Ordinance No. 940
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ORDINANCE NO. 940
AN ORDINANCE OF THE CITY COUNCIL OF THE CITY OF
VERNON PROVIDING THAT RATES TO BE CHARGED FOR
ELECTRICAL ENERGY DISTRIBUTED AND SUPPLIED BY
SAID CITY WITHIN ITS BOUNDARIES SHALL BE SET
BY RESOLUTION AND REPEALING ALL ORDINANCES OR
PARTS OF ORDINANCES IN CONFLICT THEREWITH
7 WHEREAS, the City Council of the City of Vernon has
8 previously established rates to be charged for electrical energy
9 distributed and supplied by said city within its boundaries by
10 ordinance; and
11 WHEREAS, the City of Vernon purchases substantially
12 all of its power and energy from Southern California Edison
13 Company pursuant to tariff schedules approved by the Federal
14 Energy Regulatory Corrrrnission ("FERC"); and
15 \VHEREAS, the FERC has amended its suspension policy
16 from a five (5) month suspension to a one (1) day suspension
17 for rate increases filed by wholesale suppliers when incorporated
18 into a two (2) step rate filing; and
19 WHEREAS, a one (1) day suspension by the FERC does not
20 provide sufficient time for the City of Vernon to adopt rates
21 by ordinance; and
22 WHEREAS, the City Council of the City of Vernon intends
23 by this Ordinance to amend its previous policy and set future
24 rates to include rates for demand, energy, fuel adjustment and
25 any and all other factors necessary for the collection of revenue
26 to meet the costs incurred in operating the utility service
27 by resolution.
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III
III
1 NOW, THEREFORE, THE CITY COUNCIL OF THE CITY OF VERNON
2 DOES ORDAIN AS FOLLOWS:
3 SECTION 1: That the City Council of tre City of Vernon
4 hereby finds and determines that the recitals contained herein-
5 above are true and correct.
6 SECTION 2: That the rates to be charged for electrical
7 energy distributed and supplied by the City of Vernon within
8 its boundaries shall be set by resolution.
9 SECTION 3: That in all other respects, Ordinance No.
10 929, as amended by Resolution No. 5051 and 5061, shall remain
11 in full force and effect and that the provisions in Ordinance
12 No. 929, as amended by Resolution Nos. 5051 and 5061, not
13 consistent with or in conflict with this Ordinance is hereby
14 repealed. Any other ordinance or portion thereof in conflict
15 with this Ordinance is hereby repealed.
16 SECTION 4: There being no newspaper printed, published
17 or circulated in the City of Vernon, the City Clerk is hereby
18 directed to certify to the passage of this Ordinance and shall
19 post the same, or cause the same to be posted, in three (3) of
20 the most public places in the City of Vernon, to wit: the
21 northwest corner of 38th Street and Santa Fe Avenue; the
22 northeast corner of Leonis Boulevard and Pacific Boulevard, and
23 on the bulletin board in the lobby of the City Hall of said
24 City, located at 4305 Santa Fe Avenue, all in the City of Vernon,
25 County of Los Angeles, State of California; that this Ordinance
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1 shall be in full force and effect thirty (30) days from and
2 after the passage of the same.
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APPROVED AND ADOPTED this 6th day of December, 1983.
ATTEST:
~~144 //?~y
BRUCE V. MALKENHORST, City Clerk
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1 STATE OF CALIFORNIA
ss.
2 COUNTY OF LOS ANGELES
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I, BRUCE V. MALKENHORST, City Clerk of the City of
5
Vernon, do hereby certify that the foregoing Ordinance, being
6
940
, was
duly and regularly introduced
7
Ordinance No.
ladjourned
at a regular meeting of the City Council of the City of Vernon,
8
held on
November 15. 1983
, and thereafter finally adopted
9
at a regular meeting of said City Council held on
6th
December 1983
, by the following vote:
Halburg, Davis, Gonzales, ~,fcCormi k
Councilmen: Ybarra
Councilmen: None
AYES:
NOES:
ABSENT:
Councilmen: None
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.t/~-Z"_d/;Y~~~
,
Bruce V. Malkenhorst, City Clerk
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1
AFFIDAVIT OF POS~
2 STATE OF CALIFORNIA )
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3 COUNTY OF LOS ANGELES) SS
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4 CITY OF VERNON )
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I, BRUCE V. MALKENHORST, City Clerk of the City
of Vernon, do hereby certify that I did, on the 7th day of
December , 19 83, post three (3) cODt"es of ORDINANCE N?" .
