!!ty retains the right to change its 11ne voltage at any time, after reasonable advance notice to any customer receiving a discount hereunder and affected by such change, and such customer then has the option to change his system so as to receive service at the new line voltage or to accept service through transformers to be supplied by Utility subject to the voltage adjustznent above.

5. Power Factor: The total charge for any month as computed on the above rates will be decreased or increased, respectively, by 0.1% far each 1% that the average power factor of customer's load in the month was greater orless than 85%, such average power factor to be computed (to the nearest whole per cent) from the ratto of lagging kilovolt ampere hours to kilowatt hours consumed in the month.

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6. Voltage: Service on this schedule will be supplied at the voltages se described in Electric Rule 2.

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7. Facility Charge Where the estimated installed cost of en!y those facilities necessary to provide C#

regular service which are installed after February 7,1977 is in acess of the estimated annual revenue to be derived from service under this schedule (excluding that portion of revenues equal to the product of estimated annual kilowatt. hour usage times the sum of the Fuel Cost Adjustment and the Base Weighted Average Cost of Fuel and Purchased Energy) an additional monthly charge of 1% percent of such excess will be made. If the customer elects to advance such excess cost te the Utility, the additional monthly charge will be 1 percent of such excess cost. Upon discontinuance of the use of such facilities due to termination of service or otherwise, the customer shall pay to the Utility its net cost to install and remove such facilittes. Any customer advance for costs of such facilities shall be applied as a credit tom ard such net installation and removal costs.

8. Contract: Electric service supplied under this schedule shall be in accordance with a contrac; authorized by the Public Utilities Commission of the State of California. Such contract will be regmred for a period of three years when service is first rendered hereunder and for subsequent periods of one year each thereafter, continuing until canceled by either party by written notice one year in advance of the Initial period or any subsequent period. Customers of record on September 20,1975 served under existing contracts for service under former Schedule A 14 will continue to be served under such contracts except tho' following the expiration of the initial ten-year period such contracts will continue in effect for subsequent periods of one year each until canceled by either party by written notice one year in advance of the initial ten-year period or any subsequent one year period.

.bivie L in e L. 6sE Issued by Date Filedsept. 6, 1978

!)ecision No. 8931G W. M. Gallavan Effective sept. 11, 1978 Vice. President-Rates and Valuation Resolution No.

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o. ue Pacifle Ons and Electric Comp ny Revised Ca!. P.1*.C. Sheet No. 6746-E San Francis ~a, California Canceling Relised Cal. P.U.C. Sheet No. 5765-E m

O Sdedule No. A-41 GENERAL POWE2 SERVIG APPLICAaIUTY This schedule is applicable to single phase or polyphase alternating current service, or to a combi-nation therect THERTTORY Within the Shasta Dam Rate Area.

RATES A-Connected Lead Be Wor installations with a connected load of 40 hp or less and demands not exceeding 20 kw:

Per Meser-Energy Gorges Per Month First 200 kwhr, per kwhr 4.70c Next 400 kwhr, per kwhr 3.12 Next 1400 Whr. per kwhr 1.57 Next 10,000 kwhr, per kwhr 1.41 All ereses kwhr. per kwhr 1.09 Minimeen Charge:

$0.60 per horsepower of connected power load or $1.20 per kilowatt of demand at the customer's option but not less than 35.00 for stagle-phase service or 87.50 for three-phase service. Heating and cooking load will be converted at the rate of 750 watts per horsepower.

^

B-Demand Basie-for installations with a connected load of 40 hp or more and with htlling demands exceeding 20 kw:

Per Meeer Energy Cheeses Per Meech First 50 kwhr per kw of billing demand, per kwbr 3.12e Next 100 kwhr per kw of billing demand, per kwhr 1.25 All ezeese hrhr, ter kwhr

_ G.94 Misdanums Charge, per sneenho

$14.00 but not less than $1.20 per kw of billing demand.

(esattamed) i l

1 R

j Advice Letter No. 659.E Issued by Date Filed _ March 31, 1978 Decien No.

J. F. Roberts, Jr.

Effective May 16, 1978 Vice. President-Rates and Valuation Resolution No.

E-1767 A-16

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Pacife Gas and Electric Company Revised Cal. P.U.C. Sheet No. 4725.E San Francisco. California Canceling Original Cal. P.U.C. Sheet No. 2840.E v

v Schedule No. A 41 GENERAL POWER SERVICE (Continued)

SPECIAL CONDITIONS

)

1. Manimum Demand: The maximum demand in any month will be the maximum average power taken during any 30-minute interval in the month; provided, that in cases where the use of energy is latermit.

tent or subject to violent !!uctuations, a 15-minute interval may be used. A thermal type of demand meter which does not reset after a deSnite time interval may be used.

2. Billing D=====A: The billing demand to be used la computing charges under Rate B will be the higher of ta) the maximum demand as determined under Special Condition 1 for the current month or (b) 75% of the highest such demand occurring in the year ending with the current month, but not less than 20 kw.

3. 01F. peak Demand: Any customer whose billing demand has exceeded 400 kw for 3 consecutive months and thereafter until it has fallen below 300 kw for 12 consecutive months may, upon request.

and under a contract for service for a period of 5 years, have demands ignored which occur between 10:30 P.M. and 6:30 A.M. of the following day and on Sundays and the following holidays: New Year's Day, Washicgton's Birthday. Memorial Day. Independence Day, Labor Day Veterans' Day, Thanksgiving Day, and Christmas Day, as such days are specined in Public Law B363 (U.S.C.A. Section 6103).

4. Voltage: Service on this schedule will be supplied at the secondary voltage available cr. at the optien of the customer, at the primary voltage available. Where secondary voltage is desired and polyphase power is to be combined istth single-phase, a 4 wire service w!!! be supplied in accordance with Section D of Rule i

No. 2; provided. however, that where a customer has made application for such a 4 wire service but the Utility is not in position to supply the same at that location economically then, temporarily until the Utility is ready, such single phase and polypbase service w!Il be supplied and metered separately, the meter readings being combined for the purpose of computing charges on this schedule.

5. Primary Vohage Dioceent: When delivery hereunder is made at the same voltage as that of the line from which the service is supplied, a discount of 5% for 11 kv or higher available line voltages and 3% for available line voltages of from 2 kv to 10kT will be allowed, provided, however, the Ut111ty is nat required to supply servlee at a particular line voltage where it has (or will install) ample facilities for y

supplying at another voltage equally or better suited to the customer's electrical requirements. The Utility retains the right to change its line voltage at any time. after reasonable advance notice to any custemer s

receiving a discount hereunder and afected by such change, and such customer then has the option to change his system so as to receive service at the new line voltage or to accept service (without voltage discount) through transformers to be supplied by Utility.

6. Powee Factor: When the billing demand has eseeeded 400 kw for three consecutive months and, thereafter until it has fallen below 300 kw for twelve consecutive months, bills will be adjusted for weighted monthly average power factor as follows:

The total charge (except the minimum charge) for any month as computed on the above rates will be decreased or increased, respectively, by 0.1% for each 1% that the average power factor of customer's load in that month was greater or less than 85%. such nyerage power factor to be computed (to the nearest whole per cent) from the ratto of lagging kilovolt ampere hours to k!!owatt hours consumed in the month, provided however.that no power factor correction t.C be made for any month when customer's maximum demand was less than 10% of the highest such demand in the preceding eleven months.

1 9

s s tlvice Letter No. 350.E Issued by Date Filed February 9.1971 Decision No. 7515G J. F. Roberts. Jr.

Ntive February 13.1971 Vice. President-Rates and Valuation Resolution No.

D]

A-17

C24204 Dec. 600 Paciac Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7039-E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 7W6-N Schedule No. OL-1 OUI' DOOR AREA LIGHTING SERVICE APPLICABILITY Applicable to outdoor ares lighting service for the illumination of areas where street and highway lighting schedules are not applicable and where the Utility installs, owns. operates and maintains the complete Ifghting installation on Utility's existing wood distribution poles or on customer-owned poles acceptable to the Utility installed by the customer on his private property.

TERRITORY The entire territory served.

RATES Per Lamp Per Month Mercury Vapor Lamps

• Lamp Watts 175 33.923 400 11.045 Hish Premure Sodium Vapor Lampo Lamp Watts 70 36.228 100 6.943 l

200 8.902 Adjustmes:::

The above rates include adjustments, as specified in Parts B and C of the Preliminary State-ment. as follows:

Per kwhr m

Energy Coat Adjustmen'

$.01722 Tax Change Adjustment

(.00071)

Total 8.01651 SPECIAL CONDITIONS

1. Type of Services Service will normally be supplied to individually-controlled lamps from the Utility's extsting 120/240 volt (120/208 volt star in certain localities) single phase overhead or under.

ground distribution circuits. Service from 480 volt sources will be made available only when this type of service is deemed to be practical from the Utility's angineering standpoint and the applicant pays the additional initial cost of a 480 volt supply.

2. Operating Schedules Lighting service w!!! be supplied from dusk to dawn on an operating schedule of approximately 4.100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br /> per year.

3. Lighting Facihties: The Utility will provide and maintain, at its expense, a standard luminaire.

automatic control and a standard 30-inch support arm. A longer support arm will be installed upon request provided the applicant pays to the Utility a nonrefundable amount equal to the estimated addf-tional Installed cost over that of a standard support arm. Outdoor area lighting facilities will only be installed where the Utility has. or intends to install, a wood distribution pole for the purpose of sup-porting other distribution fact!!tles. or where a customer 4wned pole acceptable to the Utility has been installed by the customer on his private property. The Ut!!!ty shall not be required to install luminaires at locatlone where in its judgment. the service may be objectionable to others.

' Closed for new installations as of June 8,1978.

(contissed) m Advice Letter No. 734.E Issued by Date Filed April 13, 1979 Decision No.

W. M. Gallavan Effective May 15. 1979 Vice-President-Rates and Valuation Resolution No. E-1836 A-18

]

a

es.eeee no. ees Pacific Gas and Electrie Company Revised Cal. P.U.C. Sheet No. 7040.E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 6982-E m

M) v hiule No.D 1 DOMESTIC SERVICE APPUCABH. TTY This schedule is applicable to domestic lighting, heating, cooking and single-phase domestic power service in single family dwellings and in Sats and apartments separately metered by the Utility; to single-phase service used in common for residential purposes by tenants in multi-family dwellings; and to all single-phase farm service on the promises operated by the person whose residence is supplied through the same meter.

TERATTORY The entire territory served exceptin the Shasta Dam Rate Area.

RATES Per Meter Per Month Base Adjust.

Efective Rates ments Rates Customer Charge

$1.75 51.75 Energy Charge (in addition to the Customer Charge):

Lifeline kwbr, per kwhr

.01604 8.01003

.02607 Excess kwbr. per kwbr

.02139

.01651

.03790 Adjustments:

The effective rates include adjustments, as specified in Parts B and C of the Preliminary State-ment as follows:

5 Per Kwbr Lifeline Non. Lifeline Energy Cost Adjustment 5.01003

$.01722 Tax Change Adjustment

(.00071)

Total 3.01003

$.01651 SPEC d. CONDTTIONS

1. Annual Contract: For customers who use service for only part of the year this schedule is appli.

cable only on an annual contract.

1. (

2. Lifeline Rates: Lifeline rates are applicable only to separately metered residential usage. The Utility may require the customer to complete and file with it an appropriate Declaration of E11gibt!!ty for Lifeline Rates.

3. Lifeline Uses : The following quantitles of electricity are to be billed at the rates for lifeline usage:

Monthly Kwbr Allowance End Use for Cimetic Band?

Code W

X Y

Z Basic Allowance" B

240 240 240 240 Basic plus Water Heating W

490 490 490 490 Basic plus Space Heating Sunimer H

240 240 240 210 Winter H

790 1,040 1,360 1,660 Basic plus Space and Water Heating Summer C

490 490 490 490 Winter C

1,040 1,290 1.610 1.910 Non-lifeline N

0 0

0 0

Air Conditioning Allowance -additive to above summer allowances:

Territory A 230 2SO Territory B 230 Energy used in excess of the lifeline allowances will be billed at the non-lifeline rates, continuing from the quantity reached by the lifeline allowance.

~

• Climatic Bands are described in the Preliminary Statement.

" Includes !!ghting, cooking and refrigeration.

(continued) s Advice Letter No. 734.E, Issued by Date Filed Apri1 13,1979 Decision No.

W. M. Gallavan Effective May 15, 1979 Vice. President-Rates and Valuation Resolution No. E-1836 A-19 pnWY 3 h\\

0

es-esee

..es Pacine Gee and Electrie Company Revised Cal. P.l!.C. Sheet No 052.E San Francisco, California runecting Reviel Cal. P.F.U. Sheet No. 6794.E m

Scliedule No. D 1 DOMESTIC SERVICE (Continued)

4. !)fe Seappove Devices: A residential customer. who certfoes in writing that regular uw of a medical Ilfs-support device, as de6ned in Rule No.1. la essential to maintain the life of a f'all-time resident of the household, is eligible for a uniform monthly lifeline allowance in addition to those allowances shown in Special Condition 3. The amount of the additional allowance will be determined by the Utility from load and operating time data. The Utility may require certiacation by a doctor or osteopath Ilcensed to practice medicine in the State of California that a particular device is necessary to sustain the user's life-

5. Seesenal Race r%.ga's Bills for service which include lifeline allowances for space heating and air conditioning will be prorated in the May and November bt!!!ag periods based on the ratto of the number of days prior to May 1 and subsequent to October 31. respectively. to the total number or days in tha billing period.

A O

m Advice Letter No. 711.E haued by DateFiled December 6, 19/.

Decision No.

W. M. Gallavan Efective_ January 5,37 Vice President-Rates and Valnation Resolution No.

)

[

d ll b

u.u u

e. m Pacific las and Electric Company Revised Cal. P.U.C. Sheet No. 6953.E San Francisco, California Canceling Revtsed Cal. P.U.C. Sheet No. 6802-E (m)

V" Schedule No. D.40 DOMESTIC SERVICE APPLICABff.ITY This schedule is applicable to domestic lighting. heating. cooking and single phase domestic power servlee in single-family dwellings and in Sats and apartments separately metered by the Utility; to single-phase service used in common for reeldential purposes by tenants in multi-family dwellings: and to all single phase farm service on the premises operated by the person whose residence is supplied through the same meter.

TERRITORY Within the Shasta Dam Rate Area. (X)

The letter in parenthesas after each Rate Area indicates the Climatic Band applicable in Special Condition 3.

RATES Per Meeee Pee Month Ufeline Non-Lifeline Energy Cherse:

Rates Rates First 30 kwbr. per kwhr 30.0539 30.0539 Next 100 kwbr. per kwbr 0.0385 0.0385 Next 100 kwbr. per kwbr -

0.0285 0.0285 Next 720 kwbr, per kwbr 0.0185 0.0185 All excess kwbr per kwbr -

0.0169 0.0169 Minianum Garse:

$1.00 per meter per month.

SPECIAL CONDfTIONS

1. Annual Contrecs: For customers who use service for only part of the year this schedule is appli-C. %

cable only on an annual contract.

2. Ufeline Ra r: Lifeline rates are applicable only to separately metered residential usage. The Utility may require the customer to complete and fLle with it an appropriate Declaration of Eligibility for Lifellne Rates.

J. Lifeline Usese The following quantitles of electricity are to be b!Iled at the rates for lifeline usage:

Monthly Kwbr Allowance End Use foe Gestic Bend

• Code X

Basic Allowance" B

240 Basic plus Water Heating W

490 Basic plus Space Heating Summer (May 1 to Oct.31)

H 240 Winter (Nov. I to April 20)

H 1.040 Basic plus Space and Water Heating Summer (May 1 to Oct. 31)

C 490 Winter (Nov. I to Apdl 30)

C 1.290 Non lifeline N

O Energy used in excess of the lifellan allowances will be billed at the non-lifeline rttes, continuing from the quantity reached by the lifeline allowance.

• Climatic Bands are described in the Preliminary Statement.

• • locludes !!ghting. cooking and refrigeration.

