ML19322C484
| ML19322C484 | |
| Person / Time | |
|---|---|
| Site: | Diablo Canyon, Crane  |
| Issue date: | 06/06/1979 |
| From: | Della Santa B, Furbush M, Ohlback R PACIFIC GAS & ELECTRIC CO. |
| To: | |
| References | |
| TASK-TF, TASK-TMR NUDOCS 8001170813 | |
| Download: ML19322C484 (80) | |
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N O
BEFORE THE PUBLIC UTILITIES COMMISSION OF THE
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STATE OF CALIFORNIA
)L FTLED Application of PACIFIC GAS AND ELECTRIC COMPANY for >
JUN 61979 Authority To lastitute An Adjustment Procedure For Unit 1 APPLICATION Nos.1 And 2 At Diublo Conyon Nuclear Generoting Station 1 NO. 5 8 9 1 1 And To Adjust its Rates in Accordonce Therewith.
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(Electric)
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APPLICATION q-Malcolm H. Forbosh.
Robert Ohlboch
- A Bernard Dollo Santo 77 Beale Street -
San Francisco, Califormio 94104 -
Attorneys for PocNic Gas
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. and Electric Company pi%d (& 95#
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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 Institute An
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5 Adjustment Procedure For Unit Nos. 1
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APPLICATION And 2 At Diablo Canyon Nuclear Generat- )
6 ing Station And To Adjust Its Rates
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NO.
In Accordance Therewith.
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7 (Electric)
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8 9
10 PACIFIC GAS AND ELECTRIC COMPANY (PGandE) respect-11 fully requests authority for an adjustment procedure with a 12 balancing account to enable PGandE to adjust its electric 13 base rates to reflect the costs of owning, operating, and
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14 maintaining nuclear Unit Nos. 1 and 2 at Diablo Canyon when 15 the units become commercially operative.
At the same time, 16 PGandE by separate application proposes to make effective an 17 Energy Cost Adjustment Clause (ECAC) reduction reflecting a 18 corresponding decrease in the amount of low sulfur fuel oil 19 for power plant operations that will occur as Diablo generation 20 replaces such oil generation.
This decrease will essentially 21 offset the base rate increase.
22 It is expected that Diablo Canyon Unit No. 1 will 23 become commercially operative during the latter part of 24 1979.
If that date for Unit No. 1 is Deceraber 1, 1979, the 25 base rate adjustment will amount to an increase of 0.2743 r~s i
(,)
26 cents per kilowatt hour on jurisdictional sales for the
1 first 12 months of operation, which amounts to an increase 2
of about $155.7 million, or 6.7 percent, annually.
If Unit 3
No. 2 becomes commercially operative on August 1, 1980, the O
adjustment for Unit No. 2 will be an increase of 0.2102 4
5 cents per kilowatt hour for the first 12 months of its 6
operation, which amounts to about $122.4 million, or 5.1 per-7 cent, annually.
Electric power generated from Diablo Canyon 8
will be less expensive to produce than that generated by the 9
conventional steam electric plant which burns fuel oil.
The 10 first unit of the plant, operating at 65% capacity factor, 11 will produce electric power at approximately 33 mills per 12 kilowatt hour which will be the lowest cost of any thermal 13 plant on PGandE's system.
For the second unit, the cost 14 will be approximatley 27 mills per kwh.
The reduction in 15 PGandE's cost of fuel for electric generation which will 16 occur when the Diablo units become commercially operative 17 will approximately offset the base rate increase through 18 ECAC reductions.
19 If Diablo Unit No. 1 becomes operative prior to 20 December 1, 1979, or if authorization of a rate adjustment 21 is delayed beyond the expected dates of commercial operation, 22 PGandE requests authority to include all appropriate costs 23 associated with Diablo Canyon and its operation in the 24 proposed balancing account.
Related energy cost reductions 25 will be inclu6ed in the existing ECAC balancing account.
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2 BACKGROUND 3
On December 23, 1966, PGandE filed Application No.
4 49051 requesting the Commission to find that the public 5
convenience and necessity required the construction of Unit 6
No. 1 at Diablo Canyon.
After 20 days of hearings, the 7
Commission issued Decision No. 73278 authorizing construction 8
of Unit No. 1.
On February 16, 1968, PGandE filed Application 9
No. 50028 requesting the Commission to issue a Certificate 10 of Public Convenience and Necessity for Unit No. 2.
The 11 Commission granted PGandE's request in Decision No. 75471 on l
12 March 25, 1969.
Since that time, PGandE has gone through
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13 many years of regulatory proceedings at all levels of local,
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14 state, and federal government to obtain the necessary permits 15 and licenses to operate the Diablo Canyon plant.
Final 16 hearings before the Atomic Safety and Licensing Board ( ASLB) 17 on.the issuance of operating licenses began in December 1978 18 and concluded on February 15, 1979.
19 II 20 REASONS FOR ESTABLISHING DIABLO CANYON RATE BASE OFFSET PROCEDURE 21 i
22 In Decision No. 86281, the Commission declined to e
23 include construction work in progress (CWIP) in rate base.
24 It recognized, however, that timely inclusion in rate base 25 of significant additions to plant was a subject not well
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26 suited to current ratemaking procedures.
The Commission, -
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therefore, proposed that the addition of Diablo Canyon be 2
considered in conjunction with an ECAC proceeding at the 3
appropriate time.
4 Due to the uncertainty surrounding operating dates 5
and the Commission's desire to handle Diablo Canyon in a 6
separate proceeding (Decision No. 86281), the 1978 and 1980 7
test year general rate cases excluded Diablo Canyon.
8 The Diablo Canyon units will add about 37% to 9
PGandE's estimated 1973 electric system rate base with 10 corresponding increases in return requirement, taxes, depre-11 ciation, maintenance, and operating expense.
It is 12 therefore critical that an adjustment procedure with a 13 balancing account and associated rate adjustments be approved.
14 If rates to offset this electric rate base increase are not 15 approved, PGandE's rate of ceturn on equity would be reduced 16 from 12.83% to approximately 8.69% by the addition of Diablo 17 Unit 1 and to 6.33% by the further addition of Unit 2.
18 The base rate adjustment requested in this e
17' application will be approximately offset by an ECAC reduction 20 resulting from the difference in fuel cost between conven-21 tional fossil fuels (about 26.6 mills per kwh with fuel oil 22 at $17 per bbl) ano nuclear fuel (about 6.2 mills per kwh).
23 In the interest of late stabilization, it is requested that 24 the base rate increase and offsetting ECAC reduction be 25 implemented concurrently.
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III 2
STATEMENT OF RELIEF SOUGHT 3
PGandE proposes that a base rate adjustment proce-4 dure be included in its tariffs which includes a balancing 5
account in accordance with Section 792.5 of the Public 6
Utilities Code to reflect the addition to rate base of Unit 7
Nos. 1 and 2 at-Diablo Canyon with associated owne. ship, 8
maintenance, and operating costs.
9 PGandE proposes that the adjustment procedure and 10 balancing account be authorized at the earliest possible 11 date, so that when Diablo Unit 1 becomes commercially opera-12 tive PGandE will be able to accumulate the actual base rate r"'g 13 costs.
PGandE also proposes that rate adjustments under the
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14 proposed adjustment procedure become effective upon the 15 dates of commercial operatiLn for Diablo Unit 1 and Unit 2, 16 respectively, concurrently with offsetting fuel cost related 17 ECAC rate reductions.
18 The base rate balancing account will accumulate 19 costs associated with operation of the plant commencing with 1
20 the date of commercial operation.
Revenues from the adjust-21 ment rate will flow to the balancing account.
The account l
22 will be used to reflect the differences in revenues generated l
23 by the authorized rates and recorded revenue tequirements to 24 assure a proper matching of revenues and corresponding 25 costs.
Exhibit A, attached, sets forth the proposed adjustment
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1 procedure and balancing account and lists the items to be 2
included in the balancing account.
3 Diablo Canyon adjustment rates will be reviewed 4
one year after Unit No. 1 becomes commercially operative and 5
annually thereafter until the adjustment procedure can be 6
integrated into a general rate proceeding.
PGandE belleves 7
that this procedure will assure equitable treatment 'br both 8
customers and PGandE.
9 IV 10 DIABLO CANYON ADJUSTMENT RATES 11 Unit No. 1 at Diablo Canyon is expected to commence 12 commercial operation in the latter part of 1979.
The rate 13 adjustment necessary if that date is December 1, 1979, is 1G based on a plant cost of approximately $907 million.
The 15 cost of Unit No. 2 if it becomes commercially operative on 16 August 1, 1980 is expected to be approximately $736 million.
17 As shown in Exhibit B, attached, the rate adjust-18 ments that would be made to offset the base costs of Diablc 19 Canyon Unit 1 and Unit 2 coming into commercial operation on 20 the above dates are 0.2743 cents per kwh and 0.2102 cents 21 per kuh, respectively.
If Diablo Unit I were to be com-22 mercially operative earlier than December 1, 1979, the 23 related base costs would be accumulated in the balancing 24 account until the adjustment rates were made effective.
25 For illustrative purposes, PGandE is also showing 26 the base rate adjustments that would be required to offset lll
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base cost increases if Diablo Unit 1 and Unit 2 become 2
commercially operative on February 1, 1980, and October 1, 3
1980, respectively.
As shown in Exhibit C, the corresponding 4
adjustment rate increases would be 0.2790 cents per kwh for 5
Unit 1 and 0.2147 cents per kwh for Unit 2.
6 At a 65% capacity factor, Diablo Canyon Unit No. 1 7
will generate 6,172,296 Mkwh per year.
As shown in Exhibit D, 8
attached, the nuclear fuel cost savings with the cost of oil 9
at $17.00 per barrel is.2049 cents per kwh which is.0694 10 cents lesu than the base rate adjustment of.2743 cents 11 per kwh as shown on line 4 of Exhibit B.
Assuming the cost 12 of oil to be $21.50 per barrel, the nuclear fuel cost savings
(~%
13 averages.2752 cents per kwh which is.0009 cents per kwh
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14 more than the base rate adjustment of.2743 cents per kwh.
15 With both units on line, the nuclear fuel cost savings with 16 oil at $17.00 per barrel would be about.403 cents per kwh 17 compared to the base rate adjustment of.485 cents per kwh.
18 With oil at $21.50 per barrel, the comparison would be 19
.541 cents per kwh for nuclear fuel and.485 cents per kwh
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20 for the base rate adjustment.
21 Under the assumptions set forth in Exhibit D, the 22 net result of revenues from base rate increases and ECAC 23 rate reductions, with fuel at $17.00 per barrel, would be a 24 net increase of approximately $31 million in revenue require-25 ments for the first 12 months of simultaneous operation of
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26 the two units at 65% capacity factor.
PGandE proposes to v
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1 offset the base rate increases exactly with corresponding 2
ECAC reductions.
3 Exhibit E, attached, includes each of PGandE's 4
Present rates for electric service which are proposed to be 5
changed.
PGandE proposes that the base rate adjustment be 6
applied to all jurisdictional sales, including lifeline 7
amounts.
8 The proposed increase when spread to jurisdictional 9
sales, including lifeline usage, results in $0.002743 per 10 kilowatt hour increase for Unit No. 1 and $0.002102 increase 11 for Unit No. 2.
The effect of the increase for the first 12 12 months of operation on classes is as follows:
13 COMMERCIAL OPERATION DATES OF DECEMBER 1,
- 1979, FOR UNIT 1 AND AUGUST 1, 1980, FOR UNIT 2 10 Class of Service Revenue Increase Percent 15 (000's) 16 Unit No. 1 Unit No. 2 Unit 1 Unit 2 17 Residential
$ 51,332
$ 40,609 7.3 5.6 Small Light and Power 12,749 9,885 5.1 3.9 18 Medium Light and Power 36,490 28,936 6.1 4.6 Large Light and Power 41,118 32,293 7.4 5.6 19 Public Authoriti 1,654 1,287 7.0 5.4 Agricultural 10,207 7,798 6.4 4.5 20 Street Lighting 1,130 799 3.9 3.0 Railway 686 526 8.2 6.3 21 Interdepartmental 392 305 6.0 4.6 Total Jurisdictional
$155,758
$122,438 6.7 5.1 22 23
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1 COMMERCIAL OPERATION DATES OF FEBRUARY 1,
- 1980, FOR UNIT 1 AND OCTOBER 1, 1980, FOR UNIT 2 2
Class of Service Revenue Increase Percent 3
(000's) 4 Unit No. 1 Unit No. 2 Unit 1 Unit 2 5
Residential
$ 52,590
$ 41,826 7.5 5.7 Small Light and Power 13,015 10,125 5.2 4.0 6
Medium Light and Power 37,400 29,841 6.2 4.7 Large Light and Power 42,079 33,183 7.5 5.8 7
Public Authority 1,691 1,318 7.1 5.5 Agricultural 10,379 7,950 6.5 5.0 8
Street Lighting 1,127 799 4.0 3.1 Railway 698 537 8.4 6.4 9
Interdepartmental 399 313 6.1 4.7 Total Jurisdictional
$159,378 3125,892 6.8 5.2 10 11 The above increases are for the base rate adjustment 12 only.
The offsetting effect of the decrease in ECAC rates
/~T 13 from the reduction in PGandE's cost of fuel for electric
(.) 14 generation due to the operation of Diablo Canyon is shown in 15 the preceding paragraphs and Exhibit D.
16 y
17 RESULTS OF OPERATIONS UNDER PRESENT AND PROPOSED RATES 18 19 Exhibit F, attached, shows PGandE's Electric
-20 Department Results of Operations as adopted by this Commis-21 sion in Decision No. 89316, dated September 6, 1978, at 22 present rates and at the base rates proposed for December 1, 23
_1979, and August 1, 1980, if Diablo Unit Nos. 1 and 2 are 24 commercially operative on these dates.
Also shown are 25 results based on commercial operation dates for Unit 1 of
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1 February 1, 1980, and for Unit 2 of October 1, 1980, using 2
the same data based on the estimated 1980 test year.
3 VI 4
TYPE OF INCREASE SOUGHT 4
5 The proposed rate adjustment in this application 6
reflects and passes through to PGandE's customers the effect 7
of increased costs to PGandE for the addition of Diablo 8
Canyon Unit Nos. I and 2 to rate base.
The decreased fuel 9
costs for the electricity furnished to its customers produced 10 by this plant are reflected in the ECAC as set forth in the 11 companion application filed herewith.
12 VII 13 COMPLI ANCE WITII TiiE VOLUNTARY PRICE GUIDELINES 14 15 The guidelines issued by the Council on Wage and 16 Price Stability are effective only through September 30, 17 1979.
At this time, PGandE does not know whether these 18 guidelines will be extended, modified or eliminated.
There-19 fore, PGandE will, at the time the Diablo offset is scheduled 20 to become ef fective, advise the Commission of the impact of 21 this request relative to any then-existing guidelines.
22 PGandE wishes to point out, however, that the offset request 23 contained herein is expected to have no net effect on customers' 24 rates in any event since a decrease in the ECAC rate of an 25 equal amount will occur simultaneously.
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VIII 2
PACIFIC GAS AND ELECTRIC COMPANY 3
PGandE is, and ever since October 10, 1905, has 4
been, an operating public utility corporation, organized S
under California law.
It is engaged principally in the 6
business of furnishing electric and gas service in California.
7 It also distributes and sells water in some cities, towns 8
and rural areas, and produces and sells steam in certain 9
parts of San Francisco.
10 PGandE's principal place of business is in San 11 Francisco, California.
Its post office address is 77 Beale 12 Street, San Francisco, California 94106; its telephone
s 13 number is 781-4211; and its attorneys in this matter are 14 Malcolm H. Furbush, Robert Ohlbach, and Bernard J. Della Santa.
15 Communications regarding this application are to 16 be addressed to Malcolm H. Furbush at the above-mentioned 17 address.
18 A certified copy of PGandE's Articles of Incorpo-19 ration, amended to the date of this application, is of 20 record before the Commission in connection with PGandE's 21 Application No. 56435, filed April 27, 1976, and these 22 Articles are incorporated herein by reference.
12 3 Attached as Exhibit G are a balance sheet and a 24 income statement indicating PGandE's financial status as of 25 March 31, 1979.
A statement of the method of computing the (3-v) 26
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1 depreciation deduction for federal income tax purposes is 2
also included.
3 Exhibit H, attached, shows for the year 1978 the 4
revenues, expenses, and rate of return, on a depreciated 5
basis, for all of PGandE's operating departments and for its 6
Electric Department.
7 The original cost of PGandE's electric properties, 8
together with the applicable depreciation reserve, consistent 9
with Exhibit H, is as follows:
10 Total Electric Plant
$5,773,748,000 11 Operative Construction Work in Progress 4,285,000 12 Total Operative Plant 5,778,033,000 Depreciation Reserve 1,741,729,000 14 15 A more detailed description of PGandE's electric 16 properties and equipment is included in PGandE's exhibits 17 filed with Application No. 58545, filed December 26, 1978, 18 which are incorporated herein by reference.
19 Incorporated by reference herein is a copy of 20 PGandE's most recent proxy statement sent to its shareholders.
21 This proxy statement was filed with the Commission by PGandE 22 in Application No. 58798 on April 10, 1979.
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IX 2
STATUTORY AUTHORITY 3
This application is made pursuant to Sections 451, 4
454, 491 and 701 of the Public Utilties Code of. the State of 5
6 X
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 base rate 11 adjustment procedure and rate adjustment is attached as 12 E::hibit I.
The State of California is the only state affected e-13 by the proposal.
Within ten days after filing this applica-k'S) 14 tion, notice as provided in Rule 24 will be mailed to the 15 appropriate officials of all of the foregoing entities, to 16 the parties of record in PGandE's ECAC filing of April 28, 17 1978, Application No. 58033 and in PGandE's pending general 18 rate case, Application No. 58545.
Notices will also be 19 included with the regular bills mailed to all customers 20 affected by the proposed adjustment.
21 XI 22 ACCOMPANYING EXHIBITS 23 PGandE's exhibits and prepared testimony in support 24 of this application accompany this filing with the Commission.
25 PGandE is now ready to proceed with its showing in (ey\\s) support-of this application.
26 _,.
1 WHEREFORE, PACIFIC GAS AND ELECTRIC COMPANY respect-2 fully requests the Commission to issue appropriate orders:
3 1.
Authorizing PGandE at the earliest possible 4
time to place into effect the proposed base rate adjustment 5
procedure and balancing account set forth in Exhibit A for 6
Unit Nos. 1 and 2 at the Diablo Canyon Nuclear Generating 7
Station.
8 2.
Authorizing PGandE on the commercially operative 9
date of Unit No.1 at Diablo Canyon Nuclear Generating 10 Station to file and place into effect the base rate adjustment 11 necessary to offset the related increases in base costs set 12 forth in Exhibit B, attached.
13 3.
Authorizing PGandE on the commercially operative 14 date of Unit No. 2 at Diablo Canyon Nuclear Generating 15 Station, to file and place into effect a base rate adjustment 16 necessary to offset the related increases in base costs set 17 forth in Exhibit B, attached.
18 4.
Finding that the base rate adjustment procedure 19 and the resulting adjustment rates are fair, reasonable, and 20 justified.
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24 25 OQ,)
1 5.
Granting PGandE such further and different 2
relief as the Commission may find to be proper.
3 Dated at San Francisco, California, this 6th day 4
of June 1979.
5 6
STANLEY T.
SKINNER Executive Vice President 7
8 MALCOLM H.
FURBUSH MALCOLM H.
FURBUSH 9
10 ROBERT OHLBACH ROBERT OHLBACH 11 12 BERNARD J. DELLA SANTA BERNARD J. DELLA SANTA
(g 13
(_s/
Attorneys for 14' PACIFIC GAS AND ELECTRIC COMPANY 77 Beale Street 15 San Francisco, California 94106 16 j
17 18
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22 23 24 1
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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 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 13 day of June 1979.