940-Prov~d~ng That Ra'f'eS To Be Charged For E ectr~~d.l Euer~, Dl.~tr -
buted and Supplied By Said City Within Its Boundar~es Shall Be Set
By Resolut~on & l{epeal~ng All Ordinanc.;e~ Or. t8ftFri8t1hgfgW~tfi~ In
one in each of the follOlN'ing places, to TtJit: At the northwest
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corner of 38th Street and Santa Fe Avenue, at the northeast cor-
ner of Leonis Boulevard and Pacific Boulevard, and on the bulletin
12 board in the lobby of the City Hall of the City of Vernon, locat-
13 ed at 4305 Santa Fe Avenue, all in said City, there being no
14 newspaper of general circulation printed and published in the City
15 of Vernon.
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Signed this
7thday of
December
, 1983 .
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&~/~~
BRUCEV. MALKEilliORST, City Clerk
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Subscribed and sworn to before me
this 7th day of December ,19~.
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:::::=~~-~~""f-
OFFICIAL SL\L ~'
LOi:; J HiLTON .,
NOTIl.RY PUBLIC - CALfi'Or.~N'lA
Las M,C"),':';,'{
My comm. ex.:.::::; rj;: t" F ',.'
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430'5 Santa Fe Avenue, Ver.~'::;;l, CA see:3
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~~,(...,.~_. ,~.".,,-.....,. ""
SUPPORTING
DOCUMENTS
v ...... . .....-C,.). I .
BAKER G CLAY !:!( ^SSOC1ATES. INC
REPORT ON RA TE DESIGN "b
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1--1 - t-f. r l,.v.~t.
, . .
CI Y OF VERNON, CALIFORNIA
unicipal Light Department
May 1984
REPORT ON RATE DESIGN
SUPPLEMENT TO DECEMBER 1983 REPORT
CITY OF VERNON, CALIFORNIA
MUNICIPAL LIGHT DEPARTMENT
MAY 1984
PREPARED BY:
BAKER G. CLAY & ASSOCIATES, INC.
TABLE OF CONTENTS
Section
Description
Page
I
Introduction
1
II
Elimination of Two Step Increase
2
III
Revised Cost of Service to Reflect
Edison's Reduced Rates
3
IV
Cogeneration
4
V
Miscellaneous Changes in Rate
Schedules
6
VI
Changes in the Energy Cost
Adjustment Billing Factor
8
VII
Adjustments to Vernon Costs
9
I. INTRODUCTION
As reported in the December 1983 Report, on November 8, 1983
Southern California Edison Company (Edison) tendered for filing
with the Federal Energy Regulatory Commission (FERC) in Docket
No. ER84-75 a proposed t~o-step increase in its wholesale rates
for service to Vernon. Edison requested effective dates for the
Step 1 and Step 2 rates of January 7, 1984 and January 8, 1984,
respectively. Vernon and the other resale Cities filed protests
with the Commission and requested maximum suspensions of both
steps of this proposed increase. On January 5, 1984 the
Commission issued an order providing for a maximum suspension of
the proposed two-step increase to June 8, 1984. Among other
reasons cited for the maximum suspension, the Commission cited
Vernon's protest:
}'.
Vernon alleges, inter alia, that Southern California
Edison (SCE) has included excessive depreciation
expenses, decommissioning expenses, and operation and
maintenance (O&M) expenses; that the company has over-
stated demand projections; and that SCE has claimed an
excessive rate of return. Vernon also challenges the
allocation of costs among customer classes.