4. Life-Su rately metere[ port Dwices: A reside.stial customer, who certiSes in writing that he resides in a sepa.

l or submetered single family dwelling unit and that regular use of a medical life-support device, as denned in Rule No.1. Is essential to maintain the life of a full-time resident of the house.

hold.14 eligible for a uniform monthly lifeline allowance in addition to those allowances shown in Special Condition 3. The amount of the additional a!!owance will be determined by the Utility from load and operating time data. The Utility may require certiScation by a doctor or osteopath licensed to practice medicine in the State of California that a particular device is necessary to sustatn the user's life.

5. Seasonal Rate Change.: Bills for service which include Ilfeline allowances for space heating and air conditioning will be prorated in the May and November billing periods based on the ratio of the number of days prior to May 1 and subsequent to October 31, respectively, to the total number of days in the billing period.

Advice Letter No. 711.E Issued by Date Filed December 6, 1978 r.ecision No.

W. M. Gallavan Effective January 5,-1979 Vice-President-Rates and Valuation. Aesolution No.

r-

,~

ca.cs..

PacW Gas and Electric Comp:ny Revised Cal. P.II.C. Sheet No. 4739.E, San Francisco. Californin Canceling Revised Cal. P.U.C. Sheet No. 2097.E

^

O Schedule DE SERVICE TO COMPANY EMPLOYEES APPLICABILITY Electricity for domestic purposes under this schedule is available, upon application, to reg a.

lar and pensinned employees of the Iftility, provided they reside in their own home (single family dwelling. separately metered flat or apartment) and are supplied directly by the litility.

This rate applies to employees living with and constituting the support of a mother, father or other relatives.

The service must be billed to and paid by the employee.

A regular employee is defined for the purpose of this schedule, as one who has been con.

tinuously employed by the Utility for more than six months and is paid on a weekly or monthly basis.

This schedule is not applicable to probationary, casual or temporary employees.

TERRITORY The entire territory served.

RATE The regular filed domestic service seaadule applicable in the territory where service is supplied, lew 2*>% discount.

m Advice Letter No. 380.E Issued by Date Filed February 9.1971 Decision No. 78186 J. F. Roberts, Jr.

Effective February 13.1971 Vice. President -Rstes and Valuation Resolution No.

d,A-22 id m

61' '

i cs-(so4 eso.117 Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7041.E p

San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 6998-E

='

i Schedule No. DM MULTI.PAMILY SERVICE APPLICABII.ITY j

This schedule is applicable to service for domestic lighting, heating, cooking, and single-phase power service supplied to multifamliy accommodations through one meter on a single premises in accordance with Rule No.18. Closed to new installations.

'IllRRITORY The entire territory served.

RA'!1[S The rate of the sir:te family domestic service schedule, applicable in the territory in which the multi-family accomw 4 tion is located, mod 18ed as follows:

Customer Charge No change Energy Charp. (in addition to the Customer Charge):

The kilo *att hours for all blocks shall be multiplied by the number jf residential dwelling units and/'. mobile home spaces wired for service.

Adjustme,.s:

Adj' atments, as spec!Aed in Parts B and C of the Preliminary Statement, will be added to each bill for service calculated at the above rates, including bills for minimum charges. Adjustment amour s are as follows:

PerKwhr Lifeline Non. Lifeline Energy Cost Adjustmen'

$.01003

$.01722 Tax Change Adjustment

(.00071)

Total 5.01003

$.01651

%s SPECIAL CONDITIONS

1. Mahiplier: In cetermination of the multiplier it is the responsibility of the customer to advise the Utility within 15 days following any change in the number of residential dwelling units and mobile homes wired for service.

2. Miscellaneous loads: Miscellaneous electrical loads such as general lighting, laundry rooms. gen-eral maintenance, and other similar usage incidental to the operation of the premises as a multi-family accommodation will be considered as domestio usage.

3. Non-enidential Enersy: Electric energy fornon-domestic enterprises such as rooming houses, board-ing houses, dormitories, rest homes, military barracks, stores, restaurants, service stations and similar establishments will be separately metered and billed under the applicable general service schedules.

4. Annual Contract: For customers who use service for only part of the year, this schedule is appli.

cable only on an annual contract.

5. Lifeline Rates: Lifeline rates are applicable only to residential usage billed under a schedule appil-cable to service for domestic uses. The Utility may require the customer to complete and Sie with it an appropriate Declar.ation of E!!gibility for Lifeline Rates.

i (continued) w (m

~ ' ')

.\\dvice Leter No. 734-E issued by Date Filed April 13, 1979 Decision No.

V. M. Gallavan Effective Ma_y 15, 1979 Vice-Pres'Jent-Rates and Valuation Resolution No. E-1836 i

1 d

a\\

....eee

.. 3 Paci$c Gas and Electric Company Revised Cd. P.U.C. Sheet No. 6955.E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 6868.E n

Schedule No. DM MULTI. FAMILY SERVICE (fa"*3=ined)

SPECfAL CONDfTIONS (f'.=d-M

6. LifeEne Usese: The following quantitles of electricity are to be billed at the rates for lifeline usage:

Meeshly Kwhc Allowance

• End Une for Casneene Beads **

Code W

X Y

Z Per Residensiel Unie Basic Allowance

• B 190 190 190 190 Basic plus Water Heating W

390 390 390 390 Basic plus Space Heating Summer (May I to Oct. 31)

H 190 190 190 190 Winter (Nov.1 to April 30)

H 520 670 865 1.040 Basic plus Space and Water Heating Summer (May 1 to Oct. 31)

C 390 390 390 390 Winter (Nov.1 to April 30)

C 720 870 1.065 1.340 Non-lifeline N

0 0

0 0

l Air Conditioning Allowance - additive to above allowances May 1 to October 31. Inclusive:

Territory A 170 170 Territory B 140 Enarry used in excess of the !!fellne allowances will be billed at the non-lifeline rates, continuing from the quantity reached by the lifeltne allowances.

'Any subm6tered unit will receive the allowance for individually metered units as shown on Schedule No. DS.

• • Climatic Bands are described in the Preliminary Statement.

• • • Includes lighting, cooking and refrigeration.

7. IJfe Support Devices: A reeldential user of electric service in a multi-family accommodation, who cert!Aes in witting that regular use of a medicallife support device, as de8ned in Rule No.1. is essential to maintain the 11fe of a full-time resident of a reeldential unit. Is eligible for a uniform monthly lifeline allowance in addition to those allowances shown in Special Condition 6. The amount of the additional allowance will be determined by the Utility from load and operating time data. The Utility may require cert!Acation by a doctor or osteopath licensed to practice medicine in the State of California that a particular device is necessary to sustain the user's life.

s. b aa.I Rene Onsages: B11:e for service which include 11 feline allowances for space heating and air conditioning will be prorated in the May and November billing periods based on the ratio of the number 1

of days prior to May 1 and subeequent to October 31, respectively. to the total number of days in the i

billing pertod.

)

9. Three Phees Service: Three phase load will be supplien service under thfe schedule for multa.

family residential customers who were supplied three phase service on a general service schedule on August 37,1976.

l i

n O,1 Advice Letter No. 711.E Issued by Date Filed December 6,1978 Decision No.

W.M. Gallavan Effective Januarv 5, 1979 Vice. President-Rates and Valuation Resolution No.

i

)

A-24 l

Q

i l

c a <so4 seo. ses Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7042-E San Francisco, California Canceling Itevised Cal. P.U.C. Sheet No. 6999-E Schedule No. DS MULTI. FAMILY SERVICE

_ APP!JCABILITY This schedule le applicable to service for domestic lighting, heating, cooking, and single-phase power service supplied to multi-famliy accommodations in other than a mobilehome park through one meter on a single premises and submetered to all individual tenants in accordance with Rule No.18.

TERRITORY The entire territory served.

RATES The rate of the single family domestic service schedule, applicable in the territory in which the multi. family accommodations is located, less 10% discount on the energy rates applicable to lifeline usage.

Customer Charges No change.

Energy Qiarge (in addition to the Customer Charge):

The kilowatt hours for all blocks shall be multiplied by the number of residential dwelling units wired for service.

Adjustments:

Adjustments, as specified in Parts B and C of the Pr*

nary Statement, will be addel to each bill for service calculated at the above rates, includin

.Is for minimum charges. Adjustment amounts are as follows:

Per Kwbr Lifeline Non-Lifeline Energy Cost Adjustmen' 8.01003

$.01722 Tax Change Adjustment

(.00071)

Total 5.01003

$.01651 SPECIAL CONDITIONS

1. Multiplier: In determination of the multiplier it is the responsibility of the customer to advise the Utility within 15 days following any change in the number of residential dwelling units wired for service.

2. Misce!!aneous Loads: Miscellaneous electrical loads such as general lighting, laundry rooms. gen.

eral maintenance, and other similar usage incider'al to the operation of the premises as a multi-family accommodation will be considered as domestic usage.

3. Non.residencia. Energy: Electric energy fornon<!omestic enterprises such as rooming houses, board-ing houses, dormitories, rest homes, military barracks, stores, restaurants, service stations and similar establishments will be separately metered and billed under the applicable general service schedules.

4. Annual Contract: For customers who use service for orJy part of the year, th's schedule is appil-cable only on an annual contract.

S. Lifeline Rates: Lifeline rates are applicable only to residential usages billed under a schedule appli-cable to service for P stic uses. The Utility may require the customer to complete and file with it an appropriate %ciaration of Eligibility for Lifeline Rates.

(continued) s Advice Letter No. 734-E Issued by Date FiledApril 13, 1979 Decision No.

W. M. Gallavan Effective May 15,19/9

~~

Vice-President-Rates and Valuation Resolution No. E-1836 t

-. m

es uu

. i..

Pacific G:s and Electric Company Revised Cal. P.U.C. Sheet No. 6957 E San Fr:ncisco. California Canceling Revised Cal. P.U.C. Sheet No. 6870.E m

Niule No. DS MULTI. FAMILY SERVICE (Consiemed)

SPECIAL CONDITIONS (Continued):

6. Lifeline Usese The following quantiues of electricity are to be billed at the rates for lifeline usage:

Meathly Kwbr Allowas:e End Une ier Gianeric Bends

• Code W

X Y

Z Per Raeidentiel Unie Basic Allowance" B

$40 240 240 240 Basic plus Water Heating W

490 490 490 490 Basic plus Space Heating Summer (May 1 to Oct. 31)

H 240 240 240 240 Winter (Nov.1 to April 30)

H 790 1.040 1.360 1.660 Basic plus Space and Water Heating Summer (May 1 to Oct. 31)

C 490 490 490 490 Winter (Nov. i to April 30)

C 1.040 1.2H 1.610 1.910 Non-lifeline N,

0 0

0 0

Air Conditioning Allowance-additive to above allowances May 1 to October 31, inclusive:

Territory A 280 280 Territory B 230 Energy usw! in excess of the lifeline allowances will be billed at the non-lifeline rates, continuing from the quantity reached by the lifeline allowances.

• Climatic Bands are described in the Preliminary Statement.

" Includes lighting, c,ooking and refrigeration.

7. life.Su port Devices: A residential ussr of electric service te a multi-faamily accommodation, who

^

certiftee in wrfting that regular use of a moda at life support device. as de8aed in Rule No.1. is essential to maintain the life of a full-time resident of a residential unit. is eligible for a uniforin monthly lifeline allowance in addition to those allowances sM.vn in Special Condition 6. The amount of the additional allowance will be determined by the Utility from load and operating time data. The Utility nasy require certtScation by a doctor or osteopstt ticonsed to practice medicine in the State of California that a particular device is necessary to suw the user's life.

8. Seesenal Rete Cheases: Bills for se/vice which include lifellae allowances for space heating and air conditioning will be prorated in the May and November billing periods based on the ratto of the number of days prior to May 1 and subsequent to October 31. respectively, to the total number of days in the billing period.

9. Three Phase Service: Three phaae load will be supplied service under this schedule for an!LI-family reefdential customers who were supplied three phase service on a general service schedule on August 27,1976.

Advice Letter No. 711.E Issued by Date Filed December 6,1978 e

{

Decision No.

W. M. 0allavan Efective January 5, 1979 Vice-President-Rates and Valuation Resolution No.

A-26 o

a e MI w

es.eso4 No. ias Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7043-E San Francisco, California Canceling original Cal. P.U.C. Sheet No. 7000-E y'w Schedule No.DT MULTI. FAMILY SERVICE - MOBILEHOME PARK APPLICABILITY This schedule is applicable to service for domestic lighting, heating, cooking and single-phase power service supplied to multifamily accommodations in a mobilehome park through one meter on a single premises and submetered to all individual tenants in accordance with Rule No.18.

TERRITORY The entire territory served.

RATES The rate of the single family domestic service schedule, applicable in the territory in which the multi-family accommodation is located,less 30% discount on the energy rates applicable to lifeline usage.

Customer Charges No change.

Energy Charge (in addition to the Cumoner Quarge):

The kilowatt hours for all blocks shall be multiplied by the number of mobilehome spaces wired for service.

Adjustments:

Adjustments. as specified in Parts B and C of the Preliminary Statement, will be added to each bill for service calculated at the above rates. Including bills for minimum charges. Adjustment amounts are as follows:

Per Kwhr Lifeline Non-Lifeline Energy Cost Adjustment 8.01003 8.01722 Tax Change Adjustment

(.00071) h Total :

8.01003 8.01651 g^

7 SPLCIAL CONDITIONS

1. Multiplier: In determination of the multiplier it is the responsibility of the customer to advise the Utility within 15 days following any change in the number of mobile homes wired for service.

2. Miscellaneous Loads: Miscellaneous electricalloads such as general lighting, laundry rooms, gener-al maintenance, and other similar usage incidental to the operation of the premises as a multi-family i

accommodation will be coristdered as domestic usage.

1

3. Non.residentia! Energy: Electric energy for non-domestic enterprises such as rooming houses, j

boarding houses, dormitortes. rest homes. military barracks, stores, restaurants, service stations and similar establishments will be separately metered and billed under the applicable general service schedules.

4. Annual Contract: For customers who use service for only part of the year, this schedule is applicable only on an annual contract.

5. Lifeline Rates: Lifeline rates are applicable only to residential usages billed under a schedule applicable to service for domestic uses. The Utility may require the customer to complete and file with it an appropriate Declaration of Eligtbility for Lifeline Rates.

(X)

(continued) fv Advice Letter No. 734-E Issued by Date FiledApril 13.197L Decision No.

W. M. Gallavan Effective May 15, 1979 Vice.Presiden:-Rates and Valuation Resolution No. E-1836 D

i D{

D

}

A-27

es..a

o. s Pacifle Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7044-E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 6M ^

O Schedule No. LS.1 STREET /.ND HIGHWAY LIGHTING APPLICABILITY This schedule is applicable to Utilityewned and maintained lighting installations which illuminate streets, highways, and other public-dedicated outdoor ways and places and which generally utilize the Utility's distribution facilities. Rates of Class A through Class F service will be applicable as determined in Special Condition 4.

TERRITORY The entire territory served.

RATES All Nisht Rates Per Lamp Per Month Half Hour Case A

B C

D E

F Adjustment Nominal Lamp Rating Incandescent Lamps

• Watts Lumens 58 600

$ 3.208 3.045 92 1.000 3.673

.071 189 2.500 5.794 8 4.789

.144 295 4,000 7.366 6.360

.226 405 6.000 9.007 7.999

.310 620 10,000 12.536 11.558

.475 Mercury Vapor Lampe*

Average Immy Line Initial Watts Watts Lumens 100 124 3.500

$ 5.343

$ 4.627 8 3.723

$ 8.748 8 8.275 8 6.660 5.080 175 198 7,500 6.229 5.528 4.870 9.415 9.199 7.574

.1*7 250 285 11,000 7.521 6.794 6.145 11.676 10.553 9.460

.182 400 451 21,000 10.254 9.360 8.542 13.482 11.965

.291

^

700 766 37,000 16.447 14.549 19.437 19.062

.493 1,000 1,088 57,000 21.103 19.093 24.402 23.673

.699 Hish Pressure Sodium Vapor Lamps Averese Lamp Line Initial Watts Watts Lumens 70 85 5,800

$ 6.163

$ 5.424* $ 4.538 8 8.970

$ 8.724 3 7.148 8.047 100 121 9.500 6.879 6.135' 4.890 9.440 9.243 7.864

.068 150 176 16,000 7.600 6.862*

6.749 10.112 10.161 8.585

.099 200 263 22,000 8.856 8.117' 6.985 11.516 11.072

.149 250 321 25.500 9.742 9.003*

7.920 12.451 12.007

.382 400 487 46,000 12.054 11.315*

10.182 14.713 14.270

.275 More than one light on a po*e:

Where more than one light is installed on a pole, all lights other than the first will be billed on the Class C rats.Not applicable to installations made prior to September 11,1978.