14 15 16 STANLEY T. SKINNER Executive Vice President 17 18 19
-20 21 22 23 24 25 I 'T 26
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k.I F
EXHIBIT A PROPOSED ADJUSTMENT PROCEDURE a
O Exhibit A PRELIMINARYSTATEMENT(Continued)
PART D Diablo Canyon Adjustment Clause (DCAC)
No. 1 -
Purpose:
The purpose of this DCAC provision is to reflect in rates pursuant to Section 792.5 of the Public Utilities Code any accumulated difference between the actual costs of owning and oper-ating Diablo Canyon Power Plant and revenues resulting from the rates authorized by the California Public Utilities Comission (CPUC) for that purpose. Associated fuel costs will be reflected in the Energy Cost Adjustment Clause of this tariff. It is intended that this DCAC provision be temporary until base rates become effective which fully include the cost of owning and operating Diablo Canyon Power Plant and until any accumulated difference is amortized.
No. 2 - Applicability:
This DCAC provision applies to all rate schedules and contracts for electric service
/G subject to the jurisdiction of the CPUC, except (a) for sales for which payment is made in fuel
(
)
and (b) for sales to the California Department of Water Resources under present contracts. The DCAC provision does not apply to usage under Schedules Nos. D-40 and A-41.
No. 3 - DCAC Rate Revision:
The Utility shall file with the CPUC a new or revised DCAC Rate hereunder to become effective twelve months after this provision first becomes effective, and subsequently at twelve month intervals. When base rates become effective which fully include the costs of owning and operating Diablo Canyon Power Plent, entries under 5(b) of the Diablo Canyon Adjustment Account shall be pro-rated to the date suh rates become effective and shall be discontinued with respect
'to subsequent periods and a filing of the DCAC Rate to amortize the balance in the Account shall be made.
No. 4 - DCAC Rates:
The amount hereunder to be added to or subtracted from each bill for electric service shall be the product of the total kilowatt hours for which the bill is rendered multiplied by the DCAC Rate. The DCAC Rate, to become effective for service on and after the date of each DCAC Rate Revision and continuing thereafter until the next succeeding DCAC Rate becomes effective, shell be the algebraic sum of a DCAC Offset Rate and a DCAC Balancing Rate, except that the initial DCAC Rate shall consist only of the DCAC Offset Rate. The DCAC Balancing Rate shall be a positive or negative amount per kilowatt hour of sales necessary to amortize the accumulated balance in ths Diablo Canyon Adjustment Account. The DCAC Balancing Rate shall be determined by dividing (1) the balance in the Diablo Canyon Adjustment Account at the end of the latest available month at the time of the computation being made under the provisions hereof, by (2) the kilowatt hours estimated
.to be sold during the 12 month period beginning with the date of the next succeeding DCAC Rate Revision. The DCAC Offset Rate is per kilowatt hour.
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No. 5 - Diablo Canyon Adjustment Account:
Commencing on the date that Diablo Canyon Power Plant becomes commercially operative or the date that DCAC Rates first become effective, whichever is sooner, the Utility shall maintain a Diablo Canyon Adjustment Account as a subaccount in CPUC Accounts Nos. 174 and 242. Entries shall be made to this account at the end of each month as follows:
(a) A credit entry equal to, if positive (debit entry, if negative), the amount of revenue billed during the month under the DCAC Rate (not including the adjustment for franchise and uncollectible accounts expense).
(b) A debit entry equal to, if positive (credit entry, if negative):
(1) Alloperation, maintenance,andinsurance, injuries,anddamagesexpenses(CPUC Accounts Nos. 517 through 532, 560 through 567, 924, and 925) at Diablo Canyon Power Plant (PGandE Locations Nos. 40 and 140) excluding fuel expenses debited to the Energy Cost Adjustment Account, plus (2) Depreciation expense and return on investment on the average of the beginning and end of month balance of nuclear production, transmission, and general plant (CPUC Accounts Nos. 320 through 325, 350 through 359, and 389 through 399) at Diablo Canyon Power Plant (PGandE Locations Nos. 40 and 140) at one-twelfth the annual depreciation rates approved by the CPUC for those accounts and at one-twelfth of the annual rate of return on investment last adopted for the Utility's electric department by the CPUC, respectively, plus such return on the average of beginning and end of month net investment in nuclear fuel (net balance in CPUC Accounts Nos.
120.2 through 120.5) at Diablo Canyon Power Plant (PGandE Location No. 40) and prepaid nuclear fuel, minus such return on the average of beginning and end of O
month accumulated depreciation and deferred investment tax credit directly v
attributable to Diablo Canyon Power Plant nuclear production, transmission, and general plant and nuclear fuel, plus (3) Taxes chargeable to CPUC Account No. 408.1. Taxes other than income taxes, utility operating income, on or related to plant set forth in item 5(b)(2) above in the month in which such taxes are actually paid, minus (4) Any direct rents or other revenue received, other than from sale of electricity, associated with ownership or operation of Diablo Canyon Power Plant or its fuel, other than amounts credited to CPUC Account No. 120.5, plus (5) Federal, state, and local taxes based on income associated with items 5 (b)(1),
(b)(2), (b)(3) and (b)(4) above, calculated at marginal tax rates currently in effect, including all available statutory adjustments and flowthrough of differ-ences between tax and book depreciation and fuel expenses, with interest cost 4
at 3.55% of net investment, and with five-year average investment tax credit.
(c) A debit entry equal to 7/12 percent of the average balance in this account and the balance in this account after entries 5(a) and 5(b) above, if average balance is debit (credit entry if average balance is credit).
(d) It is intended that this account reflect only the balances to be amortized by rates for l
sales to which the DCAC Rate applies. For the purpose of determining entries to the Diablo Canyon Adjustment Account, items 5(b)(1), (2), (3) and (4) and the appropriate determinants of item 5(b)(5) above in any month shall be pro-rated to applicable jurisdictional sales by multiplying the respective amounts by 0.93.
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EXHIBIT B 5
RATE ADJUSTMENT
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DECEMBER 1,1979
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Exhibit B PACIFIC GAS AND ELECTRIC COMPANY
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DIABLO CANYON ADJUSTMENT COMPUTATION OF 0FFSET ADJUSTMENT Unit No.1-Comercial Operating Date-December 1,1979 Unit No. 2-Comercial 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
$M Adjustment (Line 2.743 3 + Line 2) Mills per Kwh Unit No. 2 Total System CPUC Jurisdictional 1.
Sales - M Kwh 63,195 60,291 2.
Sales adjusted for DWR etc. M Kwh 58,236 3.
Revenue Requirement-131,622 122,438
$M Adjustment (Line 2.102 3 + Line 2) Mills per Kwh Sales Adjusted for Department of Water Resources, DS, DE and DT.
O v
EXHIBIT C RATE ADJUSTMENT FEBRUARY 1,1980 o
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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-Coninercial Operating Date-October 1,1980 Unit No. 1 Total System CPUC Jurisdictional 2
1.
Sales - M Kwh E1,959 59,212 2.
Sales adjusted for DWR, etc. M Kwh 57,120 3.
Revenue Requirement-171,331 159,378
$M Adjustment (Line 2.790 3 + Line 2) Mills per Kwh 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 Requirenent-135,341 125,898
$M Adjustment (Line 2.147 3 + Line 2) Mills Mr Kwh Sales Adjusted for Department of Water Resources, DS, DE and DT.
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ESTIMATE OF FUEL SAVING l
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Exhibit D Diablo Canyon Adjustment Estimate of Fuel Saving Unit No.1 Commercial Operating Date December 1,1979 Unit No. 2 Commercial Operating Date August 1, 1980 Annual Annual Annual Generation Fuel Differential Fuel System Fuel Saving Capacity 65% C.F.
Oil-Nuclear Saving Sales Mills per KW MKwh Mills per Kwh MKwh Kwh of Sales With Oil at $17.00 per bb1 (26.F, mills per kwh) and Nuclun at 6.2 mills per kwh Unit No. 1 1,084,000 6,172,296 20.4 125,915,000 61,458,000 2.049 Unit No. 2 1,106,000 6,297,564 20.4 128,470,000 63,195,000 2.033 With 011 at $21.50 per bbl (33.6 mills per kwh) and Nuclear at 6.2 mills per kwh Unit No. 1 1,084,000 6,172,296 27.4 169,121,000 61,458,000 2.752 Unit No. 2 1,106,000 6,297,564 27.4 172,553,000 63,195,000 2.730
EXHIBIT E PRESENT RATES l
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98-eeee Ise.la Pacide Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7059 E
/,_h San Franciseo, California Canceling Revised Cal. P.U.C. Sheet No. 7055.E
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v TABLE OP CONTENTS The fellowing listed tas.2 shoots contata the preliminary statement, all afective rates, rules and regulatione and sample fort a afecting rates and servies and information relating thereto in efect on and arter the date ladseated heroes:
Cet P U.C Sham No.
Thie Pepe 44 40-E TeWe et
7059 E TeWe of Comesmer--Schedule of P='-
7059 7058 E TeWe of Conannie-Contracts and Deviatjona 7058 E TeWe of Comeneer-Ra!==
7058-E TeWe of r*hple Por==
7022 7021 E Prelladsery Samwa Part A (1) Territory Served by Company 6856 E (3) Desertation of Service 6282-E (8) Procedure te Obtata Servta=
6282 E (4) metablishment of Credit and Deposte=
628* E (5) Oeaeral 6857-E (8) Servies la Citfee and Towne Not Generally Served by the Utility 6857 E (7) Symbof=
6857 E Part 8-Energy Cent Adj--
7005-69644965 7032 E PartC-Tax Cheese Adjusement Genee 6822 E Surv4co Area Mar 4513-64 DM E24-452H671-4672-4674-E u-Dem Rees Area Afep 4119 E D
SCHEDULE OF RATES j
Schasiale Cel. P U.C No.,
Title of Shase_
Shane No.
w GENERAL SERVIG A1 General Service
. 7033 E A 13 General Service-Demand Metered _.
70344006-E A 18 General Service-Demand Meterv.
7035-E A.16 General Service-Direct Curren' 7036 E A 18 Interruptible Primary Industrial Power 7017 6012 E A 23 General Service-Time Metered 7038 6564-E A-41 General Power Servios -
6746-4725-E 01,1 Outdoor Area Lightin!
7039 6750 E l
DOMESTIC SERVIG f
D1 Domeette Service 7040-7007-E D.40 Domeetle Service 7006-7009 E l
DE Service to Company Bunploy-4739 E DM Mattt Family Servie 70417010 E DS Multi-Family Servloe.
704* 7011 E l
DT Multi Family Service-Mobilehome Park 70436996 E F11EKT AND HIGHWAY IJGef!1NG Ls.1 Street and Highway Lighting 704 4-6872-6873 E IA 3 Street and Highway Lighting 7012 7045-6876 E IA.a Street and H!ahway Lighttag-Electroller Meter Rate 7046 6878 E TO1 Traffle Control Servlee 7047 E POWER SERYME P3 O!! ReSnory Electric and Steam Servica 7043-6959 E PA 1 Agricultural Power 70494043 E 51 Stand-by Servlee 7050 6972-6973 E (qv)
(continued) v Advice Letter No. 735-E Issued by Date Filed Aoril 13, '19N Decision No.
W. M. Gallavan
!. 4 - Efective Mav 15. 1979. a Vice-President-Rates and Valuation
. Resol.!!on p463P!IMt itU h$
EMDb E-1
ees Pacifle Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7058-E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 7054.*
O TABLE OF CONTENTS (Continued)
SCHEDULE OF RATES (Continued)
EXPERIMENTAL SERVICE i
Schedule ceL P.U.C.
No.
Tide of Sheet sheet No.
A 20A Experimental General Service. Demand Metered -
6902-6903 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 6908 6909-E AD Experimental Non-Domestic Load Deferral Service 7051 E DA Experimental Domestic Air Conditioning Load Deferral Service 7066 E DC Experimental Domest!c Contro!!ed Load Service 7057 E PA1X Experimental Agricultural Power. Time Varying 7053-6700 E CONTRACTS AND DEVIATIONS Tide of Sheet Cat. P.U.C. Sheet No.
List of Contracts and Deviation =
6686-6763-67644687 4975-6688 66?9-6176 6177-6690-6691469246934694-676547f 6-6767 6699-676S-6700-6769-677047716772-6960 6774 6707-67084775 E m
RULES Rule Cal P.U.C.
No.
Tide of Sheet Sheet No.
1 Definitions 6805 E 2
Description of Service 4954 2646 2755 2756-10674912 E 3
Application for Service 6276 E 4
Contracts 1069-E 5
SpecialInformation Required on Forms 6755 E 6
Establishment and Re-establishment of Credit 6756-E l
7 Deposits 6185 E 8
Notices 1073 E l
9 Rendering and Payment of B111s 4346-E 10 Disputed Bills 6757 E 11 Discontinuance and Restoration of Service 6758 67694760 E 12 Rates and Optional Rates.
1077 E 13 Temporary Service 3196-E 14 Shortage of Supply e.nd Interruption of Delivery 1079 E 14.1 Prohibitions and Curtallment Provisions 6938-6939 E 15 Line Extensions 3175-5788-53114789-4889-4890-3197 E 15.1 Underground Extensions Within 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 4375-4379-4380-43314382 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 Facilitle=
6915-6229 E (continued) m Advice Letter 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-103 /
3
u.au ao. m Pacias Gas and Electric Company R vivd Cal. PXU. Sheet No. 6963-E San Fransasso, California Canceling itevised Cal. P.U.C. Sheet No. 6437 E O.
PRELIMINARY STATEMENT (Continued)
PART B Energy Coet Adjustment 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 baa rates are the rates for electric service erective on the eNective date hereof.
3.
Base Weighead Rare for Fuel and Purchased Energy The base weighted rate for fuel and purchased energy included in Base Rata is $0.00000 per kilowatt @our.
4.
Record Period The volumes of fuel and energy to be used hereunder for the Record Period are those actually 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 Bling date occurs.
5.
Revision Detes The Revision Dates are July 1 and January 1 of each year. On such dates or as soon thereafter as the Co'nmission may authorize, the Utility shall, in ac-oordance with the provisions hereof, place into efect an increase or decrease in the Adjustment Rate then in efect to redeet chantres in the average cost of fuel and purchased energy and the Eureka Energy fuel service charge for G,--
projecta approved by the California Public Utilities Con'minsion. Unlena otherwise authorized or ordered by the Commission, such increases or de.
creases shall be made not more than twice in any calendar year.
6.
Adjustment Race The amount hereunder to be added to or subtracted from each bill shall be the product of the tcts! kilowatt hours for which the billis rendered multi-plied by the Adjustment Rate. The Adjustment Rate, to become efective for service on and after each Revision Date and continuing thereafter until the next Adjustment Rate becomes edective in accordance herewith. shall be the algebraic sum of an Ofset Rate and a Balancing Rate, each multiplied by 1.01 (to adjust for franchise and uncollectible accounta expense) and carried to the nearest 30.00001 per kilowatt hour. The Adjustment Rate applicable to each rate schedule will be set forth on that rate schedule.
(a) The Ofset Rate shall be the diference between the Current Fuel and Parchased Energy Cost per kilowatt hour of sales, and the Base Weight-ed Rate for Fuel and Purchased Energy, :s set forth in Section 7 below.
l 1
l See last page for footnotes.
l (continued)
(O' (i
Advice Letter No. 712-E lanued by Date Filed December 8, 1978 Decision No. 38121 W. M. Gallavan Efective December 28, 1978 Vice-President-Rates and Valuativu Resolution No.
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,,o. m Pacific Gaa and Electric Company H the.1 t.d. P i.C. Sheet No. 6 mil E San Freneisco, California i
. h e.c Rcu.ed e.d P.f ~ r Sheet No. 61* 1:
O PRELIMINARY STATEMENT (Continued)
PART H (Continued) 6.
Adjustment Rate (Continued)
(b) The h!ancine Itate shall be an anmuro p. r Ldonate hour ni -a h, en.
essary to amortize the accumulated balance in t he Energy t bt.\\ dj u st ment Account, included as a subarcount in CPf Y.\\ecounts No,. lu.
and 53. The procedures for determm ne th.. I:.dancme her arnt for maintanone the Ener;'y Cost.\\djustme'o.\\ccount are set fort h m Src tiorw 9 :ind 10 be!ow.
(c) The rates determined above shall be f ur ther ad visted to reHe r' : he p..
visiong of Section 739 of the Pohlic f:tiht es t odr relar me to hirine I
rates.as imph mented by the t'orunnwinn.
7.
Otiset Rate The Ofbet Rate sha!! be determined us (1 t the amount of the Cortent Cost of Fue! and Purchased Energy deternuned as specified in Section, Mou Icw (2) the total Record Permi revenues from the California Department r
o Water Resourecs under present con t ract s. all divaled by Ut i the itecord Period kilowatt hours of total sales,' and then less (4) the Hav Weichted Rate for Fuel and Purchased Energy.
8.
Current Cost 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 nuclear prmluction in the Record Period, expressed in kilowatt hours, multiplied by the cur.
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 payments. plus (3) The annualized Eureka Energy fuel service charge in effect on or before the filing date for projects approved by thr Commiwion.
(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 Bru, in effect on or before the Revision Date, weighted by the quantity of eas used under each such gas rate schedule during the Record Period.
(2) The current prices of oil and coal fuel shall be the current average coat in dollars per million Btu of each type in inventory (rPUC Ac.
count No.151, Fuel Stock) on the filing date.
(3) The cur int 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 effective for production on or before the filing date.
(4) The current prices of nuclear fuel shall be the unit rates of amor.
tization, expressed in cents per kilmatt hour, of nuclear fuel as.
semblies, including an allowance for salvage value, determined in accordance with CPUC Account No. 518. Nuclear Fuel Expense, and effective for production on or before the filing date.
(5) Utility owned hydro generation shall be included at zero cost.
See laat page for footnotes.
(continued) m Advice Letter No. 712.E Issued by Date Filed December 8,1 Decision No. 88121 W. M. Gallavan Effective December 28, 1978 Vice. President-Rates and Valuation Resolution No.
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Paciac Gas and Electric Company Revised Cal. P.U.C. Sheet No. 6965.E San Franciseo, California Canceling Revised Cal. P.U.C. Sheet No. 6337.E Og Pour TMINARY STATEMENT (Coensued)
PARTB (rs :. A)
- 9. Balancis Rass The Balancing Rate per kilowatt hour sold shall be determined by dividing (1) the balt. nee in the Energy Cost Adjustment Account at the end of the latest available month at the time of the computation being made under the provisions hereof, by (2) the Record Period kilowatt hours of applicable ju.
risdictional sales.*
- 10. Energy Cost Adjusamma Accouac Efective April 1,1976, the Utility shall maintain an Energy Cost Adjust.
ment Account. Entries shall be made to this account at the end of each month as follows:
(a) A debit entry equal to,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 ex.
eluding operation and maintenance payments and the Eunka Energy fuel service charge during the month for projects appmved by the Commission,less (2) the amount of revenue billed during the month under the Ofset Rate (not including the adjustment for franchine and unoollectible accounts expsnee),less (3) the amount equal to the volume of energy sold during the month to which the Adjustment Rate is applicable multiplied by the Base Weighted Rate for Fuel and Purchased Energy,less (4) the amount of revenue billed during the month to the Californi's De-Os par + ment of Water Resources under present contracts, less (5) the amount of revenue,if any, billed during the month for the fuel v
and purchased energy component of inter. system transactions based on incremental or nplacement fuel costa, less (6) the recorded fuel expense during the month associated with fuel re-eeipts in payment for electric service but not to exceed the expense for fuel actually used to pmvide such service.
(b) A credit entry equal to the amount of revenue billed during the month under the Balancing Rate (not including the adjustment for franchine and uncollectible accounts expense) if positive (debit entry,if negative).
(e) If the Utility receives from any of its gas or geothermal or purchased energy suppliers cash refunds, including any associated interest, on and after the date this Energy Cost Adjustment Clause bacomes efective, the amount thereof associated with sales of electricity shall be recorded as a
~
credit to the Utility *a Energy Cost Adjustment Account. Cash refunds associated with purchases of coal, oil, or nuclear fuel shall be recorded as a credit to the appropriate inventory account. An appropriate ad-justment shall be made to refleet any sale of fuel.