In its January 5, 1984 order, the Commission also granted
summary disp~sition on certain issues, whi~h results in a
reduction in Edison's resale revenue requirements from
$290,835,000 to $289,946,000. Edison filed reduced rates in
February 1984 in compliance with the Commission's January 5, 1984
order. The proposed rates applicable to Vernon as set forth in
the original filing and in the February 1984 compliance filing
are as follows:
Original
F i 1 i ng
Compliance
Filing
Customer Charge:
$ 490.00
$600.00
Demand Charge
On-Peak
Mid-Peak
$ 15.63
$ 1. 56
$ 15.54
$ 1.55
Energy Charge
On-Peak
Mid-Peak
Off-Peak
4.795t
4.495~
4.045t
4.793t
4.493t
4.043,t
The January 5, 1984 suspension order and the February 1984
Compliance filing make it appropriate to supplement our December
1983 Report as set forth herein.
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II. ELIMINATION OF TWO-STEP INCREASE
The Commission's order suspending Edison's increased rates
until June 8, 1984 also eliminated the two-step approach proposed
by Edison. Edison's total increase will become effective on June
8, 1984. In our December 1983 Report, we proposed a surcharge to
track Edison's Step 2 increase. This will no longer be
necessary, of course, and the revised rates proposed herein will
reflect Edison's total increase and no surcharge will be
necessary.
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III. REVISED COST OF SERVICE TO REFLECT
EDISON'S REDUCED RATES
Edison's reduced rates, filed in compliance with the
Commission's Summary Disposition of certain issues, results in a
decrease in the cost of service that we set forth in our December
1983 Report from $75,279,990 to $75,071,999. The various
schedules set forth in our December 1983 Report, including the
rate design schedules and tariff sheets, have been revised to
reflect this reduction in our cost of service.
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VI. COGENERATION
At pages 23 - 25 of our December 1983 Report we outlined an
approach for the calculation of transportation demand rates for
cogeneration, but did not recommend precise rates because several
pieces of vital information were missing, and at that time, had
no firm proposals in hand.
In summary, we recommended that monthly transportation demand
rates be computed by dividing the sum of Vernon's fixed costs,
including Contract Services, Miscellaneous Expenses, Operating
Agreement Costs, Depreciation, Return, and Payments in Lieu of
Taxes and Franchises, by the sum of Vernon's system demands. We
did recommend, however, that the Contract Services portion of the
costs be reduced by the amounts pertaining to activities
associated with purchases of power and energy and that Vernon
consider a reduction in the In Lieu payments on an individual
basis.
In that report we noted that the estimated demands for
transportation for the cogenerators would have to be added to
existing system demands to arrive at adjusted system demands for
use in developing rates. We did not make a projection of these
transportation for cogenerators demands, however, and thus merely
computed an "example" demand rate for transportation for
cogeneration customers on Exhibit C, Sheet 2. We have now
entered into a Letter of Intent with Sunlaw Energy Corporation
(Sunlaw) in which Vernon proposes to transport 58,~9~ kilowatts
per hour for Sunlaw at a rate of $1.996 per kilowatt-month. The
Letter of Intent provides for a charge of 2 mills per kilowatt
hour for interruptible transportation of energy in excess of
58,~99 per hour. As part of this Agreement, Vernon reserves the
right to modify the rate after the fifth year by a formula to be
developed by the parties in accordance with the approach
contained in the current Vernon Rate Report.
We have revised Exhibit C, Sheets 1 and 2 to develop a
Transportation demand rate for Sunlaw that reflects the situation
that will exist after Sunlaw transportation begins. We have
revised Sheet 1 of Exhibit C to reflect transportation for Sunlaw
of 58,~9~ kW. We have revised Sheet 2 of Exhibit C to assume
that none of contracted services relates to transportation. Also
Section 11.1 makes clear that Vernon has reduced its rate in
recognition that Sunlaw's cogeneration project will consume
natural gas as its fuel source and that Vernon will therefore
receive additional franchise fees from Southern California Gas
Co. Sunlaw is also obligated to pay Vernon an equivalent
percentage of the purchase price of alternate fuels which are
consumed in this project. As we indicated in the December 1983
Report, it is appropriate that the City consider a reduction in
the In-Lieu payments on an individual basis. Because of the
additional franchise fee payments to Vernon on the fuel
consumption at this project, we have reflected an 85 percent
discounting of the In-Lieu payments in the calculation of
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transportation rates for Sunlaw. Note that it may be appropriate
to reflect a different discounting in the calculation of
transportation rates for other cogenerators.