Adjustments:

The above rates include adjustments, as specified in Parts B and C of the Preliminary State-ment as follows:

An Energy Cost Adjustment of a positive 8.01722 per kilowatthour and a Tax Charge Adjust.

ment of a negative 1.55e applied to base rates.

Pole Charge:

For Class A and B pole installations using other than wood poles that were installed entirely at Utility expense, customer will pay a monthly pole charge of $3.15; or $2.60 for installations made prior to September 21.1575 (closed to new installations).

For Class A and B pole installations using other than wood poles where the customer elected to pay a nontefundable amount equal to the estimated additional cost of installation over that of a basic installation, the customer will pay a monthly pole charge of $1.35; or 80.00 for installations made prior to September 21 1975. (Closed to new installations.)

• Closed to new installations as of June 8,1978, except where Utility and customer shall agree, mercury vapor lamps may be installed under C!ssa A and C to provide compatibility with existing light sources.

(continued)

Advice Letter No. 734-E Issued by Date Filed April 13, 1979 Decision No.

W. M. Gallavan Effective May 15, 19/9 Vice-President-Rates and Valuation Resolution No. E-1836 J

ru

es.e.

o. eer Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 6872-E o

San Francisco, California Canceling Revised Cal. P.U.C. Sheet No 6752-E Schedule No. LS.1 ST1tEET AND HIGHWAY LIGH11NG (Conti e d) sesaAI, CONDmONS

3. Type of Service: The Utility reserves the right to supply either " multiple" or ** series" service.

Series service to new lights will only be made where it is practical from the Utility's engineering stande point to supply them from existing series systems.

2. Annual Opereeing 4Wules The above rates for All' Tight service assume an average of approx!-

mately 11 hours1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br /> operation per night and apply to lamps which will be turned on and off once each night in accordsace with a regular operating schedule agreeable to the customer but not exceeding 4.100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br /> per year.

3. Operennes LWales Odier Then All-Nishan Rates for regular operating schedules other than full All-Night will be the All. Night ste plus or minus, respectively. the half-hour adjustment fer each half-hour more or less than an average of approximately 11 hours1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br /> per night. This adjustment will apply only to lamps on regular operating schedules of not less than 1.095 hours0.0011 days <br />0.0264 hours <br />1.570767e-4 weeks <br />3.61475e-5 months <br /> per year, or 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> per night. nor more than 4.600 hours0.00694 days <br />0.167 hours <br />9.920635e-4 weeks <br />2.283e-4 months <br /> per year.

4. Description of Service Provided:

GassA Utility owns and maintains luminaire, control facilities, support arm, and service wiring on its existing distribution pole. and all lights formerly served under Schedule LS-1. Class A.

as of September 11.1978.

Cass B Utility owns and maintains luminaire, control facilities, support arm, pole or post, founda.

tion and service connection and where customer has paid the estimated installed cost of the luminaire, support arm and control facilities (applicable only to installations in service as of September 11,1978.

Cass C Utility owns and maintains its standard luminaire. control facility, overhead service and internal support arm wiring as required (ownership of pole or post. support arm and foundation by customer). Available only where customer 4wned poles comply with the

[^)

Utility's engineering and operating requirements.

V C ass D Utility owns and maintains its standard post top luminaire, control facility. Internal post wiring, standard galvanised steel post (20 ft. mounting height or less) and foundation where customer pays for the estimated installed cost of the post, support arm (if any) and founda-tion.

Cass E Utility owns and maintains its standard luminaire, control facility, internal pole wiring, service connection, galianized steel pole and foundation where the customer has paid to the Utility the estimated installed cost of the pole, support arm and foundation.

Qass F Utility owns and maintains a standard luminaire, control facility. support arm, and service connection on its wood pole or post. Installed solely for the luminaire.

5. Rearrangenwns of Facilities: At the customer's request the Utility will neke changes to or rear.

rangement of existing facilities at the customer's exg.nse.

6. U 4...

--f S.evice: The applicant at his expense shall perform the necessary trenching, backftll and paving, and shall furnish and install all neceqary conduit and substructures including substructures for transformer installations if necessary, for street lights only, in accordance with the Utility's specill-cations. Upon acceptance by the Utility, ownership of the conduit and substructures shall vest in the Utility.

The Utility, at its expense. will furnish and install the underground service conductor to the hand-hole of each street light pole where the length of the servlee is 100 circuit feet or less per luminaire.

as measured from the point of connection to the point of secondary supply. For servico lengths in excess of 100 feet the applicant shall pay to the Utility the material cost of the conductors in excess of 100 circuit feet.

t l

(continued)

D)

\\'N Advice Letter No. 688-E Issued by Date Filed sect. 6, 1978 Decision No. 89316 W. M. Gallavan Effective sept. 11, 1978 l

Vice. President-Rates and Valuation Resolution No.

l A-29 D*90 "7S '%

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Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 6873-E San Francisco, California Canceling Rensed Cal. P.U.C. Sheet No. 6752-E, Schedule No.LS 1 STREET AND HIGHWAY LIGHTING (Continued)

SPECIAL CONDITIONS (Continued)

7. Chmership: All facilities installed under this schedule except for the Class "C" customer-owned pole or pcst, support arm and foundation shall vest in the Utility,

s. Meine==ce: The Utility shall exercise reasonable care and diligence in maintaining Utility-owned facil10es. Maintenance will be performed as an accommodation on a customer-owned Class "C" pole or poet, arm and foundation. at the customer's expense, where customer is unable to obtain the service elsewhere. Where the Ut!!!ty experiences or expe(ts to experience malstenance costs exceeding its normal maintenance expense, resulting from but not limited to vandalism. or unusual non-standard design of pole, post, os luminaire, the Utility may require the customer to pay excess maintenance costs as may be necessary.

9. Special Equipenema Luminaires. polee. poets and other equipment requested by a customer or applicant. in addition to or in substitution for the Utility's standard galvanized steel poles. galvanized steel posts, photocell controls and equipment. will be provided if such equipment meets the Utility's engineering and operating standards and if the custa,mer or applicant pays the cost difference between i

the equipment normally provided by the Utility and the equipment requested by the customer or applicant. plus an additional continuing monthly payment equal to 1% of the cost difference. This pro-vision is also applicable to special optical filters, shields or other special hardware required or requested by the applicant or any governmental agency having Jurisdiction. At the request of the customer or applicant the Utility will install special equipment entirely at the Utility's expense provided the cus-tomer agrees to pay a continuing monthly payment equal to 2% of the cost difference, lo. I.ine Essensiers: Where the Utility determines that it is necessary to extend its electric distribu-tion lines to serve only a street light or a street lighting system, the applicant shall advance, subject to refund in accordance with Electric Rule No.15. the estimated installed cost of such line extension, ex.

closive of service conductors (and transformer if reg:1 ed). under the provisions of Special Condition 9.

The Ut111ty asay waive the foregoing line extension provisions where the extension is estimated to be of nominal cost and where not more than one pole and one span of overhead line is required to reach the Utility designated connection point or in the case of underground fac111ttes. where the first-service de-livery point is no greater thaa 800 feet from the Utility designated connection point. Tb-cost afference m

used in calcukting the continuing monthly payment as specified in Special Condition 9 trill be reduced by an amount equal to any Electric Rule No.15 refund, and the continuing monthly payment shall be ad-justed accordingly.

11. Tassperary th-e-- of Sewies: (nzture rimains in place) At the request of the custome:

the Utility will temporarily discontinue servlee to individual luminafres provided the customer pay, a faellity charge equal to the all-nJght rste, adjusted to 0 burning hours under the pt a risions of Sp*cial Condition 3. plus the eeHma'ad cost to disconnect and reconnect the light.

12. Concrect: Service to each light installation shall be for an initial contract term of 5 years and shall automatically continue thereafter frem year to year. The initial term shall commence wben perma.

nent service is 1:st rendered or within 90 days of when the lights are first ready fe,r service, whichever occurs first.

1 1

Advice Letter No. 688-E Issued by Date Filedsent. 6. 1978,

Decision No. 89316 W. M. Gallavan Effective sect. 11, 1978 Vice-President-Rates and Valuation Resolution No.

(

A-30, D$IOIi) ID F

M M Sjh d b d

1

+.

e e a as Pacido Gas and Electric Company Revised Cal. P.U.C. Sheet No. 6986.E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 6895.E Schedule No. LS.2 SDEET AND HIGHWAY LIGHTING APPLICABILITY This schedule is applicable to service to lighting Installations which illuIntnate streets, htshways, and other publicly <!edicated outdoor ways and places where the customer usually owns the lighting fixtures.

poles and interconnecting circuits. The customer's facilities must be of good construction acceptable to the Utility and in satisfactory condition to quality for Class B or C rates.

, TERRITORY The entire territory served.

RATES Rase pee Lamp per Month Gees A

B C

Utility supplies energy Utility supplies the on. Utility supplies the en.

and switching

• service ergy. switching', and orgy, evitching', and caly.

analatenance service maintenaceo service for for lamps and glass. entire syttem including ware.

lampe and glassware.

A B and C Half Hour All Nisbe All.Nish:

AB.Nishe Adjustmene Nominal Lamp Rating:

Incandescent Lampe Waan Lameas**

92 1.000 8 1.560 8 2.249

( 2.899 8.071 189 2.500 3.168 4.005 4.655

.144 295 4.000* "

4.971 5.858 6.508

.226 405 6.000 "

• 6.824 7.710 8.360 310 620 10.000' "

10.430 1L43$

12.085

.475 860 15.000 " '

14.475 15.598

.660 Low Pressure Sodium Veper I.ampe Ov Averese Lamp Line Initial Werte Werte Leasens**

35 68 4.800

$.862 55 90 8,000 1.114 8.039 90 148 13.500 1.832

.051 135 205 21.500 2.552

.083

.116 180 256 33.000 3.162

.143 Hish Pressure Sedium Veper Lamps 120 Volts 70 85 5.800 8 1.041 8 1.839 8 2.489 8.047 100 121 9.500 1.491 2.338 2.989

.068 150 176 16.000 2.173 3.020 3.670

.099 240 Volts 70 SP 5.800 8 1.221 8 1.802 8 2.453 8.055 100 144 9.500 1.737 2.378 3.028

.082 150 207 16.000 2.562 3.133 3.783

.116 200 263/

22.000 3.270 3.881 4 531

.149 250 321 25.500 3.988 4.599 5.249

.182 400 487 46.000 6.037 6.648 7.:H

.275 Metal Halide Lampe 400 468 30.000 8 5822 8.265 1.000 1,118 90.000 13.871

.632 Mercury Veper Lampe 100 1:4 3.500 8 1.757 8'2.229 8 2.N9 8.080 175 198 7.500 2.779 3.051 3.901

.127 250 285

..000 4.005-4 606 5.256

.192 400 451 21.000 6 374 6.975 7.625

.291 700 766 37.000 10.828 11.951 12.601

.493 1.000 1.088 57.000 15.364 16.555 17.206

.699

• Switching Service is closed to new fastallations.

i

• • 14 test published information should te consulted on best avsflable lumens.

"' Services for locandescent lamps over 2.500 lumens will be closed to new installations after September 11,1978.

(continued) v

.\\.h6.I.cn.r W. M1.E Issued by Date Filed February 2,194 1 b i-!nn L.__""16 W. M. Gallavan Effective rebruary 2, 19 7 Vica. Pre i.1.tt-Rates and Valm. sn Br<olution No.

(

j I

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es-esee

.ca Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7045-E San Franelseo, California Canceling Revised Cal. P.U.C. Sheet No. (M ^ O Schedule No. LS 2 STREET AND HIGHWAY LIGHTING (Continued)

RATT!S (Continued)

Adjustznents:

The above rates loclude adjustments, as specified in Parts B ard C of the Preliminary State-ment as follows:

An Energy Cost Adjustment of a positive 8.01722 per kilowattho1r and a Tax Charge Adjust-ment of a negative 1.6% applied to base rates, SPECIAL CONDITTONS

1. Type of Service: This schedule is applicable to mult!ple !!ghting systems to which the Utility will deliver current at secondary voltage and to series street lighting systems for which the Utility will fur-nish constant current regulating transformers. MultJple current will normally be supplied at 120/240 volt *, single. phase. Unless otuerwise agreed. series current will be delivered at 6.6 amperes. Single-phase service from 480 volt sources and series circuits will be a vallable in certain areas at the option of the Utility when this type of service la practical frou the Utility's engineering standpoint. All currents and voltages stated herein are nominal, reasonable variations being permitted.

New lights will normally be supplied as multiple systems. Series service to new ifghts will be made only when it is practical from the Ut!!!ty's r*neering standpoint to supply them from existing series systems.

'In certain loca11ttes the Utility may supply service from 120/208 volt. star connected. polyphase lines In place of 240 volt service.

2. Annual Operating Sche <fules: The above rates for All Night service assume 11 hours1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br /> operation per nfght and apply to lamps which will be turned on and off once each night in accordance with a regular operating schedule agreeable to the customer but not exceeding 4.100 hours0.00116 days <br />0.0278 hours <br />1.653439e-4 weeks <br />3.805e-5 months <br /> per year.

~. Operacing Schedules Other Tian All-Night: Itates for regular operating schedules other than full 3

m all-ntght will be the All-Night rate plus or minus, respectively, the half-hout adjustment for each half-hour more or less than an average of 11 hours1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br /> per night. This adjustment w!!! apply only to lamps on regular operating schedules o not less than 1.095 hours0.0011 days <br />0.0264 hours <br />1.570767e-4 weeks <br />3.61475e-5 months <br /> per year. or 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> per night, nor more than r

4,500 hours0.00579 days <br />0.139 hours <br />8.267196e-4 weeks <br />1.9025e-4 months <br /> per year.

4. Point of Delivery: Delivery w!!! be made from Utility's existing electric 11nes Ethout extension thereof to customer's system at a point or pointa mutually agreed upon except as provided in Special Condition 9. The Utility will provide at its expense an overhead service drop to a customer owned inter-connected group of lamps having a connected load of not less than 2 kw. For a customerowned inter-connected group of lamps having a connected load of less than 2 kw or individual customer electrollers with a self contained photo cell switch. (1) the Utility will connect the customer's overhead service wire to the Utility's overhead !!nes at the customer's expense, or (2) at the customer's option, the Utt!!ty will install. Own and maintain the overhead service provided the customer pays the initial cost of the service plus 1% per month of such initial cost. When 480 volt service is desired by the customer. energy will be supplied from overhead facilities at 480 volts, single-phase, for an interconnected group of lamps provided the total conneated load of the interconnected group of lamps to be so served is not less than 8 kw. For a customer-owned Interconnected system of less than 8 kw but not less than 2 kw. energy will be supplied at 120/240 volts unless the customer pays the additional cost of a 480 volt supply.

5. (Jaderground Service Connection: The Utility will provide an underground service connection at its expense from either its overhead or underground system to one wectroller of each group of inter-connected electrollers provided (1) the customer has arranged the system for the least practicalnumber of points of delivery. (2) there are not less than 10 electrollers in the group and (3) there is not less than 3 kw connected load. This service connection shall not exceed 25 feet of undergro1nd run from the base of the Utility's pole in an overhead !!ne nor exceed to feet of underground run from a location where service is available in an underground system. The Utility will extend the underground service beyond the free length at the customer's request in accordance with Special Condition 8.