(d) A debit entry equal to 7/12 percent of the average (# the balance in this account at the beginning of the month and the balance in this account after <ntries (a), (b) and (e) above, if average balance is debit (credit entry, if average balance is credit),
See last paso for footnotes.
(continued) i k/
vvice Letter No. 712-E Issued by Date Filed Deeember 8,1978 l
Decision No. 88121 W. M. Gallavan Efective December 28, 1978 Vice-President-Rates and Valuation Resolution No.
-mnaP h @dhhNb E-5
es.eso4 seo. er 2 Pacific Gaa and Electric Company Reviel Cal. P.U.C. Sheet No. 703SE San Francisco, California Cancelin;c Reviwd Cal. P.U.C. Sheet No. 6399 ^
O PRELIMINARY STATEMENT (Continued)
PART B (Continued)
- 10. Energy Cost Adjustment Account (Continued)
(e) It is intended that this account reflect only the balances to be amortized by rates for sales to which this Energy Cost Adjastment Clause applies.
For the purpose of determining entries to the Energy Cost Adjustment Account, items (10(a)(1), (4), (5) and (6), and item 10(c) above in any month shall be pro-rated to applicable jurisdictional energy sa'es' by the ratio of such jurisdictional energy sales to the sum of such jurisdic-tional energy sales and energy sales under Federal Power Commission jurisdiction, excluding sales associated with 10(a) (5) and (6) above.""
- 11. Time and Manner of Filing and Related Reports The Utility shall file a revised Adjustment Rate with the California Public Utilities Commission at least 30 days but not more than 90 days prior to the Revision Date. Each such filing shall be accompanied by a report which shows the derivation of the rate to be applied.
A report on the resonableness of the prices paid for fuel and energy pur-chases will be filed April 15 of each year.
m O
l Footnotes:
- Except (a) for sales for which payrnent is made in fuel and (b) for sales to the De.
partment of Water Resources under present contracts. For the purpose of Item 7.
l sales to the Department of Water Resources shall be excluded to the extent that such sales do not exceed purchases from that agency during the Record Period.
" Excluding fuel receipts in payment for electric service.
"*Except the cost of purchases during the Record Period from thermal electric gen-eration,7here identiaable and where in excess of 1% of total Record Period energy sales, shall be the Record Period volume of such purchases multiplied by the actual rates and charges for such purchases in the latest available month at the time of the computation being made under the provisions hereof.
'"*Where accumulated sales to the Departroent of Water Resources exceed accumu-lated purchases from that agency, the above enumerated items shall be further pro-rated by the ratio af (1) total sales minus the excess of such sales over such pur-chases occurring in the month to (2) total sales.
Advice Letter No. 734-E Issued by Date Filed Aoril 13. 1979 Decision No.
W.3L Gallavan Effective May 15, 1979 Vice-President-Rates and Valuation Resolution No. E-1836 D
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., aos no. e Revised Cal. P.U.C. Sheet No. 7033-E i
N Pacido Gas and Elestric Company Canceliag Revised Cal. P.U.C. tiheet No. 6975.E
{d San Frandaaa, California Schedule No. A.1 GENERAL SERVICE APPLICABILITY This schedule is applicable to single. phase or polyphase alternating current service, or to a combination thereof, except that this schedule is not applicable to service for which Schedule No. A.23 is applicable.
TERRITORY The entire territory served.
p,, y,,,,
4 RATES Per Month Single. Phase Service:
$1.75 Customer Charge:
Energy Charge (in addition to the Customer Caarge):
03 All kwhr, per kwbr Minimum Charge:
$1.75 per month, but not less than $1.50 per month per kva of connected welder load.
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Polyphase Service:
The single. phase rate plus $1.25 per meter per month.
Minimum Charge:
$3.00 per month, but not less than $1.50 per month per kva of connected welder load and per horsepower of polyphase connected load.
Adjustments:
Adjustments, as specified in Parta 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
$.01722 Energy Cost Adjustment
(.00071)
Tax Change Adjustment
$.01651 Total SPECIAL CONDITION For customers who use service for only part of the year, this schedule is applicable only on annual contract.
.m Iv Date Filed April 13, 1979 l
Advice Letter No. 734.E Issued by Decision No.
W. M. Gallavan Effective May 15, 19/9 Vice-President-Rates and Valuation Resolution No. E-1836
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i e x see No. tas Paciae Oas and Electric Company Revised Cal. P.U.C. Sheet No. 7034 E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. em6-h Schedule No. A.12 GENERAL SERVICE-DEMAND METERED 1
APPLICABILITY This schedule is applicable to single phase or polyphase alternating current service, or to a com-bination thereof, except that this schedule is not applicable to service for which Schedule No. A 23 is applicable.
_TW2RITORY The entire territory served.
RATES p., Ma Demand Charses Per Month First 50 kw of billing demand or less
$120.00 Over 50 kw of demand, per kw 2.05 Enersy Giarse:
First 150 kwbr per kw of billing demand per kwbr
.01609 Next 150 kwbr per kw of billing demand per kwbr
.01400 All excess, per kwhr
.01288 Adjustmentes The above base rates are subject to possible adjustment for voltage and/or power factor. In I
addition, bills for service willinclude adjustments, as speciaed in Parts B and C of the Preliminary Statement, as follows:
per kwbe Energy Cost Adjustmen' 8.01'22 Tax Change Adjustment
(.00071)
Total 8.01651 SPECIAL CONDITIONS
- 1. Maximum Demaands The maximum demand in any month will be the maximum average power taken during any 15-minute interval in the month, but not less than the divers 18ed resistance welder load computed in accordance with Rule No. 2. However, when the recorded monthly maximum demand has exceeded 400 kw for three consecutive months and thereafter until it has fallen below 300 kw for 12 consecutive months, a 30-minute interval will be used. In cases where the use of energy is intermittent or subject to violent fluctuations, a 5-minute or a 15-minute interval may be used. A thermal type of demand meter which does not reset after a definite time interval may be used.
1 Bi!!ing Demand: The billing demand to be used in computing charges will be the mean of the mazi.
mum 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.
- 3. Of. peak Dw+-s't Any customer whose billing demand has exceeded 400 kw for 3 consecutive i
months and therer_ar kntilit has fallen below 300 kw for 12 consecutive months may, upon request, for j
billing purposes, and under a contract for service for a period of 5 years, have demands ignored which occur between 10:30 P.M. and 4:30 A.M. of the following day and on Sundays and the following holidays:
. )
New Year's Day, Washington's Birthday, Memorial Day, Independence Day, Labor Day, Veterans' Day, Thanksgirtng Day and Christmas Day, as said days are spec 1 Sed in Public Law 90 363 (U.S.C.A. Section 6103 ).
1 (continued)
Advice Letter No. 734.E Issued by Date Filed April 13, 1979 Decision No.
W. M. Gallavan Effective May 15, 1979 Vlee. President-Rates and Valontion Resolution No. E-1836 E-8 o
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03 4 304 Ste. 33s Pacifle Gas and Electric Company Revised Cal. P.U.C. Sheet No. 6006 E San Francisco, California Canceling R vised Cal. P.U.C. Sheet No. 4714.E
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Schedule No. A.12 GENERAL SERVICE - DEMAND METERED (Continued)
- 4. Votesse Discouns: (1) When delivery hereunder le made at the same voltage as that of the !!ne from which the service is supplied, or (2) when sufficient capacity is not ava11able in distributton %c111 ties existing in the area to supply the customer's requirements, and the Utility has elected to supply service from a transmiaston line for its operating contentence by means of Utility owned transformers on the l
customer's property, a discount of 4% when such delivery to made at 11 kT or above and 3% when such delivery is made at." kV to 10 kv,Inclustve, will be allowed on the above charges, including the minimum charge, provided, however, the Ut!!!ty is not required to supply service at a non4tandard voltare. When service is supp!!od directly without tran;ft,rmattun fro:n a tranamtmoton line of 60 kV or higher, t discount l
of 57< 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 hercunder and affected by such chann, and such customer then has the option to che.nge his system so as to receive service kt the new itse voltage or to accept service twithout voltage discount) through transformers to he espplied by Utility.
O
- 5. Power Factor: When the billing demand has exceeded 400 kw for three consecutive months and thereafter untti it has fallen below 300 kw for twelve consecutive months, bills will be adbtsted for weighted monthly average power factor as follows:
The total charge (ezcept the minimum charge) for any month as computed on the above rates will be decreased or increased. respoettvely, by 0.1% for each 1% that the average power factor of customer's load in the month was greater or less than 85%, such average power factor to be computed (to the nearest whole per cent) from the ratio of lagging k!!ovolt ampere hours to kilowatt hours conenmed in the month, provided, 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 monthe.
- 6. Contract: For customers who use service for only part of the year this schedule is applicable only on annual contract.
O v
V Advice Letter No. 512.E Issued by Date Filed seet. 16. 1975 Decision No. 84902 W. 3I. Gallavan Effective Sept. 21. 1975 Vice President-Rates and Valuation Resolution No.
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. w i.e..se Pacific Gas and Electric Company Reviwd Cal. P.U.C. Sheet No. 7035-E San Francisco, California Canceling Hrvel Cal. P.U.C. Sheet No. eR7A O
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.
"ITRRTTORY The entire territory served.
RATILS Per Month Demand Gaarse:
Per Mme First 1,000 kw of billing demand
$2,658 00 Over 1,000 kw of billing demand, per kw 2.12 Unarp Charge (in addition to the Demand Charge):
First 100 kwhr per kw of billing demand, per kwbr
.01451 Next 200 kwbr pe? kw of billing demand, per kwhr
.00991 All excess, per kwht
.00791 Minimum Charges The Demand Charge constitutes the Minimum 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 Parta B and C of the Preliminary Statement, as follows:
per Imhr Energy Coat Adjustment 8.01722 Tax Change Adjustment 000071)
Total 8.01651 SPECTAL CONDITIONS
- 1. Maximum rwaAs The maximum demand in any month will be the maximum average power taken during any 30-minute intervalin the month, but not less than the diversifled reefstance 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. Bi!!iss Demand The b!Iling demand to be used in computing charges will
- 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 con %ct for service for a period of 6 years may, upon request, for btiling purposes, have maximum den '. ads Ignored which occur between 10:30 P.M. and 6:30 A.M. of the following day and on Sundays.nd the following holidays: New Year's Day, Washington's Birthday, Memorial Day, Independence Da y, 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 atless than 2 kr,or (b) when delivery is made by means of Utilityowned transformers at a distribution voltage other than a standard primary distributlon voltage, or (c) when delivery la made at a voltage that requires more than one stage of transformation from transmission voltage. When delivery 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 prtmary distribution voltage from a transmission !!ne, for its operating convenience, from Utility. owned transformers on the customer's property, the above charges for any month will be reduced by 15f per kw of billing demand in the m) nth. When delivery is made at transmission voltage (60 kv and above), the above charges for any month will be reduced by 25d per kw of billing demand in the month. The Utility retains the right to change its line voltage at any time, after raasonable 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 trans.
I formers to bo supplied by Utility subject to the voltage adjustment above.
S. Power Factor The total 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 the I
month was greater or less than 85%, such average power factor to be computed (to the nearest whole per l
cent) from the ratio of lagging kilovolt ampere hours to kilowatt hours consumed in the month.
- 6. Voltage: Service on this schedule will be supplied at the transmission or the primary distribution available, or, at the option of the customer, at the secondary voltage available.
(continued)
A 1
Advice Letter No. 734-E Issued by Date Filed Aoril 13. 1979 Decision No.
W. M. Gallavan Effective May 15. 1979 Vice-President-Rates and Valuation Resolution No. E-1836 n
.a.eu Revised Cal. P.U.C. Sheet No. 7036-E Paciac Gas and Electric Company Canceling Revised Cal. P.U.C. Sheet No. 6978-E g
San Francisco, California s
Schedute A.15 GENERAL SERVICE-DIRECT CURRENT APPLICABILITY This schedule is appliemble to direct current lighting servlee. including lamp socket appliances end. at the customer's option, to direct current service for power and heating alone or combined with lighting on the same meter. This schedule is applicable enJr to those establishments which continued servlee under this schedule on and after February 18,197L TERRITORY Certain downtown areas cf San Francisco. Oakland and Stockton where direct cur-rent is available.
Per Meter Per Meath RATES 51.75 Customer Cherse Baergy Omarse (in addittoa to the Customer Charge):
.060 All kwhr, per kwhr 88=*=a= Charse: The Customer Charge except where motors aggregating more than 6 hp are connected, in which case the total mtntmum charge will be $1.60 per month per hp.
Adiustmeses:
Adjustments, as spec 18ed in Parts B and C of the Preliminary Statement, will be O
I added to each till for service calculated at the above rates, including b111s for mini.
t,d mum charges. Adjustment amounts are as follows:
per kwbr Energy Cost Adjustment S.01722
(.00071)
Tax Change Adjustment 3.01651 Total SPECIAL CONDITION The maximum demand in any month will be the erage kw de117ery of the 15. minute laterval in whics seek delivery is greater than in any other 15-minate interval in the month. The billing demand to be used la computing charges will be the mean of the mart-man so determined for the current month and the hirhaat seek demand occurring in the year ending with the current month.
A i
s Advice Letter No.734-E Issued by DatoFiled April 13, 1979 Decision No.
W. M. Gallavan Effective May 15, 1979 Vice-President-Rates and Value. tion Resolutioii.No. E-1836 i
i i
i m
n.nes s. u.
Pacifle Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7037 E San Francisco, California Canceling Revimi Cal. P.U.C. Sheet No. ti979A O
Schedule No. A.18 INTERRUFTIBLE 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 sutstation to be owned or leased by the customer. Service under this schedule is supplied if,in the Utility's sole judgment, there exists sufficient reserve and transmission margin
'ITR RITORY The entire territory served.
RA1T Per W eer Demand Garges Per Month On. Peak, per kw of Maximum Demand, but not less than 87.000 per month 31.40 02 Peak, per kw of Maximum Demand in excess of the On Peak Demand
.35 Energy Charges All kwhr, per kwhr
.00823 Unitation on Gerses:
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.
Adjustments:
The above base rates are subject to possible adjustment for voltage and/or power factor. In addition, bills for service willinclude adjustments, as specifled in Parts B and C of the Preltminary Statement, as follows:
O per kwhr Energy Cost Adjustmen' 3.01722 Tax Change Adjustment
(.00071)
Total 3.01651 SPECIAL CONDITIONS
- 1. Contraces: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 until cancelled by either party by written notice one yearin 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 its Utility regularly filed with the Californfa Public Utllities Commission, in force at the time and applicable to service under this schedule.
- 2. Maximum Demand: The maximum demand in any month will be the average kilowatt delivery of the 30 minute interval in 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 durfug which no curtallment occurs over the number of hours in the month. Such maximum demand she.fi be not less than the average load during said month.
- 3. Powee Factor Adj-r The total chargo, except the minimum demand charge, for any month as computed on the above rate shall 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. Og. Peak Period: The hours from 10:30 P.M. to 6:30 A.M. and on Sundays and the following holt.
days-New Year's Day, Washington's Birthdry, Memorial Day. Independence Day, Labor Day, Veterans' Day, Thanksgiving Day, and Christmas Day, as said days are specified in Public Law 90 363 (U.S.C.A.
i l
Section 6103).
(continued)
A Mvice 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
noe s
. e.
Paci5e Gas sad Eltetrie Con:pany Revised Cal. P.I'.C. Simet No. 6012.E San Francisco California Canceling Revned Cal. P.U.C. Sheet No.5990-E mU v
Schedule No. A.1s INTERRUPTIBLE PRIMARY INDUSTRIAL POWER (Continued)
- 3. Curta3mese All electric power delivered hereunder shall be subject to curtallment a ben in the UUlity's sole judgment its reserve. energy resources or transtfaalos margin or any combination of these la needed to meet the demaads of its regular customers on $ra rates. er ta the Utility's judgment there la en actual or threatened need for such reserve of transmission margin. Customer.upon notice from the Utility, shall eurta!! his use of electric power, escept plant lighting. Bre pmtection load and other safety
~
and security load. to the estent requested by and as scheduled by the Utility. Curtallment sha!! be effected by customer (1) famediately upon request from the Utility in cases of emergencies not reasonably pre.
dictable by the Ut!! sty.and (3) to all other instances on nouce as spec 18ed in the standard form contract.
Full curtallment shall not escoed 3.1p0 hours during any contractual year.
- 8. Interrupties: All electric power delivered hereunder escept plant lighting. Are protectich load. and ether safety and security load, shall be subject to automatic interruption. The Utility shall install and maintain a digital underfrequency relay (or relays) with adjustable contacts set to close at the Sched.
uled Frequency and the assoc!ated relay facilities necessary in the sole opinion of the Utility to interrupt electric power automatically in the event of a reduction of frequency on the Utility's erstem to Ib*
Scheduled Frequency. If more than one underfrequency relay la required then the cus:cmer Phall pay the cost of the additional equipment.
In addition to or la lieu of interruption of electric power at the Scheduled Freuuency the Utility may require that electric power be interrupted automatically in the event of a reductron in voltage or in the event of such other operating condluons as may appear appropriate to the Utility from time to time i
After any interruptles hereunder. the customer shall not reeuse use of electric poner earept upon notlee from the Ut.!!!ty.
- 7. Sc.haduled Frequency: The Scheduled nequency la 59.75 herts (with a delay of $ cycles) until revised la accordance herewith.
Before December 1 of each year or more frequently al changed conditions may require. the Sched.
1 uled Frequency (including any delay) w!!! be reviewed and changed as appropriate The Utility will i
y thereupon notify the California Public Utilities Commission and all customers served hereunder of the revised Scheduled Frequency which shall become effecuve on the Srst day of the second scouth l
immediately following the date of such terfalon.
- g. Communiaties: The customer shall provide to the Ut!!!!y's spee!Scations and at his sole expense exclusive communication channels to the Utility's Switching Center for the purposes of alarn ins. tele.
metering. and algnaling If necessary to carry out the provisions of this schedule. the custome m 3 be required to install and maintain at his sole expense a recording vattraeter. Utility shall base the right to inspect and test relay faci!!Ues, communication channel and wattmeter upon reasonable notice to customer.
- 9. Capacity Availabuity: The total amount of capacity avatishte hereunder is limited to a maximum of 300.000 kilowatts of the Utility's reserve and transmission margin. The Utility will not!!r the Publit Utilities Commission of the State of Cahfornia in writing when the amount of capacity available here.
under has been fully contracted for. Customers applying for service hereunder when the capseity avail.
able has been fully contracted for shall be placed on a priority list according to the date of app!! ration j
and shall be served when additional capacity becomes available.
- 10. Teensmission Service Facilities: The Utiltty w!!! at its expense furnish and lastall one oveihead span of transmission conductors and attach to the h!gh voltage terrninals of the substation structure to be owned or leased by the tuttomer. When the Ut!!!ty extends its electric transmission !!nes to serve the appheant's premises. the applicant shall advance to the Utility the estimated installed cost of the exter.sfor. and thereafter pay a mor.thly ownership charge of %g of such cost If such extension or any portion thereof is thereafter used to sette new, separate!y metered permanent load for which the Utility sould install all or a portion of the extension at its expense, a proportionate share of the applicant's advance will be refunded. Where such refoods are made.the month!) ownership charge m'111 be adjusted to %'". of the unrefunded bal nee of the advance. No refunds will be scade in enress of the original advance.
G) 6 Mvice Lnter No. 512.E Issued by Date Filed Sept. 16, 1975 Writimt No. lWO2 W. M. G allavan E&ctive Sept. 21, 1975 Vice. President-Rates and Valuation Rewintini.No.
f k.