The revised transportation rate for Sunlaw computed on this
basis (applicable solely to Sunlaw) would be $1.24. The rate of
$1,.006 proposed in the Letter of Intent is somewhat lower than
the calculated rate of $1.24 per kW-month, but is well within the
zone of reasonableness considering the level of precision
attainable in projecting system demands and the need to implement
a rate that will encourage cogeneration in the City of Vernon.
!
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V. MISCELLANEOUS CHANGES IN RATE SCHEDULES
A. Schedule No. TOU-V
The applicability section of proposed Schedule No. TOU-V now
provides that any customer whose monthly maximum demand has
fallen below 500 kW for 12 consecutive months may elect to
take service on any other applicable rate schedule. We now
propose to revise this section to provide that any customer
whose maximum demand has fallen below 450 kW for 12
consecutive months may elect to take service on any other
applicable rate schedule.
B. Schedule No. GS-l
The applicability section of Schedule No. GS-l now
provides that this schedule is not applicable when in the
opinion of the~tility, the maximum demand may exceed 20 mW.
We now propose that the applicability of Schedule No. GS-l
be made available to customers with maximum demands greater
than 20 mW. We also now propose that the customer charge of
$6.00 per month be eliminated.
C. Schedule No. D.
Schedule No. D is now applicable to domestic farm
service and summer cottage customers. No such customers
exist, or are likely to exist, in the City of Vernon and we
propose that Schedule No. D be revised to eliminate the
mention of this service.
-~ l?~
,j'ftj.. ~-
1~/
All customers having!ffionthly requirements of 500 kW or
higher during the last 12 months now have magnetic tape
meters. We therefore propose that Schedule No. A-7 be
withdrawn and customers now purchasing under this schedule
having monthly requirements of 500 kW or more be required to
purchase under Schedule No. TOU-V. Customers having monthly
requirements of less than 509 kW would purchase under
Schedule No. GS-2.
D.
Schedule No. A-7
We have not proposed adjustments to the rates for
Schedule Nos. TOU-V and GS-2 to reflect the increase in
service under these schedules resulting from the transfer of
customers from Schedule A-7. Instead, we have assumed that
the total revenues from the customers transferring from
Schedule A-7 to Schedule Nos. TOU-V and GS-2 will be
approximately the same under those schedules as the revenues
we have projected for Schedule No. A-7. While this
assumption will obviously result in some error, we do not
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have the data with which to make more precise calculations of
rates. The time-of-use billing data that is now available is
limited to the large customers purchasing under Schedule No.
A-a, but data with which we can make a more precise
calculation of billing determinants for the TOU-V and GS-2
customers will be available shortly and adjustments to these
rates can be made at that time, if necessary.
E. Schedule No. TOU-V
The voltage adjustment for Schedule Nos. A-a and A-7
have applied only to the demand charges. Because energy
losses are associated with transformation, it would be
appropriate to apply the voltage adjustment to the energy
component as well. We have therefore proposed a voltage
adjustment provision for inclusion in Schedule TOU-V that
adjusts both the demand and energy co~ponent.
F. Schedule No. GS-2
We have included a power factor adjustment provision and
a voltage adjustment provision in Schedule No. GS-2 because
it will be necessary to apply these provisions to the
customers transferring from Schedule No. A-7. The voltage
adjustment for Schedule No. GS-2 will apply to both the
demand and energy components of the rate.