Where the customer requests an underground service to (1) a system of less than 10 electrollers or 3 kw connected load, or (2) an individual electroller. the customer shall install and own the extension from his system ar electroller to the Utility's distribution system when service is readily available and aball pay the cost of connecting to the Utility's distribution system. Including any necessary conduit or riser material.

(continued)

'S Advice Letter No. 734-E Issued by Date Filed April 13, 1979 Decision No.

W. M. Gallavan Effective May 15, 1979 l

Vice-President-Rates and Valuation Resolution No. E-1836

)

b

exsos up.ssa Pacific Gas and Electric Ccmpany Revised Cal, P.U.C. Sheet No. 6876-E g

San Francisco, California Canceling hevued Cal. P.U.C. Sheet No. 6333.E (w)

~

Schedule No. LS.2 STREET AND HIGHWAY LIGHTING (Continued)

6. Swisddag: Where the connected street light load on each circuit separately switched is less than 2 kw for multiple circuits served from overhead lines or less than 10 kw for series circuits served from overhead lines the customer shall pay an extra charge of $3.00 per mt, nth for each circuit sepa-rately switched by the Utility, except where switchlag facilities have been installed by the Utility for its convenience.

7. Maintenance:

(a) The Class B and C rates include all labor and material necessary for the inspection, cleaning, or replacement by the Utility of lamps and glassware, and are limited to certain glassware such as is commonly used and manufactured in reasonably large quantities. A suitable extra charge will be made for maintenance of glassware of a type enta!!!ng unusual expense.

(b) Under the Class C rate the Utility will:

(1) Paint the poles as required to maintain good appearance. Where the customer. owned poles are of a material which does not require paintlng, the Class C rates will be reduced by 80.15 per lamp per month. On multilamp installations where painting is required, the rates will be reduced by 80.15 for a!! lamps other than the Srst one.

(2) Isolate any trouble in the customer's system which has resulted in an outage or dimin-inhed light output.

(3) Make necessary repairs without replacement on accessible wiring between poles and on equipment and wiring in and on poles to keep the system in operating condition. The Utility will provide labor for the replacemect of material such as ballasts, photoelectric controls, relays Sztures, individual poles, individual cable runs between poles where such runs are in condult, and other hdtvidual pe.rts of the system. The customer shall compen-sate the Utility for any material furnished by the Ut!!!ty. The Class C rate does not pro.

vide for any major excavation or any major replace nent at Utility expense of circulta, conduits, poles..ar fixtures owned by the customer.

(c) This schedule does not prdvide for maintenance to low pressure sodlum vapor or metal halide lamps; however, at the request of the customer, the Utility will perform any of the routine maintenance described above on a time and material cost basis provided the Utility's regular standard maintenance a,Iulpment and procedures can be used.

8. Sysemma Own.d in Part by the Utilicy:Where, after the date this provision la first effective, the Utility installs and thereafter owns and maintains any portion of the fixtures, poles, circuits, or other facilities that cornprise customer's street lighting system an additional monthly charge of 2% of the Utility's estimated installed cost of such facilities will be made. If such facilities were installed prior to the date this provision is first effective. the additional monthly charge will be 1%% of such cost'. Customer or others may elect to pay the Utility's estimated installed cost of such facilities, in which event the additional monthly charge will be 1% of such cost.

9. IJae Extensions: Where, after the date this provision is first effective, the Utility extends its elec.

tric lines to serve customer's street lighting system, an additional monthly charge of 2% of the Utility's estimated installed cost of such line extension, exclusive of service connection (and transformer, if required) furnished under Special Conditions 1, 4, and 5 will be made. If such extension was installed prior to the date this provision is Srst effective, the additional monthly charge will be 1% % of such cost'.

If customer elects to advance the Utility's estimated installed cost of such extension, the additional monthly charge will be 1% of such cost. The Ut!!!ty may walve the foregoing provisions where the extension is estimated to be of nominal cost and where not more than one pole and one span of line la required. If such extension, or any portion thereof, is utilised to serve new separately metered permanent load for which an excess free length of line is allowed under Rule No. 35, such cost to be used in eeter-mining the additional monthly charge will thereafter be reduced in proporilon to the relative length of excess free footage allowance for the new load,if any, as compared to the length of the original extension.

If an advance has been made as prorided above, and if under Rule No.15,an excess free footage allowance remains after the new load is installed, all or part of the advance will be refunded without interest to the customer.These refunds will be cornputed by converting the amount of the advance to an amount per foot and multiplying the excess free footage by this unit per foot. Such refunds,if any, will be made following the connection of such new load. If such extension is part of a series of extensions, on any of which an adrance is still refundable, refunds due from new load will be made in turn as provided in Rule No.15. No payment will be made in excess of the original amount advance 1.

10. Screet Lisht Lampe-Scandard and Non-Scandard Ratings: The rates under Classes B and C are applicable to both standard and group replacement street lamps. Standard and group replacement street lamps have reference only to street Istups having wattage and operating life ratings within 3% of those specified in the eel NEMA Standards for Filament i amps Used in Street Lighting. Where Class A service is supplied to lamps of other ratings than those spac: fled in EEI NEMA Standards an adjustment will be made in the lamp rates proportionate to the difference between the wattage of the lamps and the standard lamps of the same lumen rating.

l

• Except for facilities installed prior to February 13,1971, in which case the monthly charge will be 1%%

Advice Letter No. 688-E Issued by Date Filed sent. 6.

1978 Decision No. 99316 W. M. Gallavan Effective gone. 11, 197a Vice. President-Rates and Valuation Resolution No.~

I@U M 3 h O

A-33

[)

bMOU\\ LM

es.caea peo. c s Pacifle Gas and Electric Company Revised Cal. P.I'.C. Sheet W. 7046-E San Francisco, California Canceling Itry ml Cal. P.II.C. Sheet No. twe O

Schedule No. LS.3 STREET AND HIGHWAY LIGHTING ELECTROLIER METER RATE APPLICASHITY Applicable to service to electro 11er lighting systems, excluding incandescent luminaires, which

!!!uminate streets, highways, and other pubikly dedicated outdoor ways and places where the customer usually owns the lighting itztures, poles and interconnecting circuits, and the Utillty furnishes energy at one or more central points.

'ITE RITORY The entire territory served.

RATES Per Metee Per Month Service Charge 8M Energy Cherse (In addition to the servies charge)

First 164 kwbr per kw of billing demand

.0333 Over 150 kwhr per kw of billing demand

.01:0 Switching Omarge*

For each circuit switched 3.25

• Switching Service is closed to new installations.

Adjustments:

Adjustments, s speciasj in Parts B and C of the Preliminary Statement, will be added to each bill for servlee calculated at the above rates, including bills for mtalmum charges. Adjustment amounts are as follows:

s erkwhr m

z Energy Cost Adjustment

^$.01723 Tax Change Adjustment

(.00071)

Total 8.01651 SPECIAL CONDITIONS L Trpe of Sernces This schedule is applicable to multiple Ifghting sys' ems to which the Ut!!!ty will deliver current at secondary voltage and to sortes street lighting systems for which the Utility will fur.

nish constant current regulating transformers. Multiple current will normally be supplied at 120/240 volts',

single phase. Unless otherwise eveed, sortes current will be delivered at 6.8 amperee. Single-phase service from 480 volt sources will be available In certain areas at the option of the Utility when this type of service is practical from the Ut!!!ty's angineering standpoint. All currents and voltages stated hereta are nominal, reasonable variations being permitted.

New lights will normally be supplied as muluple systems. Series service to new ifahts will be made only when it is practical from the Utility's engtLeering standpoint to supply them from existing series systems.

'Ir. certain localities the Utility supplies servlee from 120/208 volt, wre-connected, polyphase lines in place of 240 volt service.

2. Point of Delivery: Delivery will be made from the Utility's existing electric lines without estension thereof to customers system at a point or points mutually agreed upon except as provided in Special Condition 8. The Utility will provide at its expense an overhead service drop to a customer owned Inter.

connected group of lamps having a connected load of not less than 2 kw. For a customer owned inter.

connected group of lamps having a connected load of less than 2 kW (1) ths Utility will connect the customers overhead service wire to the Utility's overhead 11nes at the customers expense, or (2) at the customers option, the Ut!!!ty will in install, own and maintain the overhead servlee provided the customer pays the initial cost of the service plus 1% per month of such initial cost. When 480 voit service is desired

~

by the customer, energy will be supplied from overhead facilities at 480 volts, single-phase for an inter-connseted group of lamps provided the total connected lued of the interconnected group of la=ps to be so served is not less than 8 kw. For a customerewned interconnected system of loan. Nan 8 kw but not less than 2 kw, energy will be supplied at 120/240 volta unless the customer pays the additional cost of a 480 volt supply.

(continued 4 m

Advice Letter No. 734-E Issued by Date Filed Apri1 13,1979 Decision No.

W.3L Gallavan Efret ce May 16, 19/9 Vice. President-Rates and Valuation Reso.ution No. E-1636 D M ii) @w &

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A mn r=

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o. n Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 6750 E San Francisco, California Nelim: m vimi Cal. P.U.C. Sheets Nos. 6723 6014.E

.l Schedule No. OL.1 OUTDOOR AREA _ LIGHTING SERVICE (Continued)

4. Service Connection:

(a) A service connection will be made from the Utility's existing electric lines, either overhead. a underground, at a point mutually agreed upon, without extension thereof except as provided in Special Condition 5.

(b) W* :re an overhead secondary circuit ir readily available, the Utility will mcke a complete overhead service installation at its expense. If a secondary circult is not available, or where add!.

tional facilities are required to complete the installation, such will be provided as speci$ed in Special Condition 5.

(c) Where underground service is supplied, the appilcant shallinstall and own the poie. IncluCng any internal pole and msst arm wiring. Wnere underground service is supplied from a1 overh.qd distribution system. the applicant shall furnish and install conductors and r.ny necenary a on.luit between the base of the Utility's distribution pole where service is readily available and the top of the customer-owned pole, except that street crossings or other work in the street area shall be installed by the Ut!!ity at the applicant's espcose in accordance with Special Condition 5. The applicant shall pay to the Utility the material ccat of the pole riser. Including conduit, mciding and otber materials, but excluding the cost of the riser conductors, and the Utility ulli comptate the riser installation at its expense.

(d) Where underground service is supplied from an unkrground distribution system, the appli-cant shall furalsh and install conductors and any necessary conduit between an existing secondary splice box or other suitable point of connection an designated by the Utility at or near the appli.

cant's property line and the top of the customer-owned pole. The Utility will furnish the necessary connectors and make the underground service connection at its expense. Street crossings or other work In the street area necessary to provide an underground service will be installed by the Utility in accordance with Special Condition 5.

3. Additional Facilities: Facilities such as secondary circuits. transformers and associated equipment required in addition to the Factiltles furnished under Special Conditions 3 and 4 will be installed pro-vided the applicant advances to the Utility the estimated installed cost thereof and pays an additional m

[

)

montlJy charge of 1% of euch cost.

1. d If such additional facilities or any portion thereof are thereafter used to serve new separately.

metered permanent load for which the Utility would install all or a portion o! sa:d additional facilities at its expense under its rules, all or a portion of the appilcant's advance will be refunded without interest following the connection of such aew load. Refunds will be based on the footage by which the allowable free length under Rule 15 B.I. for such new load exceeds the lengths of line,if any, required to serve, multiplied by the unit cost per foot spectaed in Rule 15 D.3.a.(1) in effect at the time the advance is paid. Where such refunds are made, the additional monthly charge will be adjusted to 1%

of the unrefunded balance of the advance. No refunds will be made in excess of the original advance.

6. Relocation ce Removal of Facilities:

(a) When the Utility's distribution facilities from which service is supplied hereunder, and/or the lighting facilltles installed hereunder, are to be relocated or removed at the customer's request or to comply with governmental requ:rernents, the Utility shall have the right, upon written notice, to discontinue the service being furnished under this schedule without obligation or Itability. Service may be re-established in accordance with the Special Conditions of this schedule.

(b) When the Itghting facilities installed hereunder are relocated at the customer's request or when the Utility must relocate or modify the lighting facilities to comply with governmental requirements or because of an irreconcilable objection to the f acs!!tles by others, tbo Uttlity shall be paid the cost of such relocation or modi $ cation.

(c) If the lighting facilities installed hereunder are made idle or are removed before expiration of the initial term of the effective contract, the customer shall pay to the Ut!!!ty the cost of the Installation plus the estimated cost of removal,less the estimated salvage value of the facilities removed.

7. Access: All lighting facilities installed hereun ar must be accessible to the Ut!!!ty's vehicles for installation and maintenance.

8. Maintenanse: Except in the case of emergency, maintenance of lamps and equipment will be performed only during normal working hours within a reasonable period following notlacation by the customer of the need for such maintenance.

9. Centracs: A written contract in form on ole with the California Public Utilities Commission may be required for service under this schedule for a period not to exceed three years.

n khiee Letter No. 669-E Issued by Date Filed %v 9, 1978

• , ~

Decision No.

W. M. Gallavan Effective Jime 8, 1978 VimPresident-Ratra and Valuation Resolution No.

O w,

n em a m Pacifle Oas and Electric Company Revised Cal. P.U.C. Sheat L. 6878-E San Francisco, California ca nceling Revm1 Cal. P.U.C. Sheet No. 6030-E

,1 O

Schedule No. LS-3 STREET AND HIGHWAY LIGHTING ELECTROLIER ME ER RA*E (Continued)

3. (Jaderground Servwe Connections The Ut!!!ty will provide an underground service connection at its expense from either its overhead or undersvound system to one electroller of each group of Inter.

connected electrollers provided (1) the customer has arranged the system for the least practical number of points of delivery. (2; there are not less than 10 electro!!ers in the group. and (3) there is not lees than 3 kw ccanected load. This service connection shall not exceed 25 feet of underground run from the base of the Utility's pole in an overhead !!ne nor exceed 40 feet of underground run from a location where service is available in an underground system. The Utiltty will extend the underground service beyond the free length at the customer's request in accordance with Special Condition 7.

Where the customer requests an underground service to a erstem of less than 10 electrollers or 3 kw of connected load the customer shal! install and own the extension from his system to the Utility's distri-bution system where service is readily available and shall pay the cost of connecting to the Utility's distri-bution system.

4. General: Each point of do!!very to an electroller etreult or circuits will be metered and billed separately. The meter will be located at a suttable location. The billing demand w!!! be based upon the connected load or upon the metered demand, but will be not less than 3 kw.

The connected load upon which the energy charges will be based will be the sum of the ratings of all lamps that may be connected to the system plus the wattsge losses for the associated ballasts compute 1 to the nearest one-tenth kw. All lamps and ballasts will be counted at the manufacturer's nameplate or catalog rating in kw (one kw equivalent to one kva), or at ratings determined by test.

S. Switchina: Switching service will not be provided by the Utility for systems connected after September 11,1978.

6. Maintenance This schedule does not contemplate maintenance within the rates as shown above.

However, at the request of the customer. the Ut!!!ty will replace lamps and glass or unit coverings, ballasts.

and do other normal system maintenance cn a time and material cost beats provided the regular standard maintenance equ!pment and procedures can be used.

y. Systeams Owned in Part by the (Jeality Where the Utility installs and thereafter owns and maintains any portion of the 0xtures, poles, circuits or other facilities that comprise customer's street !!ghting system an additional monthly charge of 2% of the 17tility's estimated installed cost of such facilities will be made. If such facilities were installed prior to the date this provision is first effective, the addi-tional monthly charge will be 1%8'e of such cost. Customer or others may elect to pay the Ut!!!ty's esti-mated installed cost of such fact!!ttes, in which event the additional monthly charge will be 1% of such cost.