E-13
es<rae no. ase Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7038.E 8an Francisco, California Canceling itemed Cal. P.U.C. Sheet No. twoM 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 30.1975, to new customers thereafter whose maximum demand in any time period is 4,000 kilowatts or greater, and to existing customers served in accordance with any applicable General Service. Agricultural Power Refinery or Standby Service schedule, whose monthly maximum demand !s 4.000 kilowatts or greater for 3 consecutive months. Any customer whose aggregate diverstiled monthly maximum demand at a stogle service location has fallen below 3.500 kilo-watts for any 13 consecutive months may, at his option, thereafter elect to continue to receive service 1
under this schedule or elect to be served under any other applicable schedule.
.i TERRITORY The entire territory served.
RATES Per Meter Per Month Period A Peried B i
Customer Charge.
3715.00 8715.00 Demand Charge On Peak. per kilowatt of Maximum Demand 34.20
$2.80 Plus Partial Peak, per kilowatt of Maxtmum Demand 0.35 0.35 Plus Off Peak, per kilowatt of Martmum Demand No Charge No Charge Energy Charse:
On Peak, per kilowatt hour -
$.01045 3.010 G Plus Partta! Peak, per kilowatt hour
.00845
.0C845 Plus Off. Peak, per k!!owatt hour
.00645
.00645 Adjusneents:
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:
_ per h hr Energy Cost Adjustment-S.01713 Tax Change Adjustment
(.00071)
Total 3.03651 SPECIAL CONDITIONS
- 1. Time Periods:
Period A is app!! cable to meter readings from May 1 to September 30. Inclusive, for the following hours:
On Peak 13:30 p.m. to 8:30 p.m.
Monday through Friday, except holidays.
Partf al Peak 8:30 a.m. to 13:30 p.m.
Monday through Friday, except holidays.
6:30 p.m. to 10:30 p.m.
8:30 a.m. to 10:30 p.za.
Saturday, except holidays.
Off Peak 10:30 p.m. to 8:30 a.m.
Monday through Saturd ty, except holldays.
l All day Sunday and holidays.
Period 8 !s applJcable to meter readings from October 1 to Aprtl 30. lactusive, wr the following hours:
On Peak 4:30 p.m. to 8:30 p.m.
Monday through Friday, except holidays.
Partial Peak 8:30 a.m. to 4:30 p.m.
Monday through Friday, except holidays.
8:30 p.m. to 10:30 p.m.
8:30 a.m. to 10:30 p.m.
Saturday. except holidays.
Off Peak 10:30 p.m.to 8:30 a.m.
Monday through Saturday, except holidays.
All day Bunday and holldays.
(continued)
A Advice Letter No. 734.E Issued by Date Filed Apri1 13,1979 l
Decision No.
W. M. Gallavan Effective May 15, 1979 l
Vice. President--Rates and Valuation Resolution No. E-1836 E-14 "G ' N b 0)
es.uo.
.see Pacific Gas and Elcetric Company Revised Cal. P.U.C. Sheet No. 6864.E San Francisco, California Canceling Original Cal. P.U.C. Sheet No. 6394.E f
ib/
Schedule No. A.23 GENERAL SERVICE-TIME METERED (Continued)
- 2. Holidays: The holidays spec 18ed in this Schedule include: New Year's Day. Washington's Birthday, i
Memorial Day, ladopendence Day 14bor Day Veterans' Day, Thanksgiving Day, and Christmas Day.
as said days are spectaed in Public Law 90 363 (U.S.C.A. Section 6103).
- 3. Masissum Demand: The maximum demand in any month for each time period will be the maximum average power taken during any ?,0 minute interval in the Nr.th, but not less than the diverstaed resistance welder load computed in accordance with Rule Nw. 2: 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.
- 4. Voltage Adjustment: The above charges are applicable without adjustment for voltage when (al delivery is made at less than 2 kv, or (b) when delivery la 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 primary distribution voltage at 2 ky or above available in the ares 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 maximum on peak demand in the month. When delivery is made at transmission voltage (40 kv and above), the above charges for any month will be reduced by 25d per kw of manimum on peak demand in the month. The Utility retains the right to change its line voltage at any time, after reasonable advance i
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 suppIled by Utility subject to the voltage adjustment above.
S. Power Facter: The total 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 the month was greater or less than 86%, such average power factor to be compcted (to the nearest whole per cent) from the ratto of lassing kilovolt ampere hours to kilowatt hours consumed in the month.
]
- 6. Voteses: Service on this schedule will be supplied at the voltages as doecribed in Electric Rule 2.
%ner
- 7. FacMier Chares Where the estimated installed cost of only those facilities necessary to provide regular service which are Installed after February 7,1977 is in excess of the estimated annual revenue to be derived from service under this schedule (escluding that portion of revenues equal to the product i
of estimated annual kilowatt hour usage times the sum of the Fuel Cost Adjustment and the Base Welghted Average Cost of Fuel and Purchased Energy) an additional monthly charge of 1% percent of such excess will be made. !! the customer elects to advance such excess cost to the Utility, the additional i
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 not cost to install and remove such facilities. Any customer advance for costs of such facilities shall be applied as a credit toward such not installation and removal costs.
- g. Contract: Electric service supplied under this schedule shall be in accordance with a contract authortred by the Public Utilities Commission of the State of California. Such contract will be required 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 subequent 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 eacept that 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.
5 i,-
i' j \\
. Q ~ hivie k sta No. GSS.E Issued by Date Filedsept. 6,1978 Decision No. 89316 W. M. Gallavan Effective sept. 11, 1978 Vice. President-Rates and Valuation Resolution No.
~ E-15~
p
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,,0. u.
PaciSc Gas and Electric Company Revised Cal. P.U.C. Sheet No. 6746-E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 5785-E
.R
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l 1
Ok J l-No. A-41 GENERAL POWER SERVICE
(
APPLICARG.2TY Thle schedule to applicable to eingle phase or polyphase alternetlag carrent service, or to a combl.
(
netton thereof.
NY Within the Shasta Dam Rate Area.
RATES A--Connected Imed Beeio--for installations with a connected load of 40 hp or less and demands not exceeding 20 kw:
Emergy Chersea Per Maser Per Month Mret 200 kwbr, per kwhr 4.70c Next 400 kwhr, per kwhr
. 3.12 Next 1400 kwhr, per kwhr 1.57 Next 10.000 kwhr, per kwhr 1.41 All excese kwhr, per kwhr 1.09 Minie.e.n Charges I
30.60 per horeepower of connected power load or $1.20 per kilowatt of deman.1 at the customer's option but not less than $5.00 for single-phase service or $7.50 for three phase service. Ileating and cooking load will be converted at the rate of 750 watte per horsepower.
O B--Desmand Besie.-for installations with a connected load of 40 hp or more and with bt!!!ng demands exceeding 20 kw:
I l
Emergy Charges Par Messe Per Maesh Mret 50 kwhr per kw of Willas demaad, per kwhr-Next 100 kwhr per kw of bt!!!ng demand, per kwhr 3.124 1.25 All escene kwhr, per kwhr
. 0.94 l
Ms.a. - Caer
,e, e.s.
824.00 but not lose than $1.20 per kw of bt!!!ng demand.
l l
(eemstaned)
A Advice Letter No. 659.E Ianned 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
[]
h
u.nu o.o. us Pacifle Gas and Electric Company Evised Cal. P.U.C. Sheet No. 472LE San Francisco. California O
Canceling Gr ginal Cal. P.U.C. Sheet No. 2840 E V
Schedule No. A.41 GENERAL POWER SERVICE (Continued)
SPECIAL CONDITIONS
- 1. Maximuun 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 intermit.
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 deonite time interval may be used.
- 2. Billang Damead: The billing demand to be used la computing charges under Rate B will be the higher of (at the maximum demand as determined under Special Condition 1 for the current month or ib) 75% of the highest such demand occurring in the year ending with the current month, but rot less than 20 kw.
- 3. Of peak Desmand: Any customer whose billing demand has escoeded 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 pattod of 5 years. have deruands ignored which occur between 10:30 P.M. and 6:30 A.M. of the following der and on Sundays and the following holidays: New Year's Day.
Washlogton's Birthday Memorial Day, Independence Day, Labor Day Veterans' Day. Thanksgiving Day, and Christmas Day. as such days are specified in Public Law R363 (U.S.C.A. Section 6103).
- 4. Voltage: Service on thle schedule will be supplied at the secondary voltage available or, at the opticu of the customer, at the primary voltage available. Where secondary voltage is desired and polyphase power is to be combined with single-phase, a 4 wire service will be supplied in accordance with Section D of Rule 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 polyphase service will tse supp!!ed and metered separately, the meter readings being combined for the purpose of computing charges on this schedule.
- 5. Primary Vokase Discount: When delivery heteunder is made at the same voltage as that of the line from which the service is supplied a discount of 5*/c for 11 kr or higher available line voltages and tO y
3% for available line voltages of from 2 kV to 10kT will be allowed provided however. the Utility is nat required to supply service at a particular line voltage where it has (or will install) ample facilities ter supplying at another voltage equally or better suited to the customer's electrica1 requirements. The Utility retains the right to change its line voltage at any time, after reasonable advance notice to any custemer 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 (without voltage discount) through transformers to be supplied by Ut!!!ty.
- 6. Power F.ctee: 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 will be adjusted for weighted monthly everage 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 average power factor to be computed (to the nearest whole per cent) from the ratio of lagging kilovolt ampere hours to kilowatt hours consumed in the month, provided, 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 proceding eleven months.
Ovice Letter No. 350-E Issued by Date Filed February 9.1971 Decision No. 75156 J. F. Roberta. Jr.
Effective Februarv 13.1971 Vice-President-Rates and Valuation Resolution No.
E-17
e4-(804 No.Coe Paci8e Oas and Electric Company Revised Cal. P.U.C. Sheet No. 7039.E Ban Francisco, California Canceling Revised Cal. P.U.C. Sheet No. ~gt% O Schedule No. OL 1 OUTDOOR AREA LIGHTING SERVICE APPIJCABIIJTY Applicable to outdoor ares lighting service for the illuzr.! nation of areas where street and highway lighting schedules are not app!! cable and where the Utility installs, owns. operates and maintains the complete Ifghting installation on Ut!Ilty's existing wood distribution poles or on customerewned poles acceptable to the Utility installed by the customer on his private property.
'ITPRITORY The entire territory served.
RA'11tS I
Per Lamp Per Month Mercury Vapor Laemp
- Lamp Waus 175
$4.923 l
400 11.045 i
High Pressure Sodium Vapor Lampo Lamp Wans 70 36.228 100 -
6.943 200 8.902 Adjustments:
The above rates include adjustments, as specified in Parts B and C of the Preliminary State-ment, as follows:
Per kwbr Energy Cost Adjustmen*
jg
$.01722 Tax Change Adjustment
(.00071)
Total 8.01651 SPECIAL CONDITTONS
- 1. Type of Servises Service will normally be supplied to individuallv-controlled lamps from the Utility's existing 130/240 volt (120/z08 volt star in certain localltfee) sin.le phase overhead or under.
ground distribution circuits. Servlee from 480 volt cources will be made available only when this type of service is deemed to be practical from the Utility's engineering standpoint and the applicant pays the additionalinitial cost of a 480 volt supply.
- 2. Opereeing u AJ.: Lighting service will be supplied from dusk to dawn on an operaung 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. IJabning F dWe The Utility will provide and maintain, at its expense, a standard Inminalre.
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 addt-tional installed cost over that of a standard support arm. Outdoor area lighting facilities will only be installed where the Ut!11ty has. or intends to install, a wood distribution pole for the purpose of sup-porting other distributton facilities, or where a customerewned pole acceptable to the Utility has been installed by the customer on his private property. The Utility shall not be required to install luminaires at locations where. In its Judgment, the service may be objectionable to others.
i i
' Closed for new installations as of June 8.1978.
(continued) g O
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 E-18 L
\\
ee-eeee me. sa Pacifle Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7040.E San Francisco, California Canceling Revined Cal. P.U.C. Sheet No. 6962.E O
Schedule No.D 1 DOMESTIC SERVICE APPUCABIUTY 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 reeldential 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.
T11RRITORY The entire territory served eacept in the Shasta Dam Rate Area.
RATES Per Meter Per Month Base Adjust.
Egective Rates ments Rates Customer Charge
$1.75 31.75 Emeegy Charge (in addition to the Customer Charge):
Lifeline kwbr. Der kwbr
.01604 8.01003
.02607 Escess kwhr, per kwhr
.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 K=hr Lifeline Non. Lifeline Energy Cost Adjustmen' 8.01003 8.01722 Tax Change Adjustment
(.00071)
Total 5.01003 8.01651 SPECIAL CONDITIONS O
- 1. Amaus! Contract: For customers who use service for only part of the year this schedule is appli.
V(j cable only on an annual contract.
- 2. Lifeline Rates: IJtetine rates are applicable only to separately metered residential usage. The Utility may require the customer to complete and Sie with it an appropriate Declaration of E!!gibility for Lifeline Rates.
- 3. Lifetime Usage: The following quantitles of electricity are to be billed at the rates for lifeline usage:
Monthly Kwbr A!!owance End Une for Ctimatic Bands' Code W
X Y
Z Basic Allowance **
B 240 240 240 240 Basic plus Water Heating W
490 490 430 490 Basle plus Space Hosting Summer H
240 240 240 240 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 280 280 Territory B 230 Energy used in excess of the lifeline allowances will be billed at the nonlifeline rates. continu!ng from the quantity reached by the lifeline allowance.
- Climatic Bands are described in the Pre 11minary Statement.
Includes lighting, cooking and refrigeration.
(continued) h)
6)
Ad vice Letter No. 734.E, Issued by Date Filed April 13, 1979 Decision No.
W. M. Gallavan EtYeetive May 15, 1979 Vice. President-Rates and Valuation Resolution No. E-1836
ec..s
..e.
Paci8e Gas and Electric Connpany Revim! Cal. P.U.P. Sheet No tim 2 E San Francisco, California Cnne ling Revised Cal. PT.U. Sbnt No. fit 91 E Scliedule No. D.1 DOMESTIC SERVICE (Continued)
- 4. IJfe-Suppose Devkass A residentfalvustomer, who cert!fles In writing that regula use of a medical life-support device, as deoned in Rule No.1. le essential to maintain the life of a full titna resident of the household, is eligible for a uniform monthly lifeline allowance la addition to those allowances shown in Special Condition 3. The amount of the additional allowance will be determined by the t'tility from load and operating time data. The Ut!!!!y may require certiacation by a doctor or osteopath licensed to practice medicine in the State of California that a partienlar device is necessary to sustain the user's life S. b-1 Raee he Bille for service which include lifeline allowances for space heating and air conditioning will be prorated in the May and November billing periods based on the ratto of the numbee of days prior to May I and subsequent to October 31. respectively, to the total nutnber of days in th.-
billing period.
A O
i l
l l
l a
Advice Letter No. 711.E haued by Date Filed December 6, 19/.
Deci: ion No.
W. 3L Gallavan Efective_ Januarv s,,E.
Vice President-Rates and Valuation Resolution No._, _,,,,,_
g,g,o Rdg[Na, l
E-20
es.eete No.193 Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 6953.E i
San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 6802.E
%/
u -8ule No. D 40 DOMESTIC, SERVICE APPLICABILITY This schedule is applicable to domestic lighting, heating, cooking and singl+ phase domestic power service in single family dwellings and in Sats and apartments separately metered by the Utilityl to single-phase service used la common for reeldential purposee by tenanta in multifamily dwellings; and to all stagle phase farm servloe on the presslees operated by the person whose reeldence is supplied through the same meter.
TERRITORY Within the Shasta Dass Rate Area. (X)
The letter in parentheses after each Rate Ares ladleates the Cllastle Band applicable la Special Condition 3.
RNIES Pee Meeer Pee Meath Ufeline Nea. Lifeline Energy Cherse Renee Retse First 30 kwbr, per kwhr 80.0539 80.0539 Next 100 kwbr, per kwbr 0.0385 0.0385 Nest 100 kwbr per kwhr -
0.0285 0.0285 Next 720 kwbr. per kwbr 0.0185 0.0185 All escoes kwhr, per kwhr 0.0169 0.0189 Minimum Onorse:
$1.00 per meter per month.
SPECIAL CONDfTIONS O
- 1. A-==I Centracts For customers who use service for only part of the year this schedule is appli.
emble caly on an annual contract.
- 2. Ufeline Resse Lifeline rates are applicable only to separately metered residential usaga. The Utility may require the customer to cosaplete and Ale with it an appropriate Declaratica of Eligibility for Lifeline Rates.
- 3. Ufetime Uesee The following quantitles of electricity are to be billed at the rates for lifeline usage:
End Use Menably Kwbr Allowance for the Band
- Code X
Basic Allowance **
B 340 Basto plus Water Heating W
490 Basic plus space Heating Summer (May 1 to Oct. 31)
H 340 Winter (Nov.1 to April 30) -
H 1.040 Basic plue Space and Water Heating Summer (May 1 to Oct. 31)
C 490 Winter (Nov. I to April 30)
C 1.290 Non. lifeline N
0 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.
- Climaue Bands are described in t's Pretinataary Statement.
- Includes lighting, cooking and refrigerstloa.
- 4. Ufe.Suppeet De.wes: A reefdential customer, who cert 18ee in writing that he neldes in a sepa, rately metered ~or submetered single family dwentag unit and that regular use of a medical life-support device, as deoned in Rule No.1. la esseettal to malatala the life of a full-time resident of the house.
hold. la elfstble 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 certlAcation by a doctor or osteopath licensed to practice medicine in the State of California that a particular device is neccesary to sustain the user's life.
- 3. Sensenal Rate Queneses Bills for service which include lifeline a'.iowances for space beating 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 bliting period.
V Advice Letter No. 711.E Issued by Date Filed December 6,1978 T.eeision No.
W. M. Gallavan Effective January 5, 1979 Vice. President-Rates and Valuation Resolution No.
E-21 l
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ee<see me. o l'acific Uns and Elcetrie Company Revised Cal. P.U.C. Sheet No. 4739.E San Fra ncisco. California Canceling Revised Cal. P.U.C. 8heet No. 3r)7.E
^
O Schedule DE SERVICE E COMPANY EMPLOYEES APPLICABILITY Electricity for domestic purposes under this schedule is available, upon application, to regu.
~
1.ir and pensioned employees of the Utility, provided the) reside in their own home (single family duciling.neparately. metered flat or apartment) and are supplied directly by the Utility.
This rate applies to employees living with and constituting the support of a mother, father or other relatives.
The ses vice must he bi!!cd to and paid by the employce.
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 in not applicable to probationary. casual or temporary employees.
TERRITORY The entire territory nervni.
P%
RATE The regular filed domestic mervice schedule applicable in the territory where service is suppliet. leu.!5% diwount.
a Advice Letter No. 360.E Issued by Date Filed February 9.1971 Decision No. 78186 J. P. Roberts, Jr.
Effective February 13.1971 Vice. President -Rates and Valuation Resolution No.
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es.esee e,e. m Paciac Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7041.E San Francisco, California Canceling Revised Col. P.U.C. Sheet No. 6998-E l
v I
Schedule No. DM MULTI. FAMILY SERVICE APMJCABILITY This schedule is applicable to service for domestic lighting, heating, cooking, and single. phase power service supplied to multi family accommodations through one meter on a single precises in accordance with Rule No.18. Closed to new installations.
l
'rsaarroaY j
The entire territory served.
I R nills The rate of the single family domestle service schedule, appHomble in the territory in which the asalti-family accommodation is located, modi $ed as follows:
j
% Charges No change.
Basegy Cherse (in addition to the Customer Charge):
The kilowatt hours for all blocks shall be multiplied by the number of residential dwelling units and/or mobile home spaces wired for service.
Adj-me Adjustments, as speciAed 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 natntmum charges. Adjustment amounts are as follows:
Per Kwbr LifeEme Noe. Lifeline Energy Cost Adjustmen' 8.01003 8.01722 Tax Change Adjustment
(.00071)
Total 3.01003
$.01651
% *r SPECIAL CONDITIONS
- 1. Simlespliers In determinauos of the muluplier it is the responsibility of the customer to advise the Utuity within 15 days following any change in the number of residential dweDing units and mobile hennes wired for servlee.