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VI. CHANGES IN THE ENERGY COST
ADJUSTMENT BILLING FACTOR
As set forth in the revised Exhibit H, the Energy Cost of
purchases from Edison under the compliance rates is 4.385t/kWh,
which will be the base cost of energy from which the ECABF is to
be computed. Also, because the meter reading of Vernon's large
customers does not necessarily coincide with the date that Edison
reads Vernon's meters, Vernon's recorded monthly sales sometimes
vary considerably from its recorded purchases. In instances
where there is a substantial difference between recorded sales
and recorded purchases, it would be appropriate to make
adjustments to reflect these differences. A ledger should be
established in which to make entries of positive and negative
adjustments in kWh sales, and adjustments should be made such
that positive and negative adjustments are in balance as of each
November 39. A provision for these adjustments has been set
forth in Exhibit H, Sheet 4 of 4.
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VII. ADJUSTMENTS TO VERNON COSTS
Subsequent to the submission of our December Report, Vernon
has prioisedl revusuibs .illS! uts budget expenditures for the fiscal
year ~uly 1, 1984 through June 30, 1985, as follows:
000's
December
Report
Current
Estimate
Contracted Services
Operating Expenses
Miscellaneous Expenses
$ 585
2,161
152
$1,275
2,640
316
We have therefore reflected the current estimates in the sales
rates proposed herein. We have not reflected the increase in the
miscellaneous expenses in the cost of services used to develop
transportation demand rates for cogenerators. We have, however,
increased the In Lieu payment from $2,300,100 to $2,400,000, and
included 15 percent of the larger amount.
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E;.:tllblt fl
City at Ve~non Sheet 1 01 4
Compa~ison at Revenue Requi~ements (Revised)
Actual Yea~ v.s. Estimated Unde~ Edison's Step 1 Rates
(thousands)
Actual
E>~pen$es
as Adjusted
Estimated
E>:penses
w/Step 1 Rates
A
B
c
725
$75,071
1,275
316
:...:,640
400
750
$80.45:.:::
1 Cost of Powe~ & Ene~gy
2 Cont~acted Service
..;;. t-ti sce!l aneOLlS
4 Ope~atinq Agreement
5 Depreciation
b RetLl~n
7 lotal Revenue Requirement *
$65,694
6.36
113
2,092
399
$69,659
Sources :
Col B. Line 1
Cost ot Purchases for year ending October 31,
1983 from Sheet 2, Reflects Step 2 rates
in Docket No ER82-427.
Col B. Llnes 2-5: City of Vernon statement of Revenue and
Expenses for year ending October 31, 1983.
Col B, Line 6
Average Rate base @ 12.65 %
Col C. Line 1
Power and energy purchased during year ended
October 31, 1983 , priced at compliance rates.
Col C, Lines 2-5: City of Vernon proposed budget .
Col C, Line 6
Average Rate Base @ 12.65 % Rate of Return.
* Does not include payment in lieu of taxes and franchise fee.
Citv ot Vernon
Costs of Purchases from Edison
Under step 1 Rates
(Schedule f<-~.J
Billinq
Units
(thousands)
Step 1
Rates
A B
c
es
1 Customer Charge
1
$bOO.OO
Demand Charge
2 On Peak
3 Mid Peak
4 Subtotal
1 !ISb1
2~042
$15.54
1.55
5 Voltage Adjustment
1 , 861
$0.55
b Power Factor Adjustment
7 Vernon City Hall ~
8 lotal Demand
Energy Chat-ge
9 On Peak
10 I-b d Peak
11 0++ Peak
12 Subtotal
1~; FCA
14 Vernon Litv Hall *
15 Subtotal Energy
196,894
322, 9(7~8
508,729
1,028,621
$0). (l479~5
0.0449::::.
0.04043
16
lotal
Sources :
b:hibl t B
Sheet 3 01 4
,Re...,.l sed)
Amount
(thousands)
D
$7.20
28,920
3,165
$32,085
($1!1024)
$24
(11) it
:::;.1.l)81
9,437
14,512
2(), ~,68
44,517
~46:3;Jit*
(65)*
$4:::. !I ;:Y'-td
t;7~1!I (I} 1
Col. B: W/P B-2 !I 12 months ending October 31, 1983.