8. Ilne Estensions: Where the Utility extends its electric lines to serve customer's street lighting system, an additional monthly charge of 2% of the Utility's estimated installed cost of such line exten-ston, exclusive of service connection (and transformer. If required) furnished under Special Conditions

1. 2. and 3 will be made. If customer elects to advance the Utility's estimated installed cost of such exten-ston, the additional monthly charge will be 1% of such cost. The Utility may walve the foregolcg pro-visions where the extension is estimated to be of nominal cost and where not more than one pole and one span of line is required, if such extension or any portion thereof,is utilised to serve new separately metered permanent load for which an axcess free length of line is allowed under Rule No.15. such cost to be used in determining the additional monthly charge will thereafter be reduced in proportion to the relative length of excess free footage allowance for the new load,if any, as compared to the length of the original extension. If an advance has been made as provided above and if under said Rule No.15. an excess free footage allowance remains after said new load is installed, all or part of the advance will be refunded without interest to the customer. These rwfunds will be computed by converting the amount of the advance to an amount per foot and multiplying the excess free footage by this unit per foot. Such refunds. if any, will be made following the connection of such new load. If such extension is part of a series of extensions on any of which an advance is still refundable, refunds due from new loed will be made in turn as provided in Rule No.15. No payment will be made in excess of the original amount ad-vanced.

Advice Letter No. 688-E Issued by Date File <tept. 6, 1978 Decision No. 89316 W. M. Gallavan Effective Sept. 11, 1978 Vice President-Rates and Valuation Resolution No.

A-36 0

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eseses no. m 3

Paciac Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7047.E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. tiU39.E v

Schedule No.TC.1 TRAFFIC CONTROL SERVICE APPt.ICABILITY Applicable to metered sonice for traffic directional sign or signal lighting systems owned by govern.

mental agencies and located on streets, highways and other publicly-dedicated outdoor ways.and places.

TERRITORY The entire territory served.

RATES Per Metee Pee Month Seevice Geege For each Service Connection fl.50 Energy Charge (in addition to the Servlee Charge):

All kwhr. per kwbr

.03 Minimum Charge:

31.50 per mond.

Adjustments:

Adjustments. as speelfted in Parts B and C of the Preliminary Statement, will be added to each bill for service calculated at the above rates, including bills for minimum charges. Adjustment amounts are as follows:

per kwhr Energy Cost Adjustment.

$.01722 Tax Change Adjustment L00071)

Total 8.01651 SPECIAL CONDITIONS

1. Trpe of Service: Energy will normally be supplied at 120/240 volt single-phase service (120/208 s

volte star in certain localities) unless the customer pays the additional initial cost of a 480 volt supply.

However, service from 480 volt sources from underground systems will be msde available only for new servlee connections at the option of the Utility when this type of service is practical from Utility's engl.

neering standpoint.

2. Point of Defieery: Dettvery will be made from Utility's existing electrie lines at a point mutually agreed upon, without extension thereof to customer's system except as provided in Special Condition 6.

3. Service Connection: The Ut!!!ty will provide at its expense an overhead drop to the customer.

owned system: however. where the customer requests an underground service the customer will install and own the extension from his system to the Utility's nearest junction box or to the base of the pole where service is readily available and wtil pay the cost of connecting to the Utility's distribution system.

Including any necessary conduit or riser material.

4. Meeering: Each point of delivery will be metered and billed separately. The meter will be at a suitable location agreeable to the Utility.

S. Switching sad Maintenance Switching and maintenance will be performed by the customer.

6. Line Extensions: Where, after the date this provision is first effective, the Utility extends its electric lines (overhead or underground) to serve customer's system. an additional monthly charge of 1%% of the Utility's estimated Installed cost of such extension, exclusive of meter, service connection. and trans.

i former. If required, furnished under Special Conditions 1. I and 3. will be made. If ruch extension was installed prior to the date this provision is effective, the additionst monthly charge will be 1%% of such cost. If customer elects to advance Utility's estimated Installed cost of such extension, the additional monthly charge will be 1% of such cost.The Ut!!!ty may waive the foregoing provisions where the exten.

ston is estimated to be of nominal cost and where not more than one pole and one span of line is required.

If such extenston, or any partion thoreof,is utilised to serve new separately metered permanent load for which an excess free length of line is allowed under Rule No.15. such cost to be used in determining the additional monthly charge will thereafter be reduced in proportion to the relative length of excess free footage allowance for the new loaJ. If any, as compared to the length of the original extension. If an advance has been made as provided above, and if under such Rule No.15 an excess free footage allowance remains after said new load is lastalled, all or part of the advance will be refunded without interest to the customer.These refunds wt!! be computed by converting the amount of the advance to an amount per foot and multiplying the excess *ree fort Ap by the unit per foot. Such refunds. if any, will be made follow.

Ing the connection of such new mad. H such extension is part of a series of extensions, on any of which an advance is still refundable, refunds due from new load will be made in turn as provided in Rule No.15.

No payment will be made in excess if the original amount advanced.

a' Advice Letter No. 734.E Issued by Date Filed Apri1 13,1979 Decision No.

W.M. Gallavan Effective May 15. 1979 Vice. President-Rates and Valuation Remit tion No. E-1836 - - g g A -

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Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7048.E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. ti3MA O

Sc1 edule No. P.8 OIL REFINERY ELECTRIC AND STEAM SERVICE APPLICABILITY This schedule is applicable to customers receiving po!yphase alternating current electric service and 160 pounds per square inch steam service for the operation of petroleum renneries under contracts authorized by the Public Utilities Commission of the State of Californla.

TERRITORY A-The oil reSnery in the vicinity of the Martines Power Plant.

B-The oil rennery In the vic!Jty of the Oleum Power Plant.

C-The oil reSnory in the vicinity of the Avon P ver Plant.

RATES Electric Service:

The rates for electric service to each metering point w!!! be the rates and charges. Including the snergy Coat Adjustmep*, of Schedule No. A 13 or A 23, as appropriate in accordance with the Applicability clauses thereof.

Steam Service:

Demend Charge For a monthly maximum demand not to exceed Per Month 325,000 pounds per hour 36,000.00 Quandry Garge (in addition to the Douand Charge):

Money Amount:

Per 1.00o !bs.

First 125.000,000 pounds per mon'h 2.0 f All Excess 1.5 Puol Amount

.265 bbla.

O (continued)

O Advice Letter No. 734.E Issued by Date Filed Apri1 13,1979 Decision No.

W. M. Gallavan Effective May 15, 1979 Vice. President-Rates ud Valuation Resolution No. E-1836

\\

es-eese me.ese Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 6959-E San Francisco, California Canceling Revised Cal. P,U.C. Sheet No. 6342 E v

Schedule No. P-8 OIL REFINERY ELECTRIC AND STEAM SERVICE (Continued)

SPSCIAL CONDITIONS

1. Feedwesor: The customer will de11rer to Utility at aald steam plants a quantity of feedwater which will in pounds equal the pounds of steam delivered, subject to the specifications mutually agreed to by the parties.

2. Contracts Service supplied hereunder shall be in accordance with contracts authorized uy the Public Utility Commission of the State of California. This rate schedule, or parts thereof, shall expire upon ttrmination or expiration of said contracts. The term " mutually agreed to by the parties" refers to said contracts. The terms and conditions of these respective contracts as authorized by the Public Uttiltles Commission of the State of California shall govern with respect to each of the customers served hereunder, notwithstanding any inconsistency with this tariff schedule.

3. Maaneness Demand: The maximum demand in any month will be the maximum average power taken during any 30 minute interval in the month, but not less than the diversified resistance welder load computed in accordance with Rule No. 2; provided, that in cases where the use of energy is intermittent or subject to violent fluctuations, either a 5-minute cr a 15 minue interval may be used.

4. Billing Th-J The billing demand to be used in computing charges will be the mean of the maxi-mum demand as determined under Special Condition 3 for the current month and the highest such de-mand occurring in the year ending with the current month, but not less than 1,000 kw.

5. Of Peak Deensad All customers will.3or billing purposes. have maximum demands ignored which occur between 10:30 P.M. and 6:30 A.M. of tne following day and on Sundays and the following holidayo:

New Year's Day, Washington's Birthday, Memortal Day. Independence Day. Labor Day, Veterans' Day.

Thanhagtetng Day and Christmas Day, as said days are specified in Public Law 90 363 (U.S.C.A. Section 6103)

6. Power Fecree: The total charge for any month as computed on the above rates will be decreased c.r increased, respectively, by 0.1% for each 1% that the average power factor af customer's load in the month was greater orless than 85%, such average power factor to be computed (to the nearest whole per cent) from the ratto of lagging kilovolt ampere hours to kilowatt hours consumed in the month.

7. Velease Adj.m -ci The above charges are applicable without adjustment for voltage when (a) delivery is made at less than 2 kr, or (b) when delivery is made by means of Utility-owned transformers at a distribution voltage other than a standard primary distribution voltage, or (c) when delivery is made at a voltage that requires more than one stage of transformation from transmission ve Age. When dellvery is made at the standard primary distribution voltage at 2 kr or above available in the area from the Utility's distribution line or, where the Utility has elected to supply service at a standard primary distribution voltage from a transmission line, for its operating convenience, from Utility-owned transformers on the customer's property, the above charges for any month will be reduced by 15e per kw of billing demand in the month. When delivery is made at transmission voltage (80 kr and above), the above charges for any month will be reduced by 25d per kw cf billing demand in the month. The Utility retains the right to change its line voltage at any time, after reasonable advance notice to any customer receiving a discount bereunder and afected by such change, and such customer then has the option to change his system so as to receive service at the new line voltage or to accept service through trans-formers to be supplied by Utility subject to the voltage adjustment above.

t l (j Advice Letter No. 711.E Issued by Date Filed December 6, 1978 V

Decision No.

W. M. Gallavan Effective January 5, 1979 V:ce President-Rates and Valuation Resolution No.

s

u.nu me. n Pacifle Oas and Electric Company Revised Cal. P.U.C. Sheet No. 7049 E San Francisco, California Canceling P.eviel Cal. P.U.C. Sheet No. 090.%

O Schedule No. PA.1 AGRICULTURAL POWER APPLICABILITY This schedule is applicable to reclamation service and to general agricultural service on the farm.

but it is not applicable te residential and commercial service, nor to servlee to which Schedule No. A 23 is applicable. Rate A 6 hall apply to a!! single motor installations with a connected load rated less than 35 horsepower and to all multiload installations aggregating less than 15 horsepower er kilowatts.

Rate D shall apply to all sicale-motor Installations rated 35 horsepower or more, to all multi-load instal.

lations aggregating 15 horsepower or kilowatts or more. and overload motors as provided in Special Condition 10. Customers of record on September 21.1975 who maintain continuous service under either Rate A or Rate B not in conformance with the foregotng. may thereafter either continue such non.

conforming service or request a change to the applicable rate. at their option.

_'ITR RITORY The entire territory served.

RA'ITS A-Connected Load Damis.

D-Maximum Demand Basis.

Per Meter Service Cherse, per customer per month 3 2.50 Per hp or kw. per month 3.60 Energy Charge (in addition to the Service Charge)

Ftrgt 1.000 kwbr per hp or kw per year, per kwbr

.01692 Next 1.000 kwbr per hp or kw per year, per kwbr

.01341 Over 2.000 kwbr per hp or kw per year, per kwhr

.01052 Minimum Charges The annual minimum charge shall be the sum of the monthly service charges.

Adjustments:

Adjustments as speel8ed in Parts D and C of the Preliminary Statement, will be added to each bill for service calculated at the above rates, including bills for minimum charges. Adjustment amounts are as follows:

A per Irwhr Energy Cost Adjustmen' 3.01 22 Tax Change Adjustment

(.00071)

Total 3.01G51 SPECIAL CONDITIONS

1. Contracts: Where a line extension is required or where the cost to the Utility to install the neces.

sary facilities is substantial, a written contract for an initial term of three years will be required for service under this schedule. In all other instances, a written contract for an initial term of one year.

beginning on the orst regula monthly meter reading date after service is commenced, will be required.

Contracts will remain in effect after the initial term until terminated by either the customer or the Utility.

2. Contract Yur The above rates will apply to twelve month periods beginning with the orst regular monthly meter reading date after service is commenced.

3. Payment of Charges: The service charge will be payable in twelve monthly payments beginning with the nrat monthly billing period of the contract year. The energy charge will be computed on meter readings and will be payable each month. The charge for energy used during a partial month prior to the beginning of a contract year will be billed at the rate of the orst energy block.

4. Guaranteed Connected Lead oc Bd!In: Dessend: A customer may obtain the rates for a larger connected load or for a larger billing demand by guaranteeing the service charge for the contract year and rates per kilowatt hour applica51e to such larger connected load or billing demand.

5. Connected Load: Connected load for the purpose of this schedule is the sum of the rated capac!.

ties, determined in accordance with Rule No. 2. of all equipment that is served through one metering point and that may be operated at the same time. In no case will charges be based on less than two '

horsepower for single phase service nor less than three horsepower for three phase service.

6. Marimom Demand: The maximum demand in any monthly billing period will be the nazimum average power, expressed in kilowatts. t.Lken during any 15-minute interval in the month, but not less than the diverstood resistance welder lad computed in accordance with Rule No. 2. Where the use of energy is intermittent or subject to abnormal Suctuatic, t 5-minute interval may be used.

(continued) m Advice Letter No. 7.%E Issued by Date Filed ADM1 13,1979 Decision No.

W. M. Gallavan Effective May 15, 1979 Vice. President-Rates and Valuation Resolution No. E-1836 6-40 P

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es.< u.o e.e heific Gas and Electric Cmpany Reviwd Cal. Pr.C. Sheet No. 6043.E San Trancisco. California Cancelmr Hemed Cal. P.'.~.C. neet L. M4 v

Schedule No. PA.1 AGRICULTURAL POWER (Continued)

7. Bdling Demand: The billing demand used in computing charges under Rate B will be the highest maximum demand created by the installation in the twelve %4onth period ending with the curient month, except that when the connected load is permanently reduced. the maximum demands created before such pecmanent reduction will be ignored. B1111ng demand w!!! be computed to the nearest whole kilom att.

Charges will not be based on a billarg demand in kilowatts of less than 75% of the nameplate rating in horsepower of the two largest motors connected. Where the connected load is 35 horsepower or les.

the Utility may, at its option, use the demand determined by test as the billing demand for billing pui.

poses in lieu of installing a demand meter.

a. Ganee la Castemwes:When there is a change of customers during the continct year. no adjustnwnt irl!! be made in charges billed prior to the date of change. The contract year for the new customer mil begin with the first regular monthly meter reading after the date service is commenced.

9. Gensee in Connected 14ed oc Billing Dessendt Billing adjustments will be made for connected load or billing demand char.ges and for permanent decreases that take place during the contract year except that changer of three horseposer or three kilowatts or less will be ignored for billing purpore where the load is l' 'up or 15 kw or more, until the beginning of the next contract year. It shall be the customer's responsibility to notify the Utility of changes in connected load and of persnanent changes in operating conditions which will result in lower martmum demands.

No adjustments w111 be made in charges billed for aervice supplied prior to a change in connecte*!

load or billing demand. For the period remaining in the contract year after the date of the change, service charge payments will be based on the new connected load er billing demand and the energy charge t,illing will be based on the full annual energy blocks for the new load or billing demand less the kilowatt hours recorded prior to the date of the change multiplied by the ratio of the new load or billing demand in the previous load or billing demand.

m When there is a perinanent reduction in connected load, the billing demand to be used under Rate n i

shall be computed in accordance with Special Condition 7.

gj No adjustment will be made for a temporary reduction in connected load or billing demand I* toad is reconnected within twelve months after it is disconnected charges will be recomputed on the basis that no reduction in load bad taken place.

10. Ovnloaded Motoru Whenever the measured input to any motor, rated 15 horsepow er or more.

or any group of motors aggregating 15 horsepower or more, served through one metering point. is deten mined by the Utllity to exceed one kilowatt per horsepower of nameplate rated output. chstges shall be billed under Rate B.

11. Disc,atinuance of Seevice: A customer may cease taking service at any time after expiration of the inittst term of the app!!csble contract.No adjustment of billing will R inade when service is discon-tlnued. Any customer resuming service within twelve months after discontinua?? eervice will be requited I

to pay a!! charges that would have been billed if servlee had not been discontinued.