2, Aswl-leeds: Miscellaneous electrical 12 such as general lighting, laundry rooms. gen.
eral maintenance, and other sinuar usage incidental to the operation of the promises as a multi-family accommodauon will be conaldered as domesuo usage.
- 3. Non residential 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 usetored and billed under the applicable general service schedules.
- 4. Aamuel Cenerect: For customers who use service for only part of the year, this schedule is appli-cable only on an annual contract.
- 5. Lifeline Reese: 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 Declaration of Eligibility for Lifeline Rates.
v (conunued)
O Y
Advice Letter No. 734-E Issued by Date Filed April 13, 1979 l
Decision No.
W. M. Gallavan Effective Ma_y 15, 1979 Vice-President-Rates and Valuation Resolution No. E-1836 j
I
so...e4
....3 Pacific Gas and Electric Company Revised Cc.l. P.U.C. Sheet No. 6955.E San Francisco. California Canceling Herwd Cal. P.U.C. Sheet No. 6868 E Sdadule No. DM MULTI. FAMILY SERVICE (Cossinued)
SFWCIAL CONDfTIONS (ru--- 8)
- 6. Lafellae Usage: The following quantitles of electricity are to be billed at the rates for lifeline usage:
Meeshly Kwbr Agewence*
End Use for 0% Beads **
Code W
X Y
Z Per ehl Unie Basic AUowancem B
190 190 190 190
~
Basic plus Water Heating W
390 390 390 390 Basic plus Space Heating Summer (May 1 to Oct. 31)
H 190 190 190 190 Winter (Nov. I to April 30)
H 530 670 365 1.040 Baste plus Space and Water Heating Summer (May 1 to Oct. 31)
C 390 390 390 390 Winter (Nov.1 to Apru 30)
C 730 870 1.045 1.340 Non lifeline N
0 0
0 0
Air Conditioning Allowance - additive to above allowances May 1 to Cetober 31. inc unive:
Territory A 170 170 Territcry B 140 Einwsy used in excess of the lifeline allowances will be billed at the non-lifellae rates, continuing from the quantity reached by the lifellae allowances.
'Any submetered unit will receive the allowance for individually metered units as shown on Sebedule No. D8.
- Climatic Bands are described in the Preliminary Statement.
- Includes itshtlag. cooking and refrigeration.
^
- y. Life. Support Devkees A reeldential user of electric service in a multi.fasally accommodation. who cert 18ee in writing that regular use of a medical life.eupport device, as deAned in Rule No.1. is essential to maintain the life of a full-time resident of a residential unit. le ellstble for a uniform amonthly lifeline allowance in addition to those allowances shown in Special Condition 6. The amount of the additional a!!owance w111 be determined by the Utility from load and operating time data. The Utuity saar require certification by a doctor or osteopath licensed to practlee medicine in the State of California that a particular device is necessary % sustain the user's 11fe.
- a. Samoanal Reee (b y - Bille for service whlet include lifeline allowances for space heating and air conditioning wt!I be prorated in the May and Novemoer billing periode 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 bi!!!ng period.
- 9. These Phase Servke: Three phase load will be suppued servlee under this schedule for multi.
family roeidential customers who were suppued three phase service an a general service schedule on August 37.1976.
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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.
E-24 U
=>
es.e e4 ee Pacifle Gas and Electric Cornpany Reviwd Cal. I'.U.C. Sheet No. 7042 E
(].
San Francisco, California Cr.nceling lievised Cal. P.U.C. Sheet No. 6999.E v
Wlula No. DS MULTI.PAMILY SERVICE APPUCARIIITY This ochedule is appucable to service for domestle 1!shting. heating. cooking. and single phase power service supplied to multi family accommodations in other than a mobilehome park through one meter on a single promises and submetered to all individual tenants in accordance with Itule No.18.
TBatrIORY The entire territory served.
RATIES The rate of the single family domeetle service schedule. applicable in the territory in which the naultifamily accommodations is located, lees 10% discount on the energy rates applicable to lifeline osage.
P
- Omarges No change.
Energy Cheese (in additlen to the Customer Charge):
The kilowatt hours for all blocks shall be mulup!!ed by the number of residential dwelling units wired for service.
Adjusuments:
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 Adjustmen'
$.01003
$.01722
)
Tax Change Adjustment
(.00071) 5 yV Total 3.01003 5.01661 SPECIAI. CONDmONS
- 1. Multipliers In determinadon of the muluplier it is the responsibility of the customer to advise the Uttitty within 15 days following any change in the number of residential dwelling units wired for service.
- 2. Miscellaaseus Leeds: Miscellaneous electrical loads such as general lighting, laundry rooms, gen.
eral maintenance. and other almtlar usage incidental to the operation of the promises as a muld-family accommodadon will be considered as domeetto usage.
- 3. Non residential Energy: Electric energy for non<!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 Comeract For austomers who use service for only part of the year. t. ate schedule is appil.
cable only on an annual centract.
- 5. Lifeline Reess: Lifeline rates are applicable only to reefdential usages billed under a schedule appli.
cable to service for dorseede uses. The Ut!!!ty may require the customer to complete and file with it an appropriate Declaration of Eligibility for Lifeltne Rates.
a (conunued) g l (
)
Advice Letter No. 731.E Issued by Date FiledApri1 13, 1979 Decision No.
W. M. Gallavan Effective May 15, 1979 Vice-President-Rates and Valuatiot Resolution No. E-183b Di Y
$.ccG$ Mumm' E-25
ca.e.
no....
Pacifie Oas and Electric Cocpany Revised Cal. P.U.C. Sheet No. 0957.E San Francisco. California Canceling itevised Cal. P.U.C. Sheet No. 6870-E m
Sclnedule No. DS MULTI.PAMILY SERVICE (Coasismed)
SPECIAL CONDITIONS (Ceesimuod):
- 6. Lifeline U.ege The following quantidee of electricity are to be billed at the rates for lifeline usage:
Mamably Kwbr Allowaace End Use fee ciasade Reeds
- Code W
X Y
Z Per PWI Unia Basic Allowance **
B
$40 340 240 See Basic plus Water Heating W
490 490 490 490 Basic plus Space Hosting Summer (May 1 to Oct. 21)
H 240 240 240 340 Winter (Nov.1 to April 30)
H 790 1.040 1.300 1.640 Baste plus Space and Water Heating b.: umer (May 1 to Oct. 31)
C 490 400 400 490 Winter (Nov.1 to April 30)
C 1.040 1.296 1.010 1.310 Non lifeline N,
0 0
0 0
Air Conditiontag Allowance - additive to above a!!owances May 1 to October 31 inclusive:
Territory A 200 RM Territory B 330 Eksergy used in eseese of the lifeltne allowances will be billed at the nemlifeline rates, continutng from the quantity reached by the lifeline allowances.
- Climatie Beads are described in the Preliminary Statemeat
- Includes lighting, cooking and refrigeration.
A reeldential user of electric service in a mulbaantly seeemmodation, who
- y. Lif Devices:
cert 18ee in una that regular use of a enedicallife support device. as deemed la Rule No.1. la essential to maintain tbo life of a fullume reeldent of a reefdenual unit. le eligible for a uniform monthly lifeuse i
allowance in addition to those allowances shown in 8pecial Coedition 8. The namount of the addittomal allowance will be detenmined by the Utility from load and operating time data. The Utility asay require cert 1Scation by a doctor or osteopath licensed to practice anodiciae in the State of California that a particular device is necessary to sustain the user's !!!e.
- s. Sew Rene Onsages: Bills for service which include lifeline allowances for space heatias and air conditioning will be prorated in the May and November billing periode 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 pertad.
- 9. Three Phase Service: Three phase load will be supplied servlee under tWe sehedule for umulti.
family realdential customere who were supplied three phase servlee on a general service sehedule on August 27.1978.
l l
Rl Advice Letter No. 711.E Issued by Date Filed Decestber 6,1978 1
Decision No.
W. M. Gallavan Effective January 5, 1979 Vice. President-Rates and Valuation Resolution No.
9\\
\\
9
.s.eaoe
. m Pacifle Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7043-E San Francisco, California Canceling Origmal Cal. P.U.C. Sheet No. 7000.E Schedule No.DT MULTI. FAMILY SERVICE - MOBILEHOME PARK APPLICABILITY This schedule is applicable to service for domestic lighting, heating. cooking and single-p'hase power service supp11rd to multi-family accommodations in a mobilebomo park through one meter on a single premises and submetered to allindividual tenants in accordance with Rule No.18.
TERRITORY The entire ierritory served.
RAT 1iS 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.
Custoiner Charge No change.
Energy Gorge (in addition to the Customer Charge):
The kilowatt hours for all blocks shall be multiplied by the number of mobilehome spaces wired for service.
Adjusanents:
Adjustments, as specifed 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 Kwbr Lifeline Non-Lifeline Energy Cost Adjustment
$.01003 5.01722 Tax Change Adjustment
(.00071)
Total 5.01003
$.01651 SPECIAL CONDITIONS
- 1. Multipliers In determination of the multidler it is the responsibility of the customer to advise the Utility withis 15 days following any change in the number of mobile homes wired for service.
- 2. Miscellaneous Loads: Miscellaneous electricalloads such as generallighting, laundry rooms. gener.
al maintenance. and other similar usage incidental to the operation of the premises as a multi-family accommodation will be considered as domestic usage.
- 3. Non-residential Energy: Electric energy for non-domestic enterprises such as rooming houses.
boarding 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 applicable only en an annual contract.
- 5. Lifeline Rates: Lifeline rates are as,pticable only to residential usages billed under a schedule applicable to service for domestic uses. The Utility may require the customer to complete and 81e with It an appropriate Declaration of Eligibility for Lifeline Rates.
(continued)
Advice Letter No. 734.E Issued by Date FiledApri1 13,1979 Decision No.
W. M. Gallavan Effecti e Ma_y 15, 1979 Vice. President-Rates and Valuation Besolution No. E-1836 m-
]
es.esee no.et Paciac Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7044.E 1
San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 6M O O Lharfule No. LS.1 STREET AND HIGHWAY LIGHTING APPflCABILITY This schedule is applicab;e to Utilityewned and maintained Ifghting installations which illuminate streets, highways, and other public<!edicated outdoor ways and places and which generally utilize tne Utility's distribution facilities. Rates of Class A through Class F service will be appitcable as determined in Special Condition 4.
TERRITORY The entire territory served.
RATES AII Nisht Rates Per Imp Per Month Half. Hour Case A
B C
D E
F Adjustment Nominal Lassp Rating Incandescent Lampe*
Waas Lamens 58 600
$ 3.208 8.045 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*
Averese Lamp Line Initial Watts Watts Lumens 100 124 3.500
$ 5.343
$ 4.617
$ 3.723
$ 8.748 8 8.275 8 6.660 8.080 175 198 7,500 6.229 5.528 4.870 9.415 9.199 7.574
.127 250 285 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 "S
700 766 37,000 16.447 14.5 9 19.437 19.062
.493 1.000 1,088 57,000 21.103 13.6 d3 24.402 23.673
.639 Hish Pressure Sodium Vapor Lampo Aversee Lamp Line Initial Watts Wette Lumens 70 85 5,800
$ 6.163
$ 5.424* $ 4.53*
$ 8.970
$ 8.*!1 8 7.148 5.047 100 121 9,500 6.879 6.135*
4.890 9.440 9.243 7.644
.068 150 176 16,000 1.600 6.862*
5.749 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
.182 400 487 46,000 12.054 11.315*
10.182 14.713 14.276
.275 More than one IJaht on 5 pole Where more than one !!ght is installed on a pole, all lights other than the first will be billed on the Class C rate. Not applicable to installations made prior to September 11.1978.
Adjusanents:
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 kilowatthocr and a Tax Char 3e Adjust-ment of a negative 1.5s/, applisd to base rates, Pole Charse:
For Class A and D pole installations using other than wood poles that were installed entirely at Utility expense, customer will pay a monthl/ pole charge of $3.151 or $2.60 for installations made prior to September 21,1975 (closed to new installations).
For Class A and D 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 w!Il pay a monthly pole charge of $1.351 or 30.00 for installations mada prior to September 21,1975. (Closed to new installations.)
- Closed to new installations as of June 8,1978, erwt where Utility and customer shall agree, mercury vaporlamps may be installed under Class A and C to provide compatibility with existing light sources.
(continued)
Advice Letter No. 734.E Issued by Date Filed Apri1 13,1979 Decision No.
W. M. Gallavan Effective ~ Ray 15, 19/9 Vice. President-Rates and Valuation Resolution No. E-1836 b _
es.
- o. ses Revised Cal. P.U.C. Sheet No. 6872 E Pacific Gas and Electric Company San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 6752-E Schedule No. IS 1 STREET AND HIGHWAY LIGHTING (r%.- J)
SF9CIAL CONDmONS
- 1. Trpe of Sarricer The Utility reserres the right to supply either " multiple" e " series". se., rice.
Series service to inew lights will only be made where it la practical from the Utility's engineering stand-point to supply them frou existing series systems.
- 2. Anamet Opersang schedules The above rates for All-Night service assume an average of approxi.
mately 11 hours1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br /> operstitt Der night and apply to lamps which will be turned on and off once each night
~
in accordance with a regulae 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. Opersang Schedules Other 'Ihm AllNishes Rates for regular operating schedules other than full All-Night will be the All-Night rate plus or minus, respectively, the half-hour adjustment for each half.
hout more or lose 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 lees than 1.096 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-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 amore than 4.500 hours0.00579 days <br />0.139 hours <br />8.267196e-4 weeks <br />1.9025e-4 months <br /> per year.
- 4. r-- % - _ el Semco Provided:
Cass A Utility owns and maintains luminaire. control facilitiee. support arm, and service wiring on its existing distributton pole, and alllights formerly served under Schedule LS 1, Class A.
as of September 11.1978.
Q es B Ut!!!ty owns and maintains luminaire, control facilities, support arm. pole or post. founda-tion and service connection and where customer has pald the estimated installed cost of the luminaire. support arm and control facilities (applicable only to installations in service as of September 11.1978.
Qass 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. owned poles comply with the Utility's engineering and operating requirements.
Case D Utility owns and maintains its standa211 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.
Case B Utility owns and maintains its standard luminaire. control facility inttinal pole wiring.
service connection, galvanized steel pole and foundation where the customer has paid to the Utility the estimated installed cost of the pole, support arm and foundation.
Q es F Utility owns and maintains a standard luminstre, control facility. support arm, and service connection on its wood pole or post. Installed solely for the luminaire.
- 5. Rearranesawsw of Facilities: At the customer's request the Utility will make changes to or rear.
rangement of existing facilities at the customer's expense.
- 6. U '
-__l Service: The applicant at his expense shall perform the necessary trenching, backall d paving, and shall furnish and install all necessary conduit and substructures including substructuren i
E' transformer installations if necessary, for street lights only in accordance with the Utility's specif1-cativas. Upon acceptance by the Utility, ownership of the conduit and substructures stall vest in the j
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 service is 100 circuit feet or less per luminaire.
as measured from the point of connection to the point of secondary supply. For service 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.
(continued)
Advice Letter No. 688-E Issued by Date Filed sect. 6, 1978 Decision No. 89316 W. M. Gallavan Effective sept. 11, 1978 Vice-President-Rates and Valuation Resolution No.
es.ese
. m Paside Gas and Electric Cotapaniy Revised Cal. P.U.C. Sheet No. 6873-E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 6752-%
Schedule No. LS.1 STREET AND HIGHWAY LIGHTING SPECIAL CONDITIONS (Comanned)
- 7. Ownse hip: All facilities installed under this schedule except for the Class "C" customer 4wned pole or post. support arm and foundation shall vest in the Utility.
- 3. M. wanence: The Utility shall exercise reasonable care and diligence in maintaining Utility.
owned ts. des. Maintenance will be performed as an accommodation on a customer owned Class "C" pole or ;
- d. arm and foundation. at the customer's expense, where customer is unante to obtain the service euewhers. Where the Utility experiences or expects to experience maintenance costs exceeding its normal maintenance expense, resulting from but not limited to vandalism, or unusual non standard design of pole, poet, or Inminafre, the Utility may require the customer to pay excess maintenance costs as may be necessary.
- 9. Spedal ".-
s im=fanfree, poles. Poets and other equipment, requested by a custon:er or applicant, in addition to or in substitution for the Util"y's standard salvantsed steel poles, gstvantzed steel posts, photocell controls and equfpment. will be provided if such equipment meets the Utility's engineering and operating standards and if the customer or applicant pays the cost difference between 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 d!!!erence.
10 Ikas Emssesions: Where the Utility determines that it is necessary to extend its electric distribu-tion lines te 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 exteaston, ex-clasive of servies conductors (and transformer if required), under the provisions of Special Condition 9.
The Utility may 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 potat, or in the case of underground facilities, where the first-service de-livery point is no groster than 300 feet from the Utility deelsnated connection point. The coat difference a
used in calculating the cor.tinuing monthly payment as specifled in Special Condition 9 will be reduced by an amount equal to any Electric Rule No.15 refund, and the continuing monthly payment shall be ad.
justed accordingly.
- 11. Tamsperary rh.d==- et sordos: (F1sture remaks in place) At the request of the customer the Utility will temparerity discontinue service to individual lunatamires provided the customer pan a facility charge equal to the all-night rate, adjusted to 0 burning hours under the provisions of Special Condition 3, plus the esH==*a4 cost to disconneet and reconnect the light.
- 12. Cseerect: Service to each Ilght installation shall be for an initial contract term of 5 years and shall automatically continue thereafter from year to year. The initial term shall commence wben perma-nont service is Srst rendered or within 90 days of when the lights are Arat ready for service whichever occurs first.
I 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.
U E-JO D
I
..e PaciSo Gas and Electric Conspany Revised Cal. P.U.C. Sheet No. 6936-E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 6895-E U
Scbedute No.LS.2 STREET AND HIGHWAY LIGHTING APPfJCABIIIIY This schedste is app!! cable to serv!ce to lfghting installatjons which illuminate streets. h!shways, and other publicly <!edicated outdoor ways and places where the customer usually owns the !!ghting fixtures.
poles and interconnocuar circuits. The customer's facilities must be of good construction acceptable to the Utility and la satisfactory soadluon to qualify for Class B or C rates, i
TERRETORY The entire territory served.
RATES Rase per Lamp pee Month Qass A
B C
Ut1Utrsupplies energy Utility suppIIes the on-Utility suppiles the en-and switchlag' service ergy, switching *, and orgy, switchlag*, and
- only, maintenance servlee maintenance service for for lamps and glase-entire system including
- ware, lampe and glassware.
A B and C Half. Hour AB-Nisha AB-Nisbe AB.Nisbe Adjusamment Nominal Lamp Rating:
Incaedeseest Lampe Watas Lamome**
32 1.000 8 1.560 8 2.249 8 2.899 8.071 189 3.500 3.168 4.005 4.455
.144 295 4.000 "
- 4.971 5.858 8.508
.226 406 6.000
- 6.824 7.710 3.360
.310 620 10.000* "
10.430 11.435 12.005
.475 860 18.000*"
14.475 15.898
.440 Lew Pressue. Set.insa Vapoe !.aspe Averess O
b/
Lamp Line Initial Werts Weens Luanas" 35 68 4.800
$.862 8.039 55 90 8.000 1.114
.051 90 148 13.500 1.832
.083 135 205 31.500 2.552
.116 180 256 38.000 3.163
.143 Hish Pressure Sedimen Vepse Lampe 120 Volts 70 85 5.800 8 2.041 8 1.839 8 2.489 8.047 100 121 9.500 1.491 2.338 2.989
.068 150 176 18.000 2.173 3.020 3.670
.099 240 Volts i'0 98 5.800 8 1.221 8 1.802 8 2.453 8.055 100 144 9.500 1.797 2.378 3.028
.082 150 205 16.000 2.552 3.133 3.783
.116 200 263 22.000 3.270 2.881 4.531
.149 250 321 25.500 3.388 4.599 5.249
.182 400 417 46.000 6.037 6.648 7.296
.275 Mesal Holide Lampo 400 4Es 30.000 8 5.822 8.*65 1.000 1.118 90.000 13.871
.632 Mercury Vapee Lampe 100 1*9 3.500 8 1.757 8 2.**9
- 82. 9 8.080 175 198 7.500 2.779 3.251 3.901
.127 "50 285 11.000 4.005 4.606 5.256
.182 400 451 21.000 6.374 6.975 7.625
.291 700 786 37.000 10.828 11.951 12501
.493 1.000 1.088 57.000 15.364 16.555 17.*06
.699
- Switching Service is closed to new Installations.