Col. C
Step 1 rates from filing in Docket No. ERB4-75
Col. U, Lines 6, 7 & 14 :
W/P B-2
.. lotal Lity Hall
Demand @ 15/.
E.nergy @ 85 I.
$76
11
65
** Based on neqatlve .045c/kWh from Statement DB
in Docket No. ER84-75.
Citv 0+ Vernon
Costs of Purchases from Edison
Under step .2 Rates
(Schedule R-3j
Billing
Units
<thousands)
step 2
Rates
E>: h i bit El
Sheet 4 of 4
(Revised)
Amount
(thousands)
---------------------- --------- --------- ---------
PI B C iJ
1 Customer Charge 1 $6uO.00 $7.20
Demand Charge
2. On Peak
3 I'Ii d Peak
4 Subtotal
1,,861
2,,042
$15.54
1.55
5 Voltage Adlustment
1,,861
$0.55
6 Power Factor Adjustment
7 Vernon Cltv Hall
8 fotal Demand
Energy Charge
9 On Peak
1 (I I'h d f'ea k
11 Off Peak
12 Subtotal
13 FCA
14 Vernon City Hall
15 Subtotal Energy
196,8(14
322,998
508,729
1,028,,621
$0.0479::::;
0.04493
i) . 04043
16
fotal
Sources :
28,920
~;, 166
$32,086
($1,024'
$24
<11 )-It
-31, ('82
9.437
14,512
20,568
44,517
(4o"3J **
(6~) ..
1;4-3, 990
$75,072
Col. B :
W/p [1-:':;: . lL months ending October -.::.1, 1'7'8:2:..
Col. C :
Step 1 rates from filing in Docket No. ER84-75
Col. D. Lines 6" 7 & 13: W/P B-2
* lotal City Hall
Demand @ 151.
Ener-gy @ 85 %
$76
11
65
** Based on negative .045c/kWh trom Statement DB
in Docket No.ER84-75.
Litv ot Vel-non
Billing Demands tor
lransportatlon tor Logeneration
b:t1ibi t L
Sheet 1 01 3
(Revised)
Bll1ing
Demand
.. mW-.t-lonths)
H
fJ
1 Sunl aw (12*58)
2 Customer 2.
~. Customer ~.
696
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4
Tot al
696
Cltv of Vernon
Development ot fixed Costs tor
Iransportation tor Cogeneration Customers
Vernon~s Fixed Costs
1 Contracted Services
2 Miscellaneous
3 Operating Agreement
4 Depreciation
5 Return
6 In Lieu Payment (.15*2400)
7 fotal Costs
Vernon's System Demands
8 lotal system Oemand
9 lransportation for Cogeneration
10 Additional Firm
11 Hdjusted System Demands (Temporary)
12 Unit Cost per kW
Sources :
Lines 1-5
Exhibit B~ Sheet 1.
b:hibit L
. Sheet 2 of:.,
(Revised)
14mount
(OOO~s}
$0
152
2.040
40(1
750
360
2,785
696
Line 6: Payments to General Fund In-Lieu of
1.axes and Franchise Payments
Line 9: Exhibit C~ Sheet 1
$4,31)2
3;.481
III
So
3~)2
I A-B
2/H
3 65-2
4 65-1
S D
b lS-1
7 lS- 2
8 Ol-1
481 Y PII-l
Iii ril-i
.24 II 1(-1
12 lotal
Exhlbl t (
Sheet J of 3
\f(evlSed I
li tv of Vernon
Energy and peak deaand
Adjusted for losses
leaT Ending "arch 31, 1983
loss fercentages
Energy tit/hi
BillIng De.and (tN-Ho.)
Schedule
------- -------------------------------
f'naary
!list.
lotil
"eler
frans.
Heter
Inns.