12. Credit for Ownership of Transformer by Cumornw: Customers operating installations having a connected load of 50 hp or over and owning the transformers supplying such installations as of lieptember 21,1975, will be allowed the fo!!owing credits:

Siae of Annual Credit per hp of Inetellation Conamed Lead 50 99 hp 31.00 per hp 100 499 hp

.90 per hp 500 and over

.30 per bp In those esses where the customer's motor operates at the voltage at which the service la metered.

l

% credit for customer ownership of transformers will be allowed on the connected load of such motor.

Advice Letter No. 512.E Issued by Date Filed Sept. 16, 1975 i

Decision No. 84902 W. M. Gal.

i.

Effective Sept. 21, 1975 l

Vice. President-Rate:, id Valnatinn Rmintinn L.

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I CS ease 803. De Pacifle Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7050-E San Francisco, California Canceling itevne<1 Cal. P.U.C. Sheet No. twil ^

O Schedule No. S.1 STAND.BY SERVICE APPLICABILITY This schedule is applicable to stand-by or breakdown service to customers whose premises are regu-larly supplied, in whole or in part, with electric energy from a privately owned source of supply: to auxillary service to customers who at times take service (by means of a double-throw switch) from another public Ut!!!ty; and to other electric service where the Ut!!!ty must provide reserve capacity and stand ready at all t! nes to supply electricity, but where the use of electric service is not of a usual, regu-lar or continuous character.

TERRITORY The entfre territory served.

Per Meter RATES Per Month Customer Charge in addition to any other Customer Charge 85.00 Stand-by Charse per kw of Contract Capacity (Subject to voltage adjustment as provided in Special Condidon 11)

Where customer's plant or other source employs Co-generation Technology or utilises Renewable Resources as the energy source (as defined in Special Condition 13) 0.75 All other service 0.95 Stand-by Charge per kw of Contract Capacity, excess off peak service 0.40 (Subject to voltage adjustment as provided in Special Condition 11)

Reactive Deniand Qarge (in addition to Stand-by Charge) per kvar of maximum reactive demand 0.15 Demand and Energy Charsee (in addition to Stand-by Charge):

The Regular Schedule Applicable (see Special Condition 1) including the Customer Charge, m

if any, the minimum charges, Energy Cost Adjustment and all other provisions of said schedules.

SPECIAL CONDITIONS

1. Regular Schedule Applicable: Stand-by service. either alone or in combination with other load through the same meter, shall be billed in conjunction with that rate schedule which would be applicable to customer's total load including that portion of customer's load for which stand by service is provided

2. Allowance For Ci.atamar's Pleet Meiotenance: After a customer has been connected to Utility's system under this schedule and its plant has been in operation for a period of six months, for that portion of the Contract Capacity that may to out of service for scheduled maistenance in the months of February, March, April and/or November, such outages up to 30 consecutive days per calendar year will beignored for the purposes of determining demand charges under the Regular Schedule Applicable.

This allowance shall be made only if the customer submits to the Utility (a) 90 days' prior notice of intent to perform maintenance and (b) records showing to the satisfaction of the Utility what part of the load on the Utility's system in any of *he aforementio~ed months was due to such scheduled main.

tenance. The Utility, at its sole option, may defer customer's scheduled maintenance subsequent to which deferral an outage fcr maintenance will be allowed in accordance herewith. Notice of such deferra!, if any, shall be given by *he Ut!!!ty not less than 60 days prior to customer's scheduled outage, except in event of an emergency. Where maintenance is performed during a part of one or more of these months this provision shall apply only during that part. One allowance each calender year for a parttal outage for maintenance for each unit of a multiple unit source or pair of outages of up to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> for each of one or more units, to remove and replace all or a portion of customer's source shall be made in accordance with the foregoing during the months specified.

(continued)

^

Advice Letter No. 734.E Issued by Date FiledApril 13, 1979 Decision No.

W. M. Gallavan Effective May 15, 19/9 Vlee-President-Rates and Valuation Resolution No. E-1636 0

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u.uu no. u Pacifle Gas and Electric Cornpany Revised Cal. P.U.C. Sheet No. 6973.E (7

San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 4940.E k.)

v Schedule No.S.1 STAND.BY SERVICE (Continued) lo. Ructive Demand: When the customer's plant (or other souree) is operated in parallel 'with the Utility's system. the customer will so design and operate his facilities that the reactive current require.

ments of the portion of the customer's load supplied from the customer's plant (or other source) are not supplied at any time from the Utility's system. In the event customer places a reactive demand on the Utility in any month in excess of 0.1 kvar per kw of Contract Capacity, the Reactive Demand Charge shall be effective that month and each month thereafter until the customer demonstrates to the Utility's satifaction that adequate correction has been provided.

11. Voltage Adjustment: The above stand-by charges are appl. cable without adjustment for voltage when delivery is made at transmission voltage (60 kr and above). When delivery is made at the standard primary distribution voltage at 2 kv or above available in the area from the Utility's distribution line or, where the Utility has elected to supply service at a standard primary distribution voltage from a trans-mission line, for its operating cor tenience, from Utility owned transformers on the customer's property, the above charges for any month will be increased by 10e ur kw of contract capacity. When (a) delivery is made at less than 2 kr. or (b) when delivery is made by means of Utility-owned transformers at a distribution voltage other than a standard primary distribution voltage, or (c) when delivery is made at a voltage that requires more than one stage of transformation from transtnission voltage. the above charges for any month will be increased by 23e per kw of contract capacity.

The Utility retains the right to change its !!ne voltage at any time, after reasonable advance notice to any customer affected by such change, and such customer then has the option to change his system so as to receive service at the new line voltage or to accept service through transformers to be supplied by Utility subject to the voltage adjustment above.

12. Excess Of Peak Service: Ezeese off peak stand-by service is availab?e only where the Regular Schedule Applicable is Schedule No. A 22 or A 13 and applies to service which is provided only during the off peak periods specifled therein and which is in excess of other stand-by service. If any.

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13. Dennitiams:

(a) Co generation Technology - the use for the generation of electricity of exhaust steam, waste Q>

steam, beat. or resultant energy from an industrial, commercial, or manufacturing plant or process. or the use of exhaust steam, waste steam. or heat from a thermal powerplant for an industrial. commercial, or manufacturing plant or process.

(b) Renewable )tesources - those sources of enerry whleb are not diminished by use for electric generat!on, including wind power; solar heat, either dired, conversion or steam; steam where the energy sourco la rubbish, animal waste or other waste fuel not a fossil fuel or a derivation thereof; tidal or wave energy; and geothermal energy. The use of renewable resources may or may not employ Co-generation Technology.

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Advice Letter No. 714.E Issued by Date Filed Decernber 22, 1979 Decision No.

W. M. Gallavan Effective January 21, 1979 Vice. President-Rates and Valuation Resolution No.

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A-43 D

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ca caos no a Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No 7051.E San Francisco, California Cancelite Oneinal Cal. P.U.C. Sheet No. 677e O

Schedule No. AD EXPERIMENTAL NON. DOMESTIC LOAD DEFERRAL SERVICE API'LICAllILITY Service under this Schedule is provided at the sole option of the Utility for the purpose of evaluating a non-domestic load deferrej service and is applicable to single-phase and polyphase alternating current services which have Utility <:ontrolled central refrigeration air conditioning.

TERRITORY Any portion of the entire territory served, as determined by the Utility.

RATES The regular single. phase or polyphase alternating current service schedule otherwise applicable in the area served, less the following discount per ton (to the nearest.5 ton) of controlled connected load:

Per Meter Control Discount Per Month Central Air Conditioning, per ton

$1.50 provided hcwever, that the total bill for service shall not be less than the customer or demand charge plus the Energy Cost Adjustment.

SPECIAL CONDITf 0NS

1. Determination of suitability of custorner's central refrigeration air ronditioning foi controlled load service will be made by the Utility.

2. The tonnage of each centrolled air conditioner will be determined by the Utility bami on name-plate rating of the 1: nit or, 'f not available, by test or from other available data. The l'tility reserves the right to exclude from the discount any additions or changes to the customer's air conditioner (sL

3. The Control D!. count for central air conditionine in in effect inr meter readings commencing Ma)

I and termmating September 30 of each year.

^

4. Control will be c.ccomp!!shed between the hours of 8:30 am and 10:30 pm by means of a special thermostat the set point of which may be raised by the Utility by remote control, but not to excced WF During emergency conditions as determined by the Utility, cornplete interruption of the customer's air conditioner (s) may be initiated by the Utility for such a time as needed while the emergency condition lasts.

5. This schedule is not optional. Applicability will be determined by the Utility notwithstanding the provisions of Rule No.12.

6. Cortrol mechanisms and assoelated wiring shall be installed, tested and matntained at the direction of the Ut!!!ty at locations selected by the Ut!!!ty and at no expense to the rustomer. Upon termination of tbls schedule with respect to any customer, all wiring will be returned to normal operating condition at the Utility's expense. Rule No.16, items D, E, and F, are specifically applicable to service hereunder.

7. Termination of Schedule: This rate schedule is temporary and will terminate three years after it first becomes effective.

Advice Letter No. 734 E Issued by Date Filed AoM1 13.1979 Decision No.

W. M. Gallavan Effective May 15. 1979 Vice-President-Rates and Valuation Resolution No.~ E-1836 0

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Pacific Gas and Electric Cornpany Original Cal. P.U.C. Sheet No. 7056-E

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San Francisco, California Canceling Cal. P.U.C. Sheet No.

.a Schedule No. DA EXPERIMENTAL DOMESTIC A R CONDITIONING LOAD DEFERRAL SERVICE APPLICABILITY Service under this Schedule is provided at the sole option of the Utility for the purpose of evaluating a controlled domestic load service and is applicable to single-phase individually metered domestic power service customers who have Ut!!!ty<on rolle4 electric central refrigerative air conditioning. which. In the opinion of the Utility, may be P41 table for Controlled service.

T1?RRITORY Any portion of the entire territory served. as determined by the Utility.

,EATES The regular domestic service schedule otherwise applicable in the area served. less a discount of

$2.00 per household per month provided. however, that the total bill for service shall not be less than the customer charge plus the Energy Cost Adjustment.

SPECIAL CONDITIONS

1. Control will be acconsplished between the hours of 8:30 a.m. and 10:30 p.m. by interruption of controlled air conditioners for a period not to exceed 15 minutes of each half hour.

2. The Control Discount for central air conditioning is in effect for meter readings commencing May 1 and termiiating September 30 of each year.

3. Controlled loads hereunder shall be limited to permanently installed appliances served from

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branch circuits exclusively devoted to such appliancer, v

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4. This schedule is not optional under the provisions of Rule No.12. Applicability will be based on suitability as determined solely by the Utility.

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5. Control mechanisms and associated wiring shall be installed. tested and maintained at the direction of the Utility at locations selected by the Utility and at no expense to the customer. Upon ter-mination of this schedule with respect to any customer, all wiring will be returned to normal operating condition at the Util:ty's expense. Rule No.16. Items D. E. and P, are specifically applicable to service hereunder.

6. Terminatien of Sched P '.2ts rate is temporary and with 'erminate April 30,1980.

A s./

Advice Letter No. 735-E Issued by Date Filed Anril 13. 1979 Decision No.

W. M. Gallavan Effective May 15, 1979 Vice-President-Rates and 'J' --tion Ilesolution No. E-363/- - n t

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es.esos no. no Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7057-E San Francisco, California Canceling Orimnal Cal. P.U.C. Sheet No. 7052 ^ O Schcdule No. DC EXPERIMENTAL DOMESTIC CONTROLLED LOAD SERVICE APPLICABILITY 8ervice under this Schedule is provided at tLe sole option of the Utility for the purpose of evaluating a controlled domestic load service and is applicable to single. phase individually metered domestle power service c.ustorners who have Ut!!!ty controlled electric central refrigerative air conditioning. which, in the opinion of the Utility, may be suitable for controlled service.

TERRITORY Any portion of the entire territory served, as determined by the Utility.

RATES The regular domestic service schedule otherwise applicable in the area served. less a discount of

$6 00 per household per month, provided. however, that the total bill for service shall not be less than the customer charge plus the Energy Cost Adjustment.

SP'dCIAL CONDITIONS

1. Control will be accomplished between the hours of 8:30 a.m. and 10:30 p.m. by interruption of controlled air conditioners for a period not to exceed 15 minutes of each half hour.

2. The Control Discount for central air conditioning is in effect for meter readings commencing hfay 1 and terminating September 30 of each year.

3. Controlled loads hereunder shall be limited to permanently installed appliances served from branch circuits exclusively devoted to such appliances.

4. This schedule is not optional under the provisions of Rule No.12. Applicability will be based on euttability as determined solely by the Ut!!ity.

5. Control mechanisms and associated wiring shall be installed, tested and maintained 4

• the direction of the Utility at locations selected by the Utility and at no expense to the customer. Upon *er.

mination of this schedule with respect to =n) customer, all wiring will be returned to normal operattag condition at the Utility's expense. Rule No.16. items D. E and F. are specifically applicable to service hereunder.

6. Termination of Schedule: This rate is temporey and will terminate April 30.1980.

m Advice Lt. r No. 735-E Issued by Date Filed Apri1 13, 1979 Decision No.

W. M. Gallavan Effective May 15, 1979 Vice-President-Rates and Valuation Resolution No. E-183 /

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es eno4 no. ss Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7053.E San Francisco, California Canceling itevised Cal. P.U.C. Sheet No. 6991.E A/

s Schedule No. PA-1X EXPERIMENTAL AGRICULTURAL POWER - TIME VARYING APPLICASH.ITY This schedule is applicable up to 50 customers currently served under Schedule No. PA 1B who request service under this Schedule and are selected by the Utility to participate. but it is not applicable to customers to which enber time. varying Schedule No. A.21 or A.22 will be applicable. Applicability will be determined by the utility notwithstanding the provisions of Rule No.12.

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The entire territory served.

RATES (Per Meter Per Month)

Monthly Service Charge 88.60 plus $0.10 per Kw of Maximum Demand Energy Charse (In Addition to the Service Charge)

Per Meter Per Month Period A Period B On Peak, per Kwh

$0.07469

$0.03782 Plus: Partial-Peak, per Kwh 0.01232 0.01232 Plus: Off Peak, per Kwh 0.00893 0.00893 Minimum Cherse:

The minimum charge shall be the monthly service charge.

Adjustments:

Adjustments, as specified in Parts B and C of the Preliminary Notement, will be added to each p

bt!! for service calculated at the above rates, including bills for r_.J' mum charges. Adjustment f

amounts are as follows:

Q per kwh Energy Cost Adjustment 8.01722 Tax Change Adjustment

(.00071)

Total 8.01651 SPECIAL CONDITIONS

1. Timme Periods:

I Period A is applicable to meter readings from May 1 to September 30. inclusive, for the following

)

hours:

4 On. Peak 12:30 p.m. to 6:30 p.m.

Monday through Friday Partial Peak 8: 30 a.m. to 12:30 p.m.

Monday through Friday i

6:30 p.m. to 10:30 p.m.

Off-Peak 10:30 p.m. to 8:30 a.m.

Monday through Friday All day Saturday and Sunday i

l l

l (contin'ted) jv l

Advice Letter No. 734-E Issued by Date Filed April 13, 1979 Decision No.

W. M. Gallavan Effective May 15, 1979 Vice-President-Rates and Valuation ResolutionSo, Er1836 n G\\ l DgI

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Peelae Gas and Electric Company Criginal Cal. P.C C. Sheet 5o. 6790 -E San Francisco, California Canerhog Cal. P.U.C. Sheet Nn.

O Schedule No. PA-II.

Esperimental Agricultural Power - T i me. Varying (Continveci

$PECIAL CONDITIONS (Continued) 1.

m.e Periods (Continued):

Period B is a plicable to meter readings from October 1. to April 30. inclusive, for the following hours:

On-peak 4:30 p.m. to 8:30 p.m.

Monday through Friday Par.ial Peak 8:30 a.m. to 4:30 p.m.

Manday through friday 8:30 p.m. to 10:30 p.m.

Off-peak 10:30 p.m. to 8:30 a.m.

Monday through Friday All day Saturday and Sunday 2.