" Latest published informatles should be consulted on best available lumens.
"* Services forincandescent lampe over 3.500 lumens will be closed to new installations after September 11,1978.
(continued)
N. hire Ten.r.W. 721.E Issued by Date Filed rebruary 2, 197?
l; -i G n W - " 16 W. M. G allaran Effective retrua}f 2, 19 0 Y:ca-Pre i.h nt-Rates and Vsbwi..n Roolutio
- DMD
,m n p N lh 3);A Unb E-31 MLji
ea.eees no. w Paci8e Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7045.E San Francisco, California Canceling Rensed Cal. P.U.C. Sheet NoJfsFS O
Schedule No. LS.2 STREET AND HIGHWAY LIGHTING (Continued)
RATES (Continued)
Adjustmeois:
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 5.01722 per kilowatthour and a Tax Charge Adjust-ment of a negative 1.5% applied to base rates, SPECIAL CONDITIONS
- 1. Type of Servics: This schedule is appI! cable to multiple Ifghting 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. Mult!ple current will normally be supplied at 120/240 volt *, single phase. Unless otherwise agreed, series current will be delivered at 6.6 amperes. Single-phase service from 480 volt sources and series circuits will be available in certain areas at the option of the Utility when this type of service is practical from 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 lights will be made only when it is practical from the Utility's engineering standpoint to supply them from existing series systems.
- In certain localities the Utility may supply service from 120/208 volt, star connected, polyphase lines in place of 240 volt service.
- 2. Annual Operating Schedules: T' e 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 night and apply to lamps which will be turned on and off once each night in accordsuce 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 ynr.
- 3. Operating Schedules Other Than A!I.N t: Rates for regular operating sc'ledules other than full all-night will be the AllNight rate plus or gus, respectively, the half hour adjustment for each half.
q 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 adjusunent 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 haura per nfght, nor more than 4,500 hows per year.
- 4. Point of Deinery: Delivery will be made from Ut!!!ty's existing electric lines without extension thereof to customer's system at a point or points mutually agreed upon except as provved 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 customer owned 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 w!re to the Utility's overhead lines at the customer's expense, or (2) at the customer's option, the Utility wil!
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 yrill be supplied from overhead facilities at 480 volts, single-phase, for an interconnected group of lamps provided the total connected load of the interconnected group of lamps to be so served is not less than 8 kw. For a customsrowned interconnected system of less than 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.
- 3. Undersround Service Connection: The Utility will provide an underground service connection at its egense from either its overhead or underground 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 electrollers in the group and (3) there is not less than 3 kw connected load. This service connection shall not exceed 25 feet of underground run from the base of the Utility's pole in an overhead line nor exceed 40 feet of underground run from a location where service is available in an un$erground system. The Utility will extend the underground l
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 shal! Install and own the extension from his system or electroller to the Utility's distdbution system when service is readily available and shall pay the cost of connecting to the Utility's distributton system, including any necessary conduit or riser material.
i (continued)
A Advice Letter No. 734.E Issued by Date Filed April 13, 1979 Decision No.
W. M,0allaven Effective May 15, 1979 Vice. President-Rates and Valuation Resolution No. E-1836
u.uu no. see Paciac Gas and Electric Company Ravised Cal. P.U.C. Sheet No. 6876-E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 6333-E p\\
u g/
Schedule No. LS-2 STREET AND HIGHWAY LIGHTING (Continued)
- 6. Swiuldag: Where the connected street !!sht 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 month for each circuit sepa-rately switched by the Utility, except where switching facilities have been installed by the Utility for its convenience.
- 7. W=m--s (a) The Class B and C rates include all labor and material necessary for the inspection, cleaning, or replacement by the UU11ty of lamps and glassware, and are limited to certain glassware such as is commonly used and manufactured in reasonably large quantittee. A suitable extra charge will be made for maintenance of glassware of a type entalling unusual expense.
(b) Under the Class C rate the Utility will:
(1) Paint the poles as required to maintain good appearance. Where the customer +wned poles are of a material which does not require painting. the Class C rates will be reduced by 30.15 per lamp per month. On multi-lamp installations where painting is required, the rates will be reduced by $0.15 for all lamps other than the fLrst cne.
(2) Isolate any trouble in the customer's system which has resulted in an outage or dimin.
lehed 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 replacement of material such as ballasts, photo electric controls, relays,8xtures, individual poles, individual cable runs between poles where such runs are in conduit, and other individual parts of the system. The customer shall compen.
sate the Ut111ty for any material furnished by the Utility. The Class C rate does not pro-vide for any major excavation or any major replacement at Utility expense of circuits, conduits, poles, or fLxtures owned by the customer.
(c) This schedule does not provide for maintenance to low pressure sodium vapor or metal halide lamps: however, at the request of the customer, the Utility will perform any of the routine
(,\\)
standard maintenance equipment and procedures can be used.
maintenance described above on a time and material cost beets provided the Utility's regular
,w
- 3. Sy seems Owned in Part by the Utility:Where, after the date this proviston is first effective, the Ut!!ny installs and thereafter owns and maintains any portion of the fLxtures, poles, circuits. or other facilities that comprise 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 testalled prior to the date this provision is Bret effective, the additional monthly charge will be 1%% of such ocot*. Customer or others may elect to pay the Utiltty's cettmated installed cost of such facilities, in which event the additional monthly charge will be 1% of such cost.
- 9. I.Ine t---: Where, after the date this provision is Srst effective, the Utility extends its elec.
s 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 lar, of such cost. The Utility may waive 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 is required. lf such extension, or any portion thereof, is utilized 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 deter.
mining 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 Rule No.15,an excess free footage allowance remm1no after the new load is installed, all or part of the advance will be refunded without interest to the customer. These refunds will be computed by converting the amount of the advance to an amount per foot and maltiplying 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 load will be made h turn as provided in Rule No.15. No payment will be made in excese of the original amount advanced.
- 10. Street Uslet f -- ; '--- N sad Non. Standard Racings: 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 lamps having wattage and operating life ratings within 37, of those spectaed in the EEI NEM A Standards for Filament Lamps Used in Street Lighting. Where Class A service is supplied to tamps of other ratings than those spec 18ed in EEI NEMA Standards an adjustment will be made in thelamp rates proportionate to the difference between the wattage of the lamps and the standard lamps of the same lumen rating.
- Ezeept for facilities installed prior to February '.3,1971, in which case the monthly charge will be 1%%
G V Advice Letter No. 668.E Issued by Date Filed samt. 6, 1978 Decision No. 89316 W. M. GaHavan Effective s ee. 11. 1978 Vice. President-Rates and Valuation Resolution No.~
b M
nosee no. us Paci8e Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7046-E San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. Woe O
Schedule No. LS.3 STREET AND HIGHWAY LIGHTING l
ELECTROLIER METER RATE APPf3CABfDTY Applicable to service to electro 11er lighting systems, excluding incandescent luminaires, which illuminate streets, h!ghways, and other publicly dedicated outdoor ways and places where the customer usually owns the !!ghting fLttures, poles and interconnecting circuits, and the Ut!!!ty furnfsbes energy at one or more central points.
TERRTTORY The entire territory served.
RATES Per Meter Per Month Service Charge 33 00 Energy Charge (In addition to the service charge)
First 150 kwbr per kw of billing demand
.0393 Over 150 kwhr per kw of billing demand
.0120 Switchlag Garge*
For each circuit switchad 3.25
' Switching Service is closed to new installations.
Adjusanoness 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 tnounts are as follows:
perin.fic m
Energy Cost Adjustment.
5.0t722 Tax Change Adjustment
(.00071)
Total 3.01651 SPECIAL CONDfTIONS
- 1. Type of services This schedule is applicable to naultiple lightlag systenne to which the Utility will deliver current at secondary voltage and to sortes street lighting systems for which the Uttlity will fur.
nish constant current regulating transformere. Multiple current will normally be supplied at 120/2 t0 volts',
single phase. Unless otherwise agreed, series current will be delivered at s.$ amperes. Bisgle phase service from 480 volt sources will be available in certain trees at the option of the Utility when this type of service is practical from the Utility's engineering standpoint. All currents sad voltases stated herein are nominal, reasonabie triations being permitted.
New lights will normally be supplied as multiple systems. Bertes servise to new lights will be made only when it is practical from the Utility's engineering standpoint to supply them from estating series systems.
j
- !n certain localities the Utility supplies service from 120/208 volt, wyeconnected, polyphase lines in place of 240 volt service.
- 2. Polme of Delivery: Delivery w!!! be mande from the Utility's existlag electrie 11aea without extension l
thereof to customer's system at a point or points mutually agrood upon escept 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 lampe having a connected load of less than 2 kw (1) the Utility will connect the customer's overhead servios wire to the Utility's overhead lines at the customer's expense, or (2) at the custonner's option, the Utility will in install, own and maintain the overhead servlee provided the customer pays the tatual cost of the servlee plus 1% per month of such initial cost. When 480 volt service is desired by the enstomer, energy will be supplied from overhead fact 11ttee at 480 volts, stastwhase for an tutor.
connected groep of lampe provided the total connected load of the interconnected groep of lamps to be so served is not less than 8 kw. For a customer-owned interconnected system of toes thas 8 kw but not l
less than 2 kw, energy will be supplied at 120/240 volta unless the customer pays the addittomal cost of I
a 480 volt supply.
l (continued)
O Advice Letter No. 734.E Issued by Date Filed April 13, 1979 Decision No.
W. M. Gallavan Effective Ma-1b. I'3 / 9 Vice. President-Rates and Valaation Resolution No. E-163b 1% q ki E-3'4 rw#A=
l es ee a no. n Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 6750.E San Francisco, California Cancelitig Revised Cal. P.U.C. Sheets Nos. 6723 6014.E
'r i
(\\ -
J Schedule No. OL-1 QUTDOOR AREA LIGHTING SERVICE (Continued)
- 4. Service Connection:
i (a) A service connection will be made from the Utility's existing electric lines, either overbead a l
underground. at a point mutually agreed upon, without extension thereof except as provided in Special Condition 5.
(b) Where an overhead secondary circuit ir resdily available, the Utility will mnke a cociplete overhead service installation at its expense. If a secondary circuit 19 not available, or where add!.
tional facilities are required to complete the installat!on, such will be provided as speci8ed in Special Condition 5.
(c) Where underground service is supplied, the app!! cant shall install and own the pole, includ:ng any internal pole and mast arm wiring. Where underground service is supplied from an overhead distribution sy: tem, the applicant shall furnish and install conductors and any necess.try cun.Init between the base of *be Utility's distribution pole whero service la 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 Utility at the applicant's expense in accordance with Special Condition 5. The applicant shall pay to the Utility the material cost of the pole riser, including condult, molding and other materials, but excluding the cost of the riser conductors, and the Utility will complete t is riser installation at its expense.
- 1) Where underground service is supplied from an unJerground distribution system, the april-
-ant shall furnish and install conductors and any necessary conduit between an existing secondary
' ice box or other suitable point of connection as 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.
S. Additional Focilities: Facilities such as secondary circuits. transformers and associated equipment required in addition to the Facilities 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 monthly charge of 1% of such cost.
kM 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 u! ma:d additional facilities at its expense under its rules, all or a portion of the applicant's advance will be refunded without interest following the connection of such new load. Refunds will be based on the footsge by which the allowable free length under Rule 15 B.1. for such new load exceeds the lengths of line,if ary, required to serve, multiplied by the unit cost per foot specited in Rule 15 B.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 or Reasoval of Facilities:
(a) When the Utility's distribution facilities from which service is supplied hereunder, and/or the lighting facilities installed hereunder, are to be relocated or removed at the customer's request or to comply with governmental requirements. the Utility shall have the right, upon written notice, to discontinue the service being furnished under this schedule without obligation or liability. Service may be re-established in accordance with the Special Conditions of this schedule.
(b) When the lighting 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 racilities by others, the Utility shall be paid the cost of such relocation or modtScation.
(c) If the lighting faellities installed hereunder are made idle or are removed before expiration of the initial term of the effective contract. the customer shall pay to the Utility 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 hereunder must be acceselble to the Utility's vehicles for installation and maintenance,
- s. Me'-
Except in the case of emergency, maintenance of lamps and equipment will be performed only during normal working hours within a reasonable period following notification by the customer of the need for such maintenance.
- 9. Centracts A written contract in form on file with the California Public Utilities Commission may be required for service under this schedule for a period not to exceed three years.
,t
[h k
)
Advice Letter No. 669.E Issued by D te Filed my 9, 1978 V'
Decision No.
W. M. Galla van Effective June 8, 1978 Vice-President-Rates and Valuation Raolution No.
l E-35 D ]ah M M[ &ku
%) f 4
D
Es4s44 ho s37 PaelSe Oas and Electric Company Revised Cal. P.U.C. Sheet No. 6878.E San Francisco, Nafornia Canceling Revimi Cal. P.U.C. Sheet No. 6030.E A
O Schedule No. LS.3 STREET AND HIGHWAY LIGHTING ELECTROLIER METER RATE (Continued)
- 3. U "
. ' Service fb-t. m 'Ihe Utility will provide an underground service connection at its expense from either Sta overheaa of underground 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 electrollers in the group, and (3) there is not lees than 3 kw connected load. This service connection shall not escoed 26 feet of underground run from the base of the Utility's pole in an overhead line nor exosed 40 feet of underground run from a location wherv service is available in an underground system. The Utility will eatend the underground service beyond the free length at the customer's request in accordance with Special Condition 7.
Where the customer requests an anderground servloe to a system of less than 10 electrollere or 3 kw of connected load the customer shall 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: Bach pc*nt of delivery to an electrotter etrenit or circuits will be metered and billed i
separately. The meter will be located at a suitable location. The billing demand will be based upon the connected load or t;pon the metered demand, but will be not less than 3 kw.
The connected load upon which the enerry charges will be based will be the sem of the ratings of all lampo that may be connected to the system r se the wattage losses for the associated ballasts. computed to the nearest on+4eath kw. All lamps and tv lasts will be counted at the manufacturer's nameplate or catalog rating in kw (one kw equivalent to sa kva). or at ratings determined by test.
I S. Swkchlag: Switching service will not be provided by the Utility for systems connected after l
September 11.1978.
- 6. Mai
- : This schedule does not contesaplate maintenance within the rates se shown above.
l However, at the request of the customer, the Utility will replace lamps and glass or unit coverings, haltaats, and do other normal system maintenance on a ttmo and material cost besta provided the regular standard maintenance equipment and procedures can be used.
- 7. Syneeses Owned la Past ley the Utila'rys Where the Utility installs and thereafter owns and maintains any portion of the fixtures, poles, circults or other facilitsee that comprise enetorner's street lighting system, an additional monthly charge of 3% of the Ut111ty's estimated installed cost of such factittles will be made. If such fact 11ttes were installed prior to the date this provision is first effective, the addi-tional monthly charge will be 1%% of such cost. Customer or others may elect to pay the Utility's estl.
mated installed cost of such fact!!tles, in which event the additional monthly charge will be 1% of such cost.
- 8. Line Essessions: Where the Utility extends its electric linee to serve customer's street lighting system, an additional monthly charge of 3% of the Utility's estimated Installed cost of such line exten.
sion. exclusive of service connection (and transformer, if required) furnished under Special Condtttons j
- 1. 2, and 3 will be made. If customer elects to advance the Utility's estimated installed cost of such esten-ston the additional monthly charge wt11 be 1% of such cost. The Utility nasy waive the foregoing 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 excess free length of line is allowed unior Rule No.16. 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 a!!owance for the new load. If any, as compared to the length of the original extenston. If an advance has been made as provided above, and if under said Rule No.15. an excess free footago allowance remains after said new load is installed. all or part of the advance will be l
refunded without interest to the customer. These refunds will be computed by converting the amount of the advance to an amount per foot and multiplying the excess free footage by this ut.it 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 le 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 ad-vanced.
R Advice Letter No. 688.E Issued by Date File %ept. 6,1978 Decision No. 89316 W. M. Gallavan Effective Sept. 11, 1978 Vice President-Rates and Valuation Resolution No.
es.eese me.m Pacifle Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7047.E (g[
San Francisco, California Canceling itemed Cal. P.U.C. Sheet No. 6989.E v
v Schedule No.TC 1 TRAFFIC CONTROL SERVICE APPLICABILITY Applicable to meiered service for traffic directional sign or signal !!ghting systems owred by govern.
mental agencies and located on streets. highways and other public'.y dedicated outdoor ways and places.
~
TERRITORY The entire territory served.
RA'IES Per Meter Pee Manch Service Charges For each Service Connection
$1.50 Energt Charge (in addition to the Service Charg:):
All kwhr. per kwhr
.03 Minimum Charge:
$1.50 per month.
Adjustmenas:
Adjustments as specffled in Parts B and C of the Preliminary Statement, will be added to each bill for service calculated at the above rates. Including bille for minimum charges. Adjustment amounts are as follows:
per kwhr Energy Cost Adjustment.
$.01722 Tax Change Adjustment
(.00071)
Total 5.01651
)
SPECIAL CONDITIONS
\\
v'#
- 1. Type of Service: Energy will normally be suppited at 120/240 volt single.pbase service (120/203 volte star in certain localities) unlees the customer pays the additional initial cost of a 480 volt supply.
However, service from (80 volt sources from underground systems will be made ava!!able only for new servlee connections at the option of the Utility when this type of service is practical from Utility's engt.
neering standpoint.
- 2. Point of Delivery: Delivery will be nsade from Utility's existing electric 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 Utility 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 iTtility's nearest junction box or to the base of the pole where service is readily available and will pay t' -
..t of connecting to the Utility's distribution system.
Including any necessary conduit or riser teateria
- 4. Masertag: Each point of delivery will be metered and billed separately. The meter 1:111 be at a suitable location agreeable to the Utility.
- 5. Switching and Maintenee e Switching and ma!ntenance will be performed by the customer.
- 6. Line Extensions: Where after the date thte provision is first effective. the Utility extends its ele trte lines (overhead or underground) to serve customer's system, an additional monthly enarge of 1%% of the Utility's estimated installed cost of such extension, exclustre of meter, service connection, and trans.
former, if required, furnished under Special Conditions 1. 2 and 3, will be made. If such extension was installed prior to the date this prov!ston is effective, the additional 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 Utiltty may watre the foregoing provisions where the exten, ston is cettmated to be of nominal cost and where not more than one pole and one span of line is required.
If such extenston, 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.115. such cost to be used in deterrunning 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 such 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 refunds will be computed by converting the amount of the advance to an amount per foot and multiplying the excess free footage by the unit per foot. Such refunds if any. will be made follow.
Ing 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 fron. new load will be made in turn as provided in Rule No.15.
No payment will be made in==== of the original amount advanced.
n)
J Advice Letter No.734 E Issued by DateFiled Apri1 13,1979 Decision No.
W. M. Gallavan Effective May 15, 1979 Vice-President-Rates and Valuation Remit tion No. E-1836., n
...e
- o. o..
Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7048.E San Franelseo, California Canceling Revised Cal. P.U.C. Sheet No. tho O
Schedule No. P.4 OIL REFINERY ELECTRIC AND STEAM SERVICE APPUCABIIJrY This schedule is app!! cable to customers receiving polyphase alternating current electric service and 160 pounds per square inch steam service for the opersuon of petroleum refinerlos under contracts authorized by the Public Ut111 des Commisalon of the State of California, TEll2ITORY A-The oil refinery in the vicinity of the Martines Power Plant.
B-The oil refinery in the vicinity of the Oleum Power Plant.
C-The oil refinery in the vicinity of the Avon Power Plant.