A 8
Sources :
(Dlu.n F: N/r (-1
Colu.n H: Wry (-2, Nir b-i.
f l.puted @ 2S~ load factor
I. I.puted @351 load factor
Sec.
line
iiI
01
c,;;
-------- -------- --------- ------- --------- --------- ---------
t II E F II tI
t>1 01 01 645,Wt,020 045,969, {)2(I 1,416,613 1,41b,613
01 11 11 214,373,500 216,517,29& ilb,359 723,52L
n 1l 21 123,284,114 125,749,796 544,675 555,5b9
II 11 n 9,774,896 10,165,892 0 56,OB8 .
n n 4l 126,652 131,718 (I 727 f
21 21 61 1,835,724 1,945,867 4,571 4,845
21 21 61 227,748 241,413 5bO 594
21 21 61 1,615,042 1,111, '45 (I (I
21 2); 61 3,652,610 3,871,761 IB,953 15,258 if
01 n n 1,719,280 1,791,073 8,31b 8,399
n 1l 21 516,375 52b,703 (J 2,90b f
1,(~3,155,021 1,008,628,489 2,716,047 2,1&4,521
21
2);
21
21
27,
11
01
01
11 tt ot Vernon
Allocation of tost of &ervlce
Vernon's Costs Under Edison', Step 1 Rates
Deland
Schedules
Total
hat
--------------------------
"id
Puk
Ii
B
2
TOU-V $14,186,278 $12,882,892
A-8 4,353,989 3,953,960
A-7 9,409,278 8,5",273
65-2 7,117,566 6,b03,09b
65-1 718,557 066,618
D 9,310 8,&37
PA-l 195,478 181,348
PH-2 107,&0& 99,B28
1C-l 37.229 34.538
Subtotal .36,195,290 $33,030,190
3
4
S
6
7
8
9
10
11
12
13
14
15
16
17
IB
19
lOU-V
A-a
A-]
65-Z
65-1
II
PA-l
PA-2
TC-l
1,083,936
332,677
723,522
5S5,Sb9
Sb,088
727
15,258
8,399
2,9%
2,779,082
Subtotal
20
21
22
lS-1
lS-2
Ol-1
4,845
594
o
C
$1,303,386
400,029
870,004
514,411
51,939
673
14,129
7,718
2,091
$3,165,100
bhlbl t 0
Sheet 1 of 1.
\Ren sed I
Energy
Total
------- --------------------------------
Peilt
"id
Peat
Oft
Peak
D
$23,822,694
4,230,518
9,402,936
5,038,2U
455,806
5,900
173, S9B
80,575
23,610
"3,833,864
E
F
6
o
o
o
1,945,B07
241,413
1,711,945
$4,423,8Z4 $7,290,259 $12,108,&11
785,598 1,294,630 2,150,290
1,746,105 2,877,501 4,779,329
1,092,179 2,682,121 1,263,911
136,799 216,829 102,177
1,172 2,809 1,324
52,101 82,581 38,915
24,183 38,330 18,062
7,098 11,234 5,294
$1,869,650 $14,496,300 $20,467,913
1,407,506 549,5fJ4,144 95,921,845 15B,bb4,314 293,9b8,SB5
431,995 97,414,216 11,034,138 28,17&,106 52,203,973
939,504 216,517,296 37,800,831 62,625,597 110,030,8b8
555,569 125,149,196 30,691,532 58,373.485 30,684,179
50,088 10,165,892 2,966,225 4,719,942 2,480,625
727 131,718 38,433 bl,144 32,141
15,258 3,871,167 1,129,712 1,797,287 944,7b7
8,399 1,797,073 524,354 834,207 438,512
2,906 520,703 153,b82 244,497 128,5:i3
3,417,942 1,004,729,264 192,320,751 315,495,739 496,912,773
142,242,948 41,503,938 bb,029,b63 34,709,348
Colulns D,F,6 , H lines 12-13: Sal! ratio as TOU-V .
um
(6J
(1Q<1i
Lines 20-22 , Colulns B & E: Exhibit C, Sheet 3 of 4 .
Lines 20-22 , Colulns C,D,F,6 , H: Exhibit D, Sheet 2 of 2 .