Contracts: Where a line extension is requirad or where the cost to the Utility to install the recessary facliities is substantial, a written contract for an initial term of three yea-s will be requi-ed for service under ScSedule No. PA-1.

In all other instances, a written contract for an initial term of one year beginning on the first regular mont%1y meter readin; date af ter service is corrienr.ed, will be required. Contracts will remain in effect after the initia~

term until terminated by either the customer or the Utility.

3.

Contract Period: The abave rates will apply mnth to month for one year beginning with the first regular monthly meter reading date after service is corrienced. and will continue for m

up to two years at the sole discretion of the Utility.

4 Payment of Charges: The service charge and energy charge will be computed on meter readings and will be payable each month.

5.

Maximum Demand: The maximum demand in any monthly billing period will be the maximum average power. expressed in kilowatts, taken during any 15-minute interval in the month, but not less than the diversified resistance welder load computed in sccordance with Rule No. 2.

Where the use of energy is intermittent or subject to attormal fluctuation, a 5-minute interval may be used.

6.

Discontinuance of Service: A customer may cease taking service at any time after expiration of the initial term of the applicable contract. No adjustment of billing will be made when service is discontinued. Any customer resuming service within twelve months after discon-tinuing service will be required to pay all charges that would have been billed if service had not been discontinued.

7.

Credit for Ownership of Transformer by Customer: Customers operating installations having a connected load of 50 HP or over and owning the transformers supplying such installations as of September 21. 1975, will be allowed the following credits:

Stre of Annual Credit per hp of Inst 311ation Connected Load 50 - 99 HP

$1.00 per HP 100 - 499 HP

.90 per HP In those cases where the customer's motor operates at the voltage at which the service is metered, no credit for customer ownership of transformers will be allowed on the connected

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Advice Letter h*o. 679-E Issued by Date Filed June 29, 1978 Decision No.

W. M. Gallavan Efective July 29, 1978 Vice. President - Rates and Valuation Resolution No.

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EXHIBIT 8 l

RATE ADJUSTMENT DECEMBER 1,1979 ap I-5 6

$5

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Exhibit B PACIFIC GAS AND ELECTRIC COMPANY DIABLO CANYON ADJUSTMENT COMPUTATION OF 0FFSET ADJUSTMENT 4

Unit No.1-Consnercial Operating Date-December 1,1979 Unit No. 2-Coninercial Operating Date-August 1,1980 Unit No. 1 Total System CPUC Jurisdictional 2

1.

Sales - M Kwh 61,458 58,887 2.

Sales adjusted for 2

DWR, etc. M Kwh 56,780 3.

Revenue Requirement-167,438 155,758 SM Adjustment (Line 2.743 3 + Line 2) Mills per Kwh Unit No. 2 Total System CPUC Jurisdictional 2

)

1.

Sales - M Kwh 63,195 60,291 2.

Sales adjusted for DWR etc. M Kwh 58,236 4

3.

Revenue Requirement-131,622 122,438 SM Adjustment (Line 2.102 3 + Line 2) Mills per Kwh Sales Adjusted for Department of Water Resources, DS, DE and DT.

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EXHIBIT C RATE ADJUSTMENT FEBRUARY 1,1980 i

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f Exhibit C PACIFIC GAS AND ELECTRIC COMPANY DIABLO CANYON ADJUSTMENT COMPUTATION OF 0FFSET ADJUSTMENT Unit No. 1-Commercial Operating Date-February 1, 1980 Unit No. 2-Comercial Operating Date-October 1,1980 i

Unit No. 1 Total System CPUC Jurisdictional 2

1.

Sales - M Kwh 61,959 59,212 2.

Sales adjusted for 2

DWR, etc. M Kwh 57,120 3.

Revenue Requirement-171,331 159,378

$M Adjustment (Line 2.790 3+Line2) Mills per Kwh O

Unit No. 2 Total System CPUC Jurisdictional 2

1.

Sales - M Kwh 63,694 60,720 2.

Sales adjusted for DWR etc. M Kwh 58,635 3.

Revenue Requirement-135,341 125,898

$M Adjustment (Line 2.147 3 + Line 2) Mills per Kwh Sales Adjusted for Department of Water Resources, DS DE and DT.

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Exhibit D Sheet 1 of 4-PACIFIC GAS A10 ELEC1W1C COMPA1f Results of Operations - 1978 Test Year - Decision 89316 Adjusted To Reflect Comercial Operating Date Unit no.1 Decemeer 1,1979 And Unit No. 2 - Au9ust 1, 1980 (000's Omitted)

Total Electric Diablo Diablo -

CPut Jurisdictional tales Diablo Diablo Prop. wd ECAC Adjustment r nyon Canyon Dec. No. 89316 Canyon Canyon Base Diablo Diablo a

Line 8'.t No. I Unit No. 2 at Authorized Unit No. 1 Unit No. 2 Rates Canyon Canyon Line 1

Addition Addition Rates (a)

Addition Addition Adjusted Unit No. 1 Unit No. 2 Adjusted No.

(A)

(B)

(C)

(D)

(E)

(F)

(G)

(H)

(1) 1 Operating Revenues 167.438 131,622 2,000.011 155.758 122.438 2.278,207 (155.758)

(122,438) 2,000.011 1

Operating Espenses Production Espenses -

2 ECAC 831.951 831.951 (154,178) (121,196) 556.577 2

Production Espenses -

3 Non ECAC 4.621 4.843 90.128 4,298 4,504 98,930 98.930 3

4 Transmission Expenses 13.318 13,318 13.318 4

5 Distribution Espenses 109.423 109,423 109.423 5

Customer Account 6

Empense 44.553 44.553 44.553 6

7 Unco 11ectibles 551 434 4.367 551 434 5,352 (551)

(434) 4.367 7

Customer Services and Informational Expenses 8

Base Program 6.479 6,479 5.479 8

9 Supplemental Conservattor 6,655 6.655 6,655 9

10 Total 13,134 13.134 13,134 10 F

Load Management 11 Rate Research 6,716 6,716 6.716 11 Administrative and 12 General Expense 1.863 1.507 100.945 1,733 1,402 104,080 104.080 12 11 Franchise Requirements 1,106 869 12.636 1.029 808 14,473 (1,029)

(808) 12,636 13 14 Wa9e Adjustments 2,153 2,153 2.153 14 15 Sub-Total 8.140 7.C53 1,229,324 7.611 7.148 1,244,083 (155,758) (122,438) 965.887 15 16 DepreciatfA Expense 35.705 29.211 162,270 33.206 27,166 222.642 222.642 16 17 Tames Other Than Income 6.284 4.899 116,603 5,844 4,556 127,003 127,003 17 4

o State Corporation 18 Franchise Tan 8.240 6,308 24,541 7.663 5.866 38,070 38,070 18 19 Federal Income Tax 22.664 14.895 87.589 21.078 13,852 122,518 122,518 19 Total Operating 20 Expenses 81,034 62, % 6 1,620,326 75,402 58.588 1.754,316 (155.758) (122,438) 1,476,120 20 C

Net Operatin9 21 Revenues - Adjusted 86,404 68,656 379,685 80,356 63,850 523.891 523,891 21 C

22 Rate Base 909,517 722.695 3,996,682 845,850 672.106 5,514.638 5.514,638 22 23 Rate of Return 9.5%

9.5%

9.55 9.5%

9.5%

9.5%

9.5%

23 EEP (a) ECAC Revenues and ECAC Production Expenses and associated franchise and uncollectibles at rate of May 15, 1979 are included.

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Exhibit D Sheet 2.of 4 PACIFIC GAS AND ELECTRIC COMPA.NY Results of Operations - 1978 Test Year - Decision 89316 Adjusted To Reflect Consnercial Operating Date t' nit No.1 February 1,1980 And Unit No. 2 October 1; 1980 (000's Omitted)

Total Electric CPUC Jurisdictional Sales Diablo Diablo Diablo Diablo Proposed ICAC Mjustment Canyon Canyon Dec. No. 89316 Canyon Canyon Base Diablo Diablo Line Unit No. 1 Unit No. 2 at Authortred Unit No. 1 Unit No. 2' Adjusted Unit No. 1 Unit No. 2 Adjusted A Rates Canyon Canyon tine

_Nou.

_ Addition Addition Rates (a)

_ Addition Addition (A)

(B)

(C)

(D)

(E)

(F)

(G)

(H)

(I) 1 Operating Revenues 171.331 135,341 2.000.011 159,37S 125.898 2.285.287 (159.378) (125.898) 2.000.011 2

i Operating Expenses Production Expenses -

2 ECAC Production Expenses -

831,951 831,951 (157,760)

(124.#21) 549.570 2

3 Non ECAC 4.675 4.899 90.128 4,348 4,556 99,032 99.032 3

4 Transmission Expenses 13,318 13,318 13,318 4

5 Ofstribution Expenses 109,423 109,423 109.423 5

Customer Account 6

Expense 44,553 44.553 44.553 6

7 Unco 11ectibles 565 447 4,367 565 447 5,379 (565)

(447) 4,367 7

Customer Services and Informational Expeases 8

60se Program 6,479 6.479 6,479 8

9 Supriemental Conservation 6.655 6,655 6.655 9

10 Total 13,134 13.134 13,134 10 Load Management 11 Rate Research 6.716 6,716 6.716 11 Administrative and 12 General Expense 1,889 1.529 100.945 1,757 1.422 104.124 104.124 12 13 Franchise Requirements 1,132 893 12.636 1,053 830 14,519 (1.053)

(830) 12,636 13 14 Idage Adjustments 2.153 2,153 2,153 14 15 Sub-Total 8.261 7,768 1.229,324 7,723 7.255 1,244,302 (159,378) (125.898) 959.026 15 16 Depreciation Expense 36.545 29,681 162,270 33, % 7 27.603 223.860 223,860 16 17 Taxes Other Then Income 6.531 5,116 116,603 6,074 4.758 127,435 127,435 17 State Corporation 18 Franchise Tax 8,4 94 6,616 24.541 7,899 6,153 38.593 3b.593 18 19 Federal Income Tax 23,752 16.328 87,588 22,089 15,185 124.862 124.862 19 Total Operating 20 Expenses 83,583 65,509 1,620.326 77.772 60,954 1.759,052 (159.378) (125.898) 1.473.776 20 Net Operating 21 Revenues - Adjusted 87.748 E9,832 379,685 81,606 64.944 526.235 526.235 21 22 Rate Base 923,663 735,077 3,996,682 859,007 683,622 5.539.311 5.539.311 22 1

23 Rate of Return 9.51 9.5%

9.55 9.5%

9.55 9.51 9.5%

23 l

(a) ECAC Revenues and ECAC Production Expenses and associated franchise and uncollectibles at rate of May 15, 1979 are included.

d v

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Exhibit D Sheet 3 of 4 PACIFIC GAS AMD ELECTRIC COMPANY Results of Operations - 1980 Test Year - Application 58545 Adjusted To Reflect Comunercial Operating Date Unit No.1 December 1.1979 And Unit No. 2 - Au9ust 1.1980 (000'sOmitted)

D'41 Electric CPUC Jurisdictional Sales Diablo Diablo Diablo Diablo Proposed ECAC Adjustment Canyon Canyon At Canyon Canyon Diablo Diablo Line Unit No. I Unit No. 2 Proposed Base Unit No. 1 Unit No. 2 Canyon Canyon Line No.

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Addition Addition Rates Addition Addition Total Unit No. I Unit No. 2 Adjust M A (A)

(B)

(C)

(D)

LE)

(F)

(G)

(H)

(I) 1 Operating Revenues 167.438 131.622 1.426.631 155.758 122.438 1.704.827 (155.758) (122.438) 1.426.631 1

Operating Expenses Production Expenses -

2 ECAC (154.178)

(121.196) (275.374) 2 Production Expenses -

3 Non ECAC 4.621 4.843 124.566 4.298 4.504 133.368 133.368 3

4 Transmission Expenses 16.873 16.873 16.873 4

5 Olstribution Expenses 131.912 131.912 131.912 5

Customer Account 6

Expense 51.752 51.752 51.752 6

7 Unco 11ectibles 551 434 2.244 551 4 34 3.229 (551)

(434) 2.244 7

Customer Services and 4 Informational Expenses 8

Base Program 24.810 24.810 24.810 8

9 Load Management 29.518 29.518 29.518 9

Aeninistrative and 10 General Expense 1.863 1.507 126.050 1.733 1.402 129.185 129.185 10 11 Franchise Requirements 1.106 869 9.072 1.029 808 10.909 (1.029)

(808) 9.072 11 12 Wa9e Adjustments 5.049 5.049 5.049 12 13 Sub-Total 8.141 7.653 521.846 7.611 7.148 536.605 (1.580)

(1.242) 533.783 13 14 Depreciation 35.705 29.211 192.219 33.206 27.165 252.591 252,%91 14 15 Taxes Other Than income 6.284 4.899 80.773 5.844 4.556 91.173 91.173 15 Q

5 tate Corporation b

16 Franchise Tax 8.240 6.308 34.590 7.663 5.866 48.119 48,119 16 17 Federal Income Tax 22.664 14.895 119.190 21.078 13.852 154.120 154.120 17

]Q Total Operating s

18 Expenses 81.034 62.966 948.618 75.402 58.588 1.082.608 (155.758)

(122.439) 804.412 18 19 Net Operating Revenues 86.404 68.656 478.013 80.356 63.850 622.219 622.219 19 zpg 20 Rate Base 909.517 722.695 4.463.239 845.850 672.106 5.981,195 5.981,195 20 21 Rate of Return 9.5 9.5 10.71 9.5 9.5 10.40 10.40 21 u

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Exhibit D Sheet 4 of 4 PACIFIC GAS AMD ELECTRIC COMPAM Results of 0(erations - 1980 Test Year - Application 58545 Adjusted To Reflect' Commercial Operating Date Unit No.1 February 1,1980 And Unit No. 2 - Au9ust 1. 1980 (000's Omitted)

Total Electric CPUC Jurisdictional Sales Diablo Diablo Diablo Diablo Proposed ECAC Ad.justment Canyon Canyon At Canyon Canyon Diablo Diablo Line Unit No. 1 Unit No. 2 Proposed Base Unit No. 1 Unit No. 2 Canyon Canyon Line A

Addition Addition Rates Adittion Addition Total Unit No. 1 Unit No. 2 Adjusted A (A)

(B)

(C)

(D)

(E)

(F)

(5)

(H)

(I) 1 Operating Revenues 171.331 135.341 1.426.631 159.378 125.892 1.711.901 (159.378)

(125.892) 1.426.631 1

Operatin9 Expenses Production Expenses -

2 ECAC (157.760) (124.615) (282.375) 2 Production Expenses -

3 Non ECAC 4.675 4.899 124,566 4.348 4.556 133,470 133.470 3

4 Transmission Expenses 16.873 16,873 16.873 4

5 Distribution Expenses 131.912 131.912 131.912 5

Customer Account 6

Expense 51.752 51.752 51.752 6

7 Unco 11ectibles

$65 447 2.244 565 447 3.256 (565)

(447) 2.244 7

Customer Services and 8

Information Expenses 24,810 24.810 24.810 8

9 Load Mana9ement 29.518 29.518 29.518 9

Administrative and 10 General Expense 1.889 1,529 126.050 1.757 1.422 129.229 129.229 10 11 Franchise Requirements 1.132 893 9.072 1.053 830 10.955 (1.053)

(830) 9.072 11 12 Wege Adjustments 5.049 5.049 5.049 12 13 Sub-Total 8.261 7.768 521.846 7.723 7.255 536.824 (1.C18)

(1.277) 533.929 13 14 Depreciation 36.545 29.681 192.219 33.987 27.603 253.809 253.809 14 15 Taxes Other Than !ncome 6.531 5.116 80.773 6.074 4.758 91.605 91.605 15 State Corporation 16 Franchise Tax 8.494 6.616 34.590 7.899 6.153 48.642 48.642 16 C

17 Federal Income Tax 23,752 16.328 119.190 22.089 15,185 156.464 156.464 17 i -

Total Operating 18 Ex.nenses 83.583 65.509 948.618 77,772 60,954 1.087.344 (159.378)

(125.892) 802.074 18 19 Net Operating Revenues 87.748 69.832 478.013 81.606 64,938 624,557 624.557 19 20 Rate Base 923.663 735,077 4.463.239 839.007 683,622 6.005.868 6.005.868 20 f

21 Rate of Return 9.5 9.5 10.71 10.4 10.4 21 g

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EXHIBIT E P G and E FINANCIAL DATA

)

1

n PACIFIC GA5 AND ELECTRIC COMPANY O

BALANCE SHEET MARCH 31. 1979

. (

v ASSETS AhD OTHER DEBITS (000 Omitted)

Line Line No.