RATES Electric Services The rates for electric service to each metering potat will be the rates and charges, including Ge Energy Coat Adjustment, of Schedule No. A.13 or A 23. as appropriate in accordance with the Applicability clauses thereof.
Sseem Service Demand Charges For a monthly maximum demand not to exceed Per M a ch 335.000 pounds per hour M 6004@
Quamelty Charge (in addition to the Demand Charge):
Money Amount:
Per 1,000 k First 125,000,000 pounds per mona 2.0d All Excess 1.5 Fuel Amount -
.368 bbts.
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-u) sescrAt coNDmONS
- 1. Feedreser: The customer will deliver to Utility at said steam plants a quantity of feedwater which will in pounds equal the pounds of stessa delivered, sub}ect to the speciRestions mutually agreed to by the parties.
- 2. Centract: Se Ice supplied hereunder shall be in accordance with contracts authorized by the Public Utility Commission of the State of California. This rate schedule, or parts thereof, shall expire upon termination 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 Utilities Commission of the State of California shall govern with respect to each of the customers served j
hereunder, notwithstanding any inconsistency with this tartif schedule.
- 3. Mamanness Desmand The maximum demand la any month will be the maadmum average power taken during any 30wminute interval in the month, but not less than the difere18ed resistance welder load computed in accordance with Rule No. Il provided. that in cases where the use of energy is intermittent i
or subject to violent Suctuations, either a 5 minute or a 15. minute interval may be used.
- 4. Billing Demnands The bD11ag demand to be used la computing charges willbe the mean of the mari.
mum demand as deternained under Special Condition 3 for the current month and the highest such do.
maad occurring in the year ending with the current month, but not less than 1,000 kw.
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- 5. Of peak rhJ All customers will for billing purposes. have macmum demands ignored which coeur between 10:30 P.M. and 6:30 A.M.of the following day and on Sundays and the following holidays:
New Year's Bay, Washington's Birthday, Memortal Day, Independence Day,14bor Day. Veterans' Day.
O, Theakasivtag Day and Christmas Day, as said days are spec 18ed in Public Law 90-863 (U.S.C.A. Section 6104)
- 6. P%er Factor: The total charge for any month as computed on the above rates will be decreased orincreased, roepectively, by 0.1% for each 1% that the average power factor of customer's load in the month was greater orless than 864 such average power factor to be computed (to the nearest whole per cent) from the ratio of lagging kilovolt ampere hours to kilowatt hours consumed in the month.
- 7. Valsass Adjamenmane: The above charges are applicable withoct 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 voltage. When delivery is made at the standard primary distribution voltage at 2 kv or above available in the area fresa the Utility's distributton line er, where the Utility has glected 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 prcperty, the above charges for any month will be reduced by 15e per kw of Miling demand in the month. When delivery is made at transmis vt voltage (60 kr and above), the above charges for any month will be reduced by 26d per kw of bill' mand in the month. The Utility retains the right to change its line voltage at any time, after reasc..,... advance notice to any customer reestving a discount hereunder and mRected by such change, and such customer then has the option tri change his systema so as to receive service at the new line voltage or to accept service through trans.
ferssere to be supplied by Ut!!!ty subject to the volthge adjustment above.
l Advice Letter No. 711.E Issued by Date Filed December 6,1978 Decision No.
W. M. Gallavan Effective January 5, 1979 Vice. President-Rates and Valuation Iksolution No.
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O. IsA Pacifle Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7049.Fg San Francisco, California Cnneeling Revised Cal. P.U.C. Sheet No. 6990 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 to residential and commercial service, nor to service to which Schedule No. A 23 is appifcable. Rate A shall apply to all single-motor instanations with a connected load. rated less than 35 horsepower and to all multi-load installations aggregating less than 15 horsepower or kilowatts.
Rate B shall apply to all single motor installations rated 35 horsepower or more, to all multi-load instal-latlons aggregating 15 horsepower or k!10 watts 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 foregoing, may thereafter either continue such nos.
conforming service or request a change to the applicable rate, at their option.
_TERRrrORY The entire territory served.
RATES A-Connected Load Basis.
B-Maximum Demand Baste.
Per Meter Service Qiarse, per customer per month 3 2.50 Per hp or kw, per monn 8.60 Energy Charme (in addition to the Service Charge)
First 1.600 kwhr per hp or kw per year, per kwbr
.01692 Next 1.000 kwhr per hp or kw per year, per kwbr
.01341 Over 2,000 kwhr per hp or kw per year, per kwhr
.01052 Minimami Charse:
The annual minimum charge shall be the sum of the monthly service charges.
Adjustaments:
Adjustments, 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 sharges. Adjustment
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amounts are as follows:
per Irwine Energy Cost Adfustmen' 8.01722 Tax Change Adfustment
(.00071)
Total 8.01651 SPECIAL CONDITIONS
- 1. Con; races: Where a 11ae extension is required or where the oest *a 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 fLret regular monthly meter reading date after servlee is commenced, win be required.
Contracts will remain in effect after the initial term until terminated by either the customer or the Ut!!!ty.
- 2. Centrece Year: The above rates wul apply to twelve month periods beginning with the fleet regular monthly meter reading date after service is commenced.
- 3. Payaneet of Chargss: The service charge wn! be payable in twelve monthly payments beginning with the nrst monthly billing period of the contract year. The energy charge wul be computed on taetor readings and will be payable each month. The charge for energy used durtag a partial month prior to the beginning of a contract year wHl be billed at the rate of the first energy bleek.
- 4. Guarenesed Ceansceed Load oc muts-g Da-ad A customer may obtain the rates for a tasser
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connected load or for a larger b!111ng demand by guaranteeing the sorvies charge for the contract year and rates per kilowatt hour applicable to euch larger connected load or b!!!!ng demand.
- 3. &- :_' Leeds Connected load for the purpose of this ochedule is the sum of the rated capact.
l ties, determined in accordance with Rule No. 2. of all equipment that is served through one metering
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l point ana' 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 lose than three horsepower for three. phase service.
- 6. Mashnami Damiand: The martmum demand in any monthly billing period will be the maximum average power, expressed in kilowatts, taken during any 15. minute interval in the moMh, but not less than the diversified resistance welder load computed in accordance with Rule No. 2. Where the use of energy is intermittent or subject to abnormal fluctuation, a 5. minute interval may be used.
(dentinued)
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Advice Letter No. 734.E Issued by Date Filed A6H1 13,1979 Decision No.
W. M. Gallavan Effective May 15, 1979 Vice. President-Rates and Valuation Resolution No. E-1836 r&D d
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en. nee ese heffie Gas and Electrie Company Revised Cal. Pr.C. Sheet No. 6043.E San Trancisco, California Canceling kvwd Cal. Pr.C. Sheet No.m.E Schsdule No. PA 1 AGRICULTURAL POWER (Continued)
- 7. Billins Damiend: The b!!!!ng demand used in computing charges under Rate B will be the highest snaximum demand created by the installation in the twelve. month period ending with the curient month, except that when the connected load is permanently reduced. the mastmum demands created before such permanent reduction will be ignored. Billing demand will be computed to the nearest whole kilowatt.
Charges will not be based on a billing demand in kilowatts of less than 76% of the nameplate rating in horeepower of the two largest motors connected. Where the connected load is 35 horse;ower or les-the Utility may, at its option. use the demand determined by test as the billing demand for billing put.
poses in lieu of lastalling a demand meter.
- 8. Gange in Cmeamers: When there is a change of customers during the conta act year. no adytsinunt w111 be made in charges b!!!ed prior to the date of change. The contract year for the new customer will begin with the Bret regular monthly meter reading after the date service is commenced.
- 9. Changes la Connected 14ed er Billing Demand: Billing adjustments will be made for contiectril load or billing demand changes and for permanent decreases that take place during the contract year except that changes of three horeepower or three kilowatts er less will be ignored for billing purpoe9 where the load is 15 hp 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 permanent changes in operating conditions which will result in lower mszimum demands.
No adjustments will be made in charges billed for service supplied prior to e change in connecteil 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 or billing demand and the energy charge ti!Hur 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 to the previous load or billing demand.
When there is a permanent reduction in connected, load, the billing demand to be used under Rate n
[~N shall be computed in accordance with Special Condition 7.
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No adjustment will be made for a temporary reduction in connected load or billing demand ti load is reconnected within twelve months after it is disconnected. charges will be recomputed on the basis that no reduction in load had taken place.
- 10. Overleeded Motors: Whenever the measured input to any motor. rated 15 horsepower or more, or any group of motors aggregating 15 horsepower or more. served through one metering point. is detes.
mined by the Utility to exceed one kilowatt per horsepower of nameplate rated output. charges shall be billed under Rate B.
- 11. Disc--mos 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 discon.
tinued. Any custosser resuming service within twelve months after discontinuing service wt!! be 1equiled to pay all charges that would have been billed if servlee had not been discontinued.
- 12. Credit for Owneraliip of Transfeeseer by Cuwomer, 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:
Sies of Annuel Credit per hp of Installation Connected Lead 50 99 hp 31.00 per hp 100 499 hp
.90 per hp 500 and over
.80 per hp In those esses where the costomer'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 load of such motor.
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Mvice Letter No. 512.E Issued by Date Filed Sept. 16, 1975 Decision No. 84902 W. M. G al.
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Effective _Sep t. 21, 1975 Vice. President-Rate:. id Valnation Rewintion L.
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Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7050-E_
1 San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 6N1J O
Schadule 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 'n part, with electric energy from a privately owned source of supply: to auxiliary service to customers who at times take service (by means of a double throw switch) from another public Utility; and to other electric service where the Utility must provide reserve capacity and stand ready at all times to supply electricity, but where the use of electric service is not of a usual, regu-lar or continuous character.
TERRITORY The entire territory served.
Per Meter RATES Per Month Customer Charge in addition to any other Customer Charge 35.00 Scand.by Charge per kw of Contract Capacity:
(Subject to voltage adjustment as provided in Specla! Condition 11)
Where customer's plant or other source employs Co generation Technology or utiuses Renewable Resources as the energy source (as defined in Special Condition 13) 0.75 All other service Stand-by Charge per kw of Contract Capacity, excess off peak service 0.95 0.40 (Subject to voltage adjustment as provided in Special Condition 11)
Reactive Demand Charse (in addition to Stand-by Charge) per kvar of maximum reactive demand 0.15 D====4 and Energy Charges (in addition to Stand by Charge):
The Regular Schedule Applicable (see Special Condition 1) including the Customer Charge.
if any, the minimum charges, Energy Cost Adjustment and all other provisions of said schedules.
SPECIAL CONDITIONS
- 1. Resular Schadste AppH,=h!=: Stand-by service, either alone or in combination with other load through the same motkr, shall be billed in conjunction with that rate scheduls 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 Cheromer's Plant Maintenance: 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 Contreet Capacity that may be out of service for scheduled maintenance in the months of February, March. April and/or November, such outages up to 30 consecutive days per calendar year will be ignored 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 i
I the load on the Utility's system in any of the aforementioned months was due to such scheduled main.
tenance. The Utility, at its sole option, may defer customer's scheduled maintenance sabsequent to which deferral an outage for maintenance will be allowed in accordance herewith. Notice of such deferral if any, shall be given by the Utility not less than 60 days prior to customer's scheduled outage, except In event of an emergency. Where maintenance la 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 partlal outage for maintenance for each unit of a multiple unit source or pair of outages of up to 73 hours8.449074e-4 days <br />0.0203 hours <br />1.207011e-4 weeks <br />2.77765e-5 months <br />, for each of one or more units, to remove and replace all or a portlon of customer's source shall be made in accordance with the foregoing during the months specified.
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Advice Letter No. 734.E Issued by Date FiledApri1 13,1979 Decision No.
W. M. Gallavan Effective May 15,19/9 Vice. President-Rates and Valuatica Resolution No. E-1836 D*
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San Francisco, California Canceling Revised Cal. P.U.C. Sheet No. 4940-E Schedule No.Sd STAND.BY SERVICE (Continued) to. Reactive Demsed: When the customer's plant (or other source) is operated in parallel 'with the Utility's system, the customer will so design and operate his facilities that the reactive current require-monts of the portion of the customer's load supplied from the customer's plant (or other source) are not suppued at any time from the Utility's system. In the event customer places a reactive dernand on the Utility in any month in eacess of 0.1 kvar per kw of Contract Capacity, the Reactive Demand Charge shall be eEoctive that month and each month thereafter until the customer demonstrates to the Utility's sattfaction that adequate correction has been provided.
- 11. Vohsse Adjustment: The above stand-by charges are applicable without adjustment for voltage when delivery is made at transmission voltage (60 kv 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 convenience, from Ut!!!!y-owned transformers on the customer's property, the above charges for any month will be increased by 10e per kw of contract capacity. When (a) delivery is made at less 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 transformation from transmission voltage, the above charges for any month will be increased by 25f per kw of contract capacity.
The Utility retains the right to change its line voltage at any time, after reasonable advance notice to any customer aEacted by such change, and such customer then has the option to change his system to as to receive service at the new line voltage or to accept servi'e through transformers to be supplied by Utility subject to the voltage adjustment above.
- 12. Excess Of Peak Semce: Excess of peak stand-by service is available only where the Regn!ar Schedule Applicable is Schedule No. A-22 or A 23 and appites to service which is provided only d" ring the of peak periods specifled therein and which is in excess of other stand-by service,if any.
- 13. rus.%:
f (a) Co.generadon Technology - the use for the generation of electricity of exhaust steam, waste
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steam, heat 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 Resources -those sources of energy which are not diminished by use for electric generation, including wind power; solar heat, either direct conversion or steam; steam where the energy source is rubbish, animal waste or other waste fuel not a fossil fuel or a derivation thereof; tidal or wave energyl and geothermal energy. The use of renewable resources may or may not englor Co-generation %echnology.
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v Advice Letter No. 714-E Issued by Date Filed December 22, 1978
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Decision No.
W. M. Gallavan Effective January 21, 579 Vice-President-Rates and Valuation Resolution No.
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(s< a04 NO. e Pacific Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7051.E San Francisco, California Canceling Original Cal. P.U.C. Sheet No. 6778^ O Schedule No. AD EXPERIMENTAL NON. DOMESTIC LOAD DEFERRAL SERVICE AMICABILITY Servlee under this Scheduleis provided at the sole option of the Ut!!!ty for the purpose of evaluating a non domestic load deferral service and is applicable to single-phase and polyphase alternating current services which have Utility-contro!!ed central refrigeration air conditioning.
TERRITORY Any portion of the entire territory served, as determined by the Utility.
RATES Ths regular single phase or polyphase alternating current service tchedule otherwise applicable in the area served, less the following discount per ton (to the nearest.5 tes) of controlled connected load:
Per Meter Control Discount Per Month Central Air Conditioning, per ton 31.50 provided. however, that the total bill for service shall not be less than the customer or demand charge plus the Energy Cost Adjustment.
SPECIAL CONDITIONS
- 1. Deto mination of. ability of customer's central refrigeration air conditioning for controtted load serif, will be made by the Utility.
- 2. The tonnage of each controlled air conditioner will be determined by the Utility based on name-plate rating of the unit or, if not available, by test or from other available data. The Utility resers es the right to exclude from the discount any additions or changes to the customer's air conditioner (st
- 3. The Control Discount for central air conditionir.g is in effect for meter readings commencing May 1 and terminating September 30 of each year.
- 4. Control will be accomplished between the hours of 8:30 am and 10:30 pm by means of a special thermostat the set point of whleh may be raised by the Utility by remote control, but not to exceed 82*F.
During emergency conditions as determined by the Ut!!ity, complete 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. 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 termination of this 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 11rst becomes effective.
A. O Advice Letter No. 734.E Issued by Date Filed Aoril 13. 1979 Decision No.
W. M. Gallavan Effective Mav 15. 1979 Vice. President-Rates and Valuation Resolution No. E-1836 E 44 hb 0
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Pacific Gas and Electric Company Original Cal. P.U.C. Sheet No. 7056-E San Francisco, California Canceling Cal. P.U.C. Sheet No.
Schedule No. DA EXPERIMENTAL DOMESTIC AIR CONDITIONING LOAD DEFERRAL SERVICE APPLICABILITY Service under this Schedule is provided at the sole optics of the Utility for the purpose of evaluating a controllsd domestic load service and is applicable to single-phase indivklually metered domestic power service customers who have Utility <ontrolled 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 atea served, less a discount of 32.00 per household per month, provided, however, that the total bill for service shall not be less than the cratomer charge plus the Energy Cost Adjustment.
SPECIAL 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 May 1 aN 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 suitability as determined solely by the Utility.
- 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 Utility's expense. Rule No.16, items D. E. and F, are spec!!!cally applicable to service hereunder.
- 6. Termination of Schedule: This rate is temporary and will terminate April 30.1980.
Advice Letter No. 735.E Issued by Date Filed AnH1 13_ 1979 Decision No.
W. 3I. Gallavan Effective May 15, 1979 Vice-President-Rates and W -tion Resolution o bl8310 s
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Pacifle Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7057-E San Francisco, California Canceling Original Cal. P.U.C. Sheet No. 7052^ O Schedule No.DC EXPERIMENTAL DOMESTIC CONTROLLED LOAD 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 app!! cable to single-phase ladividually metered domestic power service customers who have Utility <ontrolled electric central refrigerative air conditioning, which, in the opinf an 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.
SPECIAL 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 nfay 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 suitability as determined solely by the Utility.
- 6. Control mechanisms and associated wiring shall be installed, tested and malntained 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 wir!ng will be returned to normal operating condition at the Utility's expense. Rule No.16. Items D. E. and F. are speciocally applicable to service hereunder.
- 6. Termination of Schedule: This rate is temporary and will terminate April 30.1980.
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W.3I. Gallavan Effective May 15, 1979 Vice-President-Rates and Valuation Resolution No. E-lE34 n n n f
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Pacifle Gas and Electric Company Revised Cal. P.U.C. Sheet No. 7053-E San Francisco, California Canceling lievised Cal. P.U.C. Sheet No. 6991.E h
Schedule No. PA.1X EXPERIMENTAL AGRICULTURAL POWER - TIME VARYING APPLICABILITY 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 either 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.
'IliRRITORY The entire territory served.
RATES (Per Meter Per Month)
Monthly Service Charge 81.59 plus 80.10 per Kw of Maximum Demand Energy Charge (In Addition to the Service Charge)
Per Meter Per Month Period A Period B On. Peak, per Kwh 30.07469
$0.03782 Plus: Partial Peak, per Kwh 0.01232 0.01232 Plus: Off. Peak, per Kwh 0.00893 0.00893 Minimum Gorge:
The minimum charge shall be the monthly service charge.
Adju.anents:
Adjustments, as specified in Parts B and C of the Preliminary Statement, will be added to each n
bill for service calculated at the above rates, including bille for minimum charges. Adjustment
/
amounts are as follows:
,r per kwh Energy Cost Adjustment
$.01722 Tax Change Adjustment
(.00071)
Total 5.01651 SPECIAL CONDITIONS
- 1. Time Periods:
Period A is applicable to meter readings from May 1 to September 30, inclusive. for the following hours:
On. Peak 12:30 p.m. to 6:30 p.m.
Monday through Friday Partial Peak 8:30 a.m. to 12:30 p.m.
Monday through Friday 6:30 p.m. to 10:30 r m.
Off-Peak 10:30 p.m. to 8:30 a.m.
Monday through Fr14ay All day Saturday and Sunday
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(continued)
V Advice Letter No. 734-E Issued by Date Filed April 13, 1979 Decision No.
W. M. Gallavan Effective May 15, 1979 Vice-President-Rates and Valuation Resolution No..,E-18351 h[b E-47 0
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Pasias Gee and Electric Company Sea Franciseo, Californi" o r iginal Cal. P.U.C. Sheet No. 6790-E Canceling Cal. P.U.C. Sheet No.
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$chedule No. PA-1X.
Emperimental Agricultural Power - Time varying (Continued)
SPECIAL CONDIT!ONS (Continued) 1.
Time Periods (Continued):
Period B is applicable to meter readings from October 1. to April 30. inclusive for the
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following hours:
On-peak 4:30 p.m. to 8:30 p.m.
Monday through Friday Partial Peak 8:30 a.m. to 4:30 p.m.
Monday 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 Ifne extension is required or where the cost to the Utility to install the necessary facilities is substantial, a written contract for an initial term of three years will be required for service under Schedule No. PA-1.
In all other instances, a written contract for an initial term of one year, beginning on the first regular mons.ly meter reading date after service is consnenced, 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 above rates will apply month to month for one year beginning with the first regular monthly meter reading date after service is comenced, and will continue for a
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 Denand: 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 accordance with Rule No. 2.
Where the use of energy is intermittent or subject to abnormal fluctuation, a 5-minute interval may be used.
6.
Otscontinuance 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-tinuinP 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 i
l 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-l l
$1re of Annual Credit per hp of Installation Connected Load 50 - 99 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 transfortners will be allowed on the connected load of such motor.
O Advice Letter No. 679-E Issued by Date Filed June 29, 1978 Decision No.
W. M. Gallavan Efective Julv 29, 1978 Vice. President - Rates and Valuation Resolution No.
1 a
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EXHIBIT F RESULTS OF OPERATIONS
p g
V PACIFIC GAS AND ELECIRIC COMPANY
- Exhibit F Sheet 1 of 4 pesults of Operations - 1978 Test fear - Decision 89316 Adjusted To Reflect Comercial Operating Date Unit no.1 December 1.1979 And Unit No. 2 - Au9ust 1. 1980 (000's Omitted)
T)tal Electric CPUC Jurisdictional Sales Diablo Diablo Diablo
- Diablo Proposed ECAC Adjustment Canyon Canyon Dec. No. 89316 Canyon Canyon Base Giablo Diablo Line Unit No. I Ur.it No. 2 at Authorized Unit No. 1 Unit No. 2 Rates Canyon Canyon Line A
Addition _ Addition Rates (a)
Addition Addition Adjusted Unit No. 1 Unit No. 2 Adjusted A (A)
(B)
(C)
(D)
(E)
(F)
(G)
(H)
(I) 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 Expenses Production Expenses -
2
. ECAC 831.951 831.951 (154.178) (121.196) 556.577 2
Production Expenses -
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 Olstribution Expenses 109.423 109.423 109.423 5
Customer Account 6
Expense 44.553 44.553 44.553 6
7 Unco 11ectibles
$51 434 4.367 551 434 5.352 (551)
(4 34) 4.367 7
Customer Services and Informational Expenses 8
8ase Program 6.479 6.479 6.479 8
9 Supplemental 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 1,863 1.507 100.945 1.733 1.402 104.080 104.080 12 13 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 (Q
15 Sub-Total 8.140 7.653 1.229.324 7.611 7.148 1.244.083 (155.758)
(122.438)
% 5.887 15
[M 16 Depreciation Expense 35.705 29.211 162.270 33.206 27.166 222.642 222.642 16 c-T 17 Taxes Other Than Income 6.284 4.899 116.603 5.844 4.556 127.003 127.003 17 State Corporation 18 Franchise Tax 8.240 6.308 24.541 7.663 5.866 38.070 38.070 18 19 Federal Income Tax
?2.664 14.895 87.588 21.078 13.852 122.518 122.518 19 Total Operating go 20 Expenses 81.034 62.966 1.620.326 75.402 58.588 1.754.316 (155.758)
(122.438) 1.476.120 20 Net Operating 21 Revenues - Adjusted 86.404 68.656 379.685 80.356 63.850 523.891 523.891 21 22 Rate Base 909.517 722.695 3.9 % 682 845.050 672.106 5.514.638 5.514.638 22 23 Rate of Return 9.5%
9.5%
9.5%
9.5%
9.5%
9.5%
9.5%
23 1333
{J
.(a)'ECAC Revenues and ECAC Production Expenses and associated franchise and uncollectibles at rate of May 15. 1979 are included.
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PACIFIC GAS AND ELECTRIC COMPAM Exhibit F Sheet 2 of 4 Results of Operations - 1978 Test Year - Decision 89316 Adjusted To Reflect Commercial Operating Date Unit No.1 February 1.1980 And Unit No. 2 October 1.1980 (000's Onitted)
Total Electric CPUC Jurisdictional Sales Diablo Diablo Diablo Diablo Proposed ECAC Adjustment Canyon Canyon Dec. No. 89316 Canyon Canyon Base Diablo Diablo Line Unit No. I Unit No. 2 at Authorized Unit ho. 1 Unit No. 2 Rates Canyon Canyon Line A.
Addition Addition Rates (a)
Addition Addition Adjusted Unit No. 1 Unit No. 2 Adjusted 1 (A)
(B)
(C)
(D)
(E)
(F)
(G)
(H)
(I) 1 Operating Revenues 171.331 135.341 2.000.011 159,378 125.898 2.285.287 (159,378) (125.898) 2.000.011 2
Operating Expenses Production Expenses -
2-ECAC 831.951 831.951 (157.760) (124,621) 549.570 2
Production Expenses -
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 Distribution 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 anJ -
Informational Expenses 8
Base Program 6.479 6.479 6.479 8
9-Supplemental 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 Wege Adjustments 2.153 2.153 2.153 14 15 Sub-Total 8.261 7.768 1.220.324 7.723 7.255 1.244.302 (159.378) (125.898) 959.026 15 m
16 Depreciation Expense 36.545 29.681 162.270 33.987 27.603 223.860 223.860 16 rd) 17 Taxes Other Than income 6.531 5.116 116.603 6.074 4,758 127.435 127.435 17 pm State Corporation QW 18 Franchise Tax 8.494 6,616 24.541 7.899 6.153 38.593 38.593 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 i
Jr Net Operating
~~P
- 21 Revenues - Adjusted 87.748 69.832 379.685 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 C 23 Rate of Return 9.5%
9.5%
9.5%
9.5%
9.5%
9.5%
9.5%
23 y
(a) ECAC Revenues end ECAC Production Expenses and associated franchise and uncollectibles at rate of May 15, 1979 are included.
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PACIFIC GAS AND ELECTRIC COMPANY Exhibit F Sheet 3 of 4 Results of Operations - 1980 Test Year - Application 58545 Adjusted To Reflect Constercial Operating Cate Unit No.1 December 1.1979 And Unit No. 2 - August 1, 1930 (000's Omitted)
Total Electric CPUC Jurisdictional Sales Diablo Diablo Diablo Diablo Proposed ECAC Adjustment Canyon Canyon At Canyon Canyon Diablo Diaalo Line Unit No. 1 Unit No. 2 Proposed Base Unit No. I Unit No. 2 Canyon Canyon Line No.
Addition Addition Rates Addition Addition Total Unit No. I Unit No. 2 Adjusted No.
(A)
(B)
(C)
(D)
(E)
(F)
(G)
(H)
(I) 1 Operatin9 Revenues 167.438 131.622 1.426.631 155.758 122.438 1.704.827 (155.758) (122.438) 1.426.631 1
Operatin9 Expenses Production Empenses -
2 ECAC (154.178) (121.1%) -(275.374) 2 production Espenses -
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 Distribution Expenses 131.912 131.912 131.912 5
Customer Account 6
Expense 51.752 51.752 51.752 6
7 Unco 11ectibles 551 434 2.244 551 434 3.229 (551)
(434) 2.244 7
Customer Services and informational Expenses 8
8ase program 24.810 24.810 24.810 8
.9 Load Management 29.518 29.518 29.518 9
Aministrative 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 27.166 252.591 252.591 14 15 Taxes Other Than Income 6.284 4.899 80.773 5.844 4.556 91.173 91.173 15 State Corporation 16 Franchise Tam 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 Total Operating 18 Expenses 81.034 62.966 948.618 75.402 58.588 1.082.608 (155.758) (122.438) 804.412 18
- t__,
19
. Net Operating Revenues 86.404 68.656 478.013 80.356 63.850 622.219 622.219 19 V
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 Gb=w W
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PACIFIC GAS AND ELECTRIC COMPANY Exhibit F sheet 4 of 4 Results of Operations - 1980 Test Year - Applicatior, 58545 Adjusted To Reflect Comercial Operating Date Unit No.1 February 1.1980 And Unit No. 2 - Augast 1.1980 (000's Omitted)
Total Electric CPUC Jurisdictional Sales Diablo Diablo Diablo Diablo Proposed ECAC A.11ustment 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' No.
Addition Addition Rates Addition Addition Total Unit No. 1 Unit No. 2 Adjusted ' No.
(A)
(B)
-(C)
(D)
(E)
(F)
(G)
(H)
(1) 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
Operating Expenses Production Expenses -
2 ECAC (157.760) (H4.615) (282.375) 2 Production Expenses -
,3 Non ECAC 4.675 4.899 12a.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 s
6 Expense
$1.752 51.752 51.752 6
7 Unco 11ectibles 565 447 2.244 565 447 3.256 (565)
(447) 2.244 7
8
' Customer Services and Information Expenses 24.810 24.810 24.810 8
9 Load Management 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 Wa9e Adjustments 5.049 5.049 5.049 12 13 Sub-Total 8.261 7.768 521.846 7.723 7.255 536.824 (1.618)
(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 income 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 17 Federal Income Tax 23,752 16.328 11).190 22.089 15.185 156.464 156.464 17 Total Operating 18 Expenses 83.583 65.509 948.618 77.772 60.954 1.087.344 (159.378) (125.892) 802.074 18 CA 19 Net Operating Revenues 87.748 69.832 478.013 91.606 64.938 624.557 624.557 19 20 Rate Base 923.663 735.077 4.463.235 859.007 683.622 6.005.868 6.005.868 20 21 Rate of Return 9.5 9.5 10.71 10.4 10.4 21
-o C M
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EXHIBIT G Q
i:3 F
P G and E c a.
FINANCIAL DATA p '"
c
PACIFIC GAS AND ELECTRIC COWANY O)
GALANCE SHEET MARCH 31. 1979 (G
ASSETS AND OThER DE8ITS (000 Omitted)
Lin No.'
Line No.
UTILITY PLANT 1
UtilityPlant.................................................................................
$7.842.443 1
2 Con s t ruc t i o n Wo r k i n P rog res s.................................................................
'2.016.458 2
3 T o ta l U t i l i ty P l a n t......................................................................
9.858.901 3
4 Less Accumul a ted P rovi s ion for Depreci ati on and Amorti za tion..................................
2.514.481 4
5 Ne t U ti l i ty P l an t. Le s s N uc lea r Fuel.....................................................
7.344.420 5
6 NuclearFuc1..................................................................................
163.746 6
7 Less Accumulated Provision for Amortization of Nuclear Fuel Asser611es........................
7.029 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 red Unde rgroun d - Nonc u rrent..........................................................
12.191 10 OTHER PROPERTY AND INVESTMNTS 11 No n u t i l i ty P ro p e r ty..........................................................................
2.482 11 12 Investment in Subsidiary Companies (Cost $151.789)............................................
204.990 12 13 O t h e r I n ve s tme n ts.............................................................................
958 13 14 Special Funds.................................................................................
427 14 15 To ta l O the r Prope rty a nd I nve s tmen ts.....................................................
208.857 15 CURRENT AND ACCRUED ASSETS 16 Cash..........................................................................................
16 p) 17 Special Deposits................................................................,.............
1.474 17 18 WorkingFunds...........................................................................
383 18
\\/
19 Te np o r4 ry C a s h I n ve s tme n ts....................................................................
64.346 19 20 Notes and Accounts Receivable (less accumulated provision for uncollectible accounts).........
349.860 20 21 Receivables from Associated Companies.........................................................
24.783 21 22 Re g ula to ry B al anci n g Ac coun ts - Re ce i vable....................................................
117.935 22 23 Ma te ri a l s a n d S uppl i e s........................................................................
187.307 23 24 (ma s S to re d un de rg 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 vi den ds Rert i vabl e.............................................................
10.133 26 27 To tal Cu rre n t an d Ac rued As s e ts.........................................................
926.676 27 DEFERRED DE8ITS 28 Un ano rt i z e d De b t E x pen s e......................................................................
4.299 28 29 C l e a r i n g A c c o un ts.............................................................................
29 3[284517) 30 30 Tempo ra ry Fa ci l i t i e s..........................................................................
31 Miscellaneous Deferred Debits.................................................................
1.748 31 32 To ta l De fe r re d Deb i ts....................................................................
8.814 32 33 Total Assets and Other Debits
$8.657.676 33
()Denot6sDeduction 1
Exhibit G h
h 0h n
PACIFIC GAS AND ELECTRIC COWANY BALANCE 5HEET MARCH 31,1979 LIABILITIES AND OTHER CREDITS (000 Omitted)
Line Line No.
No.
PROPRIETARY CAPITAL 1
Como n S t o c k ! s s ue d........................................................................
$1.015.746 1
2 P re fe rred S toc k I s s ue d....................................................................
1.102.451 2
3 Premium on Capital 5tock..................................................................
733.093 3
4 Discount on Capital Stock (7.796) 4 5
Capital Stock Expense......................................................................
(51.848) 5 6
Re t a i n e d E a m i n gs..........................................................................
I 341 506 6
7 To t a l P ro p ri e t a ry C a p i t a l............................................................ D.D 7
LONG-TERM DEBT 8
Bon ds ( l e s s $ 18,382 re a c q u i red )............................................................
3.538.252 8
9 Unamo rti z e d P remi um on L ong-Te m Deb t......................................................
1.070 9
10 Unamo r t i ze d Di s coun t on Lon g-Te nn 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 Accounts Payable...........................................................................
242,046 13 14 Payabl es to As s oci a te d Comp ani es...........................................................
83.593 14 15 Regula tory Ba lancing Accoun ts - Re fundable................................................
14.915 15 16 Custoner Deposits..........................................................................
13.592 16 17 Taxes Accrued..............................................................................
187.473 17 18 Interest Accrued...........................................................................
85.737 18 19 Dividends Declared.........................................................................
81.051 19 20 Ma t u re d L on g-Te m Deb t................................................................,...
1.253 20 21 Ma t u re d I n t e re s t...........................................................................
230 21 22 Tax Collections Payable....................................................................
14.403 22 23 Mi scellaneous Current and Acc rued Li abili ti es..............................................
10.032 23 24 Total Current and Accrued Liabilities.................................................
784.256 24 DEFERRED CREDITS 25 Cus tome r Ad va nces fo r Con s truc ti on.........................................................
72.779 25 26 Accumul a ted De fe rred Inves tment Tax Credi ts...............................................
59.863 26 27 O t he r De f e rre d C re d i ts.....................................................................
15.187 27 28 Un amo rti z ed Ga i n on Re a cqui re d Deb t.......................................................
42.768 28 29 Ac c umul a ted De fe rred I ncome Ta xes..........................................................
30.856 29 30 Tota l De ferred Credi ts.......................
221.45,3 30 31 Total Li abi l i ties a nd other Credi ts..............................................
$8.657.676 31
()DenotesDeduction 2
Exhibit G D
f, j
PACIFIC GAS AND ELECTRIC COMPANY w/
INCOME STATEMrNT (000 Omitted)
Three Months Twelve Months Line r"W Ended Line No.
Marc e, 1979 March 31.1979 No.
UTILITY OPERATING INCOME Operating Revenues:
1 E l e c t r i c De p a r tre n t..................................................
$540.070
$2.176.217 1
2 Ga s De p a rtme n t.......................................................
454.744 1.445.995 2
3 Wa te r De p a rtme n t.....................................................
141 1.248 3
4 Steam Sales Department...............................................
973 2.916 4
5 To ta l Ope ra ti n g Re ven ue s........................................
995.928 3.626.376 5
Operating Expenses:
6 Ope ra t i on E xpe n s e s...................................................
729.136 2.524.495 6
7 Maintenance Expenses.................................................
30.579 118.807 7
8 De p re c i a t i o n E xpe n s e s................................................
58.502 224.407 8
9 Amortization and Depletion of Utili ty Plant.........................,
8 31 9
10 Ta xes Othe r than I ncome Ta xes........................................
29.239 117.870 10 11 Income Taxes - Federal...............................................
28.099 157.129 11 12 I n come T a xe s - O the r.................................................
6.600 34.828 12 13 P rovi sion for De fe rred Income Ta xes - Credi t.........................
(736)
(2.945) 13 14 Inves tment Tax Credi t Adj us tmen ts - Net..............................
(9.543)
(30.753) 14 15 Total Uti li ty Ope ra ti ng Expens es................................
871.934 3.143.669 15 16 Ne t u ti l i ty Ope ra ti ng In core...........................................
123.994 482.507 16 OTHER INCOME AND DEDUCTIONS Other Income:
A 17 Nonu ti l i ty Ope ra ti n g I n come..........................................
28 40 17 (V
)
18 Equi ty i n Ea rni ngs of S ubs i di a ry Comp ani es...........................
7.177 22.772 18 19 I n te re s t a n d Di vi den d In come.........................................
5.994 23.577 19 Y
20 Allowance for Equity Funds Used During Construction..................
31.935 116.183 20 21 Miscellaneous Nonoperating Income....................................
93 283 21 22 Gain on Di s posi ti on of Property......................................
2.079 22 23 To ta l O the r I n co me..........................................,...
45.227 164.934 23 Other Income Deductions:
24 Los s on Di s pos i t i on o f P rope rty......................................
152 24 25 Mi s ce l l aneo us Amo rti z a ti on...........................................
265 25 26 Mi s ce l l a neo us I n come Ded u cti ons......................................
1.335 4.657 26 27 To tal Othe r Income De duc tions...................................
1.335 5.074 27 Taxes Applicable to Other Income and Deductions:
28 Ta xes O ther than income f a xes........................................
61 274 28 29 I ncome T a x e s - Fe de ra l...............................................
{4.933)
(21.131) 29 30 Income Taxes - Other.................................................
11.032)
(4.410) 30 31 Investment Tax Ceedit Adjustments - Net..............................
108 356 31 32 To tal Ta xe s on O the r Income.....................................
(5.796)
(25.511) 32 33 Net Other Income and Deductions........................................
49.688 185.371 33 INTEREST CHARGES 34 Interest on Long-Tern Debt.............................................
64.906 251.884 34 35 Amorti zation of Debt Discount and Expense..............................
420 1l640153) 36 35 36 Amo rti zation of P remi um on Debt - Credi t...............................
(48) 37 Amortization of Gain on Reacqui red Debt - Credi t.......................
(719)
(2.347) 37 38 O th e r I n te re s t E x p e n s e.................................................
1.449 8.667 38 39 Allowance for Borrowed Funds Used During Construction..................
(7.984)
(31.297) 39 40 To tal I n te re s t Ch a rges..........................................
58.024 228.394 40 41 Net Income.............................................................
$115,658
$ 439.484 41
( ) Denotes Deduction O
@ h Ib h 0 h kr S Exhib1t G a um m
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 Comission (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 rate-making purposes.
4 Exhibit G
4 EXHIBIT H RESULTS OF OPERATIONS-SYSTEM 3
E O
I a*o' 3
l 3
i c3 ALL OPERATING DEPARTMENTS h
REVENUES, EXPENSES, RATE 8ASES AND RATES OF RETURN YEAR 1978 RECORDED (000'sOmitted)
Line All Operating Line No.
Description Derartments 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 c
7 Informational Expense 14,109 8,632 7
8 Administrative 'nd General 181,816 122,851 8
a Total Expenses Excluding 9
Taxes and Depreciation 2,806,378 1,356,724 9
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 14 Total Taxes 262,612 204,585 14 15 Depreciation 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%-
19 b) v Exhibit H e
1
EXHIBIT I SERVICE OF NOTICE OF APPLICATION I'it
SERVICE OF NOTICE OF APPLICATION L'
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
(%
Humboldt San Benito Trinity (D
Kern San Francisco Tulare Kings San Joaquin
'l uolumne 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 Burlingame Anderson Bakersfield Calistoga Angels Belmont Campbell Antioch Belvedere Capitola Arcata Benicia Carmel Arroyo Grande Berkeley Chico Arvin Blue Lake Chowchilla 0hh
)
1 Exhibit I 1
l
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Cicyton.
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