No.

UTILITY PLANT 1 Utility Plant.................................................................................

$7,842,443 1

2 Con s t ruc ti o n Wo rk i n P rog re s s.................................................................

2.016.a58 2

3 Total Utility Plant......................................................................

9.658,901 3

4 Less Accumulated Provision for Depreciation and Amorti zation..................................

2.51a.481 4

5 he t U ti l i ty P l an t, Le s s N uc l ea r Fuel....................................................

7.344,420 5

6 m.clearFuel..................................................................................

163.746 6

7 Le;s AC(umulated Provision for Amortization of Nuclear Fuel Assed11es........................

7.026 7

8 N e t N u c l e a r F ue l........................................................................

156.718 8

9 Net Utility Plant 7.501.138 9

10 Ga s S to re d Unde rg round - Nonc urren t..........................................................

12.191 10 GTHER PROPERTY AND INVESTENTS 11 Po n u t i l i ty P ro p e r ty...........................................................................

2,482 11 12 In ves tmen t i n Subs i di a ry Compani es (Cos t $151,789)............................................

204,990 12 1

13 O t h e r I n v e s ttre n t s............................................................................

958 13 l

14 Special Funds................................................................................

427 14 15 To ta l O the r P rope rty and I n ve s tmen ts.....................................................

208.857 15 CURRENT AND ACCRUED ASSETS 16 16 Cash..........................................................................................

17 Soccial Deposits............................................................................

1,474 17

/m 18 WortingFunds.................................................................................

383 18

\\

19 Temp o r a ry Ca s h I n ve s tme n t s....................................................................

64,346 19 2U Uotes and Accounts Receivable (less accumulated provision for uncollectible accounts).........

349,860 20 21 Peceivables from Associated Companies.........................................................

24.783 21 22 Reg ul a tory Bal anci ng Accoun ts - Recei vable....................................................

117,935 22 23 N te ri a l s a n d S u pp l i e s........................................................................

187,307 23 24 G a s S to re d un de r g ro un d - Cu r re n t..............................................................

133,740 24 25 Prepayments...................................................................................

36,715 25-26 I n te res t a nd Di v i dends Recei vabl e.............................................................

10.133 26 27 To ta l Cu rren t and Acc rued As se ts.........................................................

926.676 27 4

DEFERRED DEBITS 28 Un ario r t i z e d De b t E s pens e......................................................................

4,299 28 1

29 C l e a r i n g A c c o un t s............................................................................

3,284 29 30 Temporary Facilities..........................................................................

(517) 30 31 Mi s c e l l a n e ou s De fe rre d Deb i ts................................................................

l.748 31 32 To t a l De fe r re d Deb i t s....................................................................

8.814 32 Total Assets a d Other Debits

$8.657.6 76 33 33 n

( ) Denotes Deduction t-t t

i I

g Exhibit E O

go Q

mc PACIFIC CAS MD ELECTRIC COMPANY BALANCE SHEET 14 ARCH 31. 1979 LI ABILITIES AND OTHER CREDITS

(& 0 Omitted)

Line Line No.

ho.

PROPRIETARY CAPTIS 1

Como n S t o c k I s s ue d.......................................................................

$1.015.746 1

2 P re f e r re d S t oc k I s s ue d.....................................................................

1.102.451 2

3 Premium on Capital Stock...................................................................

733.053 3

4 Discount on Caottal Stock (7.795) 4 5

Ca p i t a l S to c k E x pe n s e......................................................................

(51.848) 5 6

RetainedEamings..........................................................................

J.341.506 6

7 T o t a l P rop ri e t a ry C a p i t a l.............................................................

4.133.112 7

LONG-TERM DEBT 8

Bon ds ( l e s s $ 18. 3 82 re a c q u i re d )............................................................

3.538.252 8

9 Una mo rt i z e d P remi um on L on g-Te nn Deb t......................................................

1.070 9

10 Unamo rt i s e d Di s co un t on Lon g-Te rm Deb t.....................................................

(20.467) 10 11 Total Long-Term Debt..................................................................

3.518.855 11 CURRENT AND ACCRUED LI ABILITIES 12 Notes Payable..............................................................................

49.931 12 13 A c co un ts P ay a b l e.....................................................

242.046 13 14 Pay abl es to As soc i a te d Comp an i es...........................................................

83.593 14 15 Re gul a tory Ba l ancing Accoun ts - Re funda b le................................................

14.915 15 16 Cu s t one r De pos i t s...................................................

13.592 16 17 TaxesAccrued...................................................................................................

187.473 17 18 I n t e re s t A c c r ue d................................................

85.737 18 19 Dividends Declared.........................................................................

81.051 19 20 Ma t u re d L on g. Te rm De b t..................................................................

1.253 20 21 Ma t u re d I r. t e re s t........................................................................... 230 21 22 T a x Co l l e c t i o n s P ay a b l e....................................................................

14.403 22 23 Mi s ce ll a neous Curren t and Acc rued Li abili ties..............................................

10.032

?3 24 To tal Cu rren t and Acc rued L i abili t ies................................................

784.256 24 DEFERRED CREDITS 25 Cus tome r Ad va nce s fo r Con s t ruc ti on.........................................................72.779 25 26 Accumul a ted De fe rred In ves tment Tax Credi ts.........................

59.863 26 27 O t he r De fe rre d C re d i t s....................................................................15.187 27 28 Un a m r t i z e d Ga i n on Re a cqui red Deb t........................................................

42.768 28 29 A c c umul a t e d De f e r re d I n come T a x e s..........................................................

30.856 29 30 T o ta l De fe r re d C re d i ts...............................................................221.453 30 31 Tota l L i abili ti es a nd Other Credi ts..............................................

$8.657.676 31

( ) Denotes Deduction t

Exhibit E

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PACIFIC GAS AND ELECTRIC COWANY sV V

INCOME STATEMENT (000 Omitted)

Three Months Twelve Months Ended Ended Line Line March 31, 1979 March 31,1979 No.

No.

UTILITY OPERATING INCOME Operating Revenues:

$540.070

$2.176.217 1

1 E l e c t r i c De p a r tme n t..................................................

2 G a s De p a r tme n t.......................................................

454,744 1.445.995 2

141 1.248 3

3 Wa te r De p a r tme n t.....................................................

973 2.916 4

4 Steam Sales Department...............................................

5 Total Operating Revenues........................................

995.928 3.626.376 5

Operating Expenses:

6 Operation Expenses...................................................

729.186 2.524.495 6

7 Maintenance Expenses.................................................

30.579 118.807 7

8 Dep re c i a t i o n E xpe n s e s................................................

58.502 224.407 8

9 Amorti z a ti on and Depletion of Utili ty Pl ant..........................

8 31 9

10 Ta xes O the r than i ncome Ta xes.......................................

29.239 117.870 10 11 Income Taxes - Federal...............................................

28.099 157.129 11 12 Income Taxes - Other.................................................

6.600 34.828 12 13 Provi s i on for De fe rred I ncome Tapes - Credi t.........................

(736)

(2.945) 13 14 Investment Tax Credi t Adjustments - Net..............................

(9.543)

(30.753) 14 15 To tal utili ty Ope ra ti ng E xpenses................................

871.934 3.143.669 15 16 Ne t U ti l i ty Dpe ra ti ng I ncome...........................................

123.994 482.507 16 OTHER INCOME AND DEDUCTIONS _

Other Income:

s 17 Nonuti l i ty Ope ra ti n g In cone.........................................

28 40 17

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18 Equi ty i n Ea rai ngs of Subsidi ary Companies..........................

7.177 22.772 18 4

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19 In te res t a nd Di vi dend In come.........................................

5.994 23.577 19 20 Allowance for Equity Funds Used During Construction..................

31.935 116.183 20 21 Miscellaneous Nonoperating Income....................................

93 283 21 22 Gai n on Di s posi ti on o f P rope rty......................................

2.079 22 23 T o ta l O the r I ncome..............................................

45.227 164.934 23 Other income Deductions:

24 Los s on Di s po s i t i c.n of P rope rty......................................

152 24 25 Mi s ce l l a neo us Amo rti z a ti on...........................................

265 25 26 Miscellaneous Income Deductions......................................

1.335 4.657 26 27 Total Othe r i ncome Deducti or.s.................................

1.335 5.074 27 Taxes Applicable to Other Income and Deductions:

28 Ta xes O the r tha n I ncome Ta xes........................................

61 274 28 29 Income Taxes - Federal...............................................

(4.933)

(21.731) 29 30 Income Taxes - Other.................................................

(1.032)

(4.410) 30 31 Inves tsent Tax Credi t Adj ustments - het..............................

108 356 31 32 T o tal Ta xe s on Othe r Income.....................................

(5.796)

(25.511F 32 33 Ne t O the r I n come a nd De d uc ti ons........................................

49.688 185.371 33 INTEREST CHARGES 34 I n t e re s t on Lo n g -Te rm De b t.............................................

64.906 251.884 34 35 Amorti za ti on of Debt Di scount and Expense..............................

420 1.640 35 (48 (153) 36 (719}

(2.347) 37 36 Amorti za ti on o f P remi um on Debt - Credi t..............................

'37 Amorti z-ti on o f Gain on Reacqui red Debt - Credi t......................

38 O the r I n te res t E x pens e.................................................

1.449 8.667 38 39 Allowance for Borrowed Funds L' sed During Construction..................

(7.984)

(31.297) 39 40 To tal I n te res t Ch a rges..........................................

58.024 228.394 40 41 Net income.............................................................

$115.658

$ 439.484 41

( ) Denotes Deduction O)

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Exhibit E D

DEPRECIATION AND FEDERAL INCOME TAXES The following statement is submitted in accordance with Rule 23(h) of the Commission's Revised Rules of Procedure which requires a statement by applicant as to which of the optional methods provided in the Internal Revenue Code applicant has elected to employ in computing the depreciation deduction for the purpose of determining its federal income tax payments, and whether applicant has used the same method or methods in calculating federal income taxes for the test period for rate-making purposes:

For financial statement purposes depreciation of utility plant has been computed on a straight-line remaining life basis at rates based on the estimated useful lives of plant properties.

For federal income tax accrual purposes the Company generally computes depreciation using liberalized methods, the 200%

declining balance method on all qualified depreciable properties, class life system including the deduction of cost of removal on a current basis, and asset depreciation range system as allowed by the Treasury Department.

In accordance with requirements of the California Public Utilities Conmission (which has ruled that for rate-making and accounting purposes federal income taxes shall be considered at the accruable actual liability) the Company has reflected in net income the current tax reductions arising from the use of such liberalized methods of depreciation. The fore-going is the method used for both income presentation and for r-+e-making purposes.

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Exhibit E

Y EXHIBIT F RESULTS OF OPERATIONS-SYSTEM r

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ALL OPERATING DEPARTMENTS b$

- REVENUES, EXPENSES, RATE BASES AND RATES OF RETURN YEAR 1978 RECORDED (000'sOmitted) e Line All Operating Line No.

Description Departments Electric No.

(A)

(B) 1 Gross Operating Revenues

$3,742,093

$2,096,788 1

Operating Expenses:

2 Production 2,306,899 1,042,786 2

3 Storage 3,248 3

4 Transmission 41,222 17,801 4

5 Distribution 171,693 115,276 5

6 Customer Accounts 87,391 49,378 6

Customer Service and 7

Informational Expense 14,109 8,632 7

8 Administrative and General 181,816 122,851 8

Total Expenses Excluding 9

Taxes and Depreciation 2,806,378 1,356,724 Taxes:

10 Property 111,073 82,970 10 11 Payroll and Business 22,419 14,842 11 12 State Corporation Franchise 29,177 23,861 12 13 Federal Income Tax 99,943 82,912 13 1

14 Total Taxes 262,612 204,585 14 15 Depreciat fon 220,105 166,724 15 16 Total Operating Expenses 3,289,095 1,728,033 16 17 Net for Return

$ 452,998

$ 368,755 17 18 Rate Base

$5,592,884

$4,217,600 18 19 Rate of Return 8.10%

8.74%-

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SERVICE OF NOTICE OF APPLICATION In accordance with Rule 24, Applicant will mail a notice to the following, stating in general terms its proposed increases in rates.

State of California To the Attorney General and the Department of General Services Counties To the County Counsel or District Attorney and the County Clerk in the following counties:

Alameda Marin Santa Clara Alpine Mariposa Santa Cruz Amador Mendocino Shasta Butte Merced Sierra Calaveras Monterey Siskiyou Colusa Napa Solano Contra Costa Nevada Sonoma El Dorado Placer Stanislaus Fresno Plumas Sutter Glenn Sacramento Tehama 1

s Humboldt San Benito Trinity

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Kern San Francisco Tulare Kings San Joaquin Tuolumne Lake San Luis Obispo Yolo Lassen San Mateo Yuba Madera Santa Barbara Municipal Corporations To the City Attorney and the City Clerk of the following municipal corporations:

Alameda Atherton Brentwood Albany Atwater Brisbane Amador Auburn Purlingame Anderson Bakersfield

.alistoga Angels Belmont Canpbe ll antloch Belvedere Capitola Arcata Benicia Carmel

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Arroyo Grande Berkeley Chico 1

Arvin Blue Lake Chowchilla Exhibit G i

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Cloytm, Islston Paso Robles Cloverdcle Jcckson Pattersun Clovis Kerman Petaluma Coalinga Kings City Piedmont Colfax Kingsburg Pinole Colma Lafayette Pismo Beach Colusa Lakeport Pittsburg Concord Larkspur Placerville Corcoran Lemoore Pleasant Hill Corning Lincoln Pleasanton Corte Madera Live Oak Plymouth Cotati Livermore Point Arena Cupertino Livingston Portola Valley

~

Daly City Lodi Red Bluff Davis Lompoc Redding Del Rey Oaks Los Altos Redwood City Dinuba Los Altos Hills Reedley Dixon Los Banos Richmond Dos Palos Los Gatos Rio Del El Cerrito Madera Rio Vista Emeryville Manteca Ripon Escalon Maricopa Riverbank Eureka Martinez Rocklin Fairfax Marysville Rohnert Park Fairfield McFarland Roseville Ferndale Mendota Ross Firebaugh Menlo Park Saint Helena Folsom Merced Salinas Fort Bragg Millbrae San Anselmo Fortuna Mill Valley San Bruno Foster City Milpitas San Carlos Fowler Monterey San Francisco Fremont Monte Sereno San Joaquin Fresno Moraga San Jose Gilroy Morgan Hill San Juan Bautista Gonzales Morro Bay San Leandro Grass Valley Mountain View San Luis Obispo Greenfield Napa San Vateo Gridley Nevada City San Pablo Grover City Newark San Rafael Guadalupe Newman Sand City Gustine Novato Sanger Half Moon Bay Oakdale Santa Clara Hanford Oakland Santa Cruz Hayward Orange Grove Santa Maria Healdsburg Orland Santa Rosa Hercules Oroville Saratoga Hillsborough Pacifica Sausalito Hollister Pacific Grove Scotts Valley Huron Palo Alto Seaside Ione Parlier Sebastopol 9

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Selma Taft Watsonville i

Shafter Tehama Wheatland Soledad Tiburon Williams Sonoma Tracy Willits Sonora Trinidad Willows South San Francisco Ukiah Winters i

Stockton Union City Woodland i

Suisun City Vacaville Woodside Sunnyvale Vallejo Yountville Sutter Creek Walnut Creek Yuba City

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