(20i
(2)
UBi
(8)
III
171
fotal 2,784,521 2,778,84Q 3,417,942 1,008,628,489 192,320,711 315,495,123 49b,912,b73
Sources :
Line 10: Exhlbit D, Sheet 2.
Line 11: VIP D-2
Colulns C , E: Exhibit C, Sheet 3 tMote: line 12 is total A-8 less TOU-V).
CoIulns F,6 , H lines 14-19: RatIO based on total sv:tel less lines 11-13.
fotal
Alount
H
$38, O(IB, ~i~
8.584, SU7
18,872,214
12,755,782
1,174,3b3
15,210
369,075
188,181
60,845
$80,029,154
(501
101
(44)
1. 950.565
241,998
1,711,81&
83,933,535
1
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!
Citv of Vernon Exhlll1t [,
Cla5sification ot kevenue ReQUire.ent5 Sheet 2 of 2
Purchases fro. Edison @ Step 1 Rates Utev15edl
A.ount
fotal --------- ----------- -------.-- --------- ----------- ----------
Illunt lotil De.and Energy
Pirticulars Peak Ih d-Peak Peak "id-Peak Off -Peak
-------------------- -------- -------- -------- -------- -------- -------
A II C D E f 6
8, ~Il 1 Purchased Power $75,071 $27,916 $3,165 tll,91(\ $14,512 $2V,568
.,507 2 Contracted Service 1,275 1,275
2,214 3 "iscellaneous 316 31b
5,782 4 Operating Agree.ent 2,040 2,040
4,363 5 Depreciation 400 400
5,21b 6 Return 150 750
,9,075
a,181 7 Total Revenue Req $80,452 $33,297 $3,165 t8,910 $14,512 $20,568
,(1,845
:9,154 8 "iscellaneous Rev. t$2S) tt2SJ
9 lS-1 Revenues (t2QSi ($127) (t20) ($8; t$501
10 lS-2 Revenues (IS; tb) t2) l1i (o)
11 OL-l Revenues (178) U~J (18) m (441
12 Total for Allocation tSO,029 133,030 $3,105 tll,870 $14,490 $20.468
Sources :
Line 1: Exhibit II, Sheet 3.
SO,50S
H,'1~8
11,81~
lines 2-7: Exhibit I, Sheet 1.
line 8: MiP C-3.
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Revenues @ Existing Rates
Revenues @ the Proposed Rates
and the Resulting Increase
E:-: h i bit G
Sheet 1 of 4
(Revised)
Revenues @ Revenues @
Schedule No. E:<isting Rates Proposed Rates Increase
-------------- -------------- -------------- ---------
A B C D
1 IDU-V $34,598,316 $39,184,589 $4,586,273
2 A-7 16,080,720 19,455,932 3,375,212
3 85-2 11,418,981 13,150,319 1,731,~~38
4 85-1 947,285 1,210,686 263,401
C. PA-l 293,922 380,491 86,569
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6 PA-2 169,856 194,001 24,144
7 TC-l 38,870 42,754 :'::.,884
8 D 5,571 5,699 128
9 LS-l 205 205 (I
10 LS-2 15 15 (I
11 OL-1 178 178 (I
1 r, Total $63, 553, 91 ct. $73,624,868 $10,070,94'7'
..:..
Sources :
Lines 1-6: Exhibit G, Sheet 2
Li nes 7--8
W/P G-:..::.
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Citv 0+ Vernon
Revenues @Existing Rates
Revenues @ the Proposed Rates
and the Resulting Increase
b:hi bi t G
Sheet 1 o-f 4
(Revised)
Schedule No.
fo:evenues ~
E:<isting Rates
Revenues @
Proposed Rates
Incr-ease
--------------
A
B
c
D
1 lOU-V "'34,598,316 "'39,184,589 "'4,586,273
2 A-7 16,080,720 19,455,932 3,375,212
3 8S-2 11,418,981 13, 150,319 1,731,~';38
4 65-1 947,285 1,210,686 263,401
c- PA-1 293,922 380,491 86,569
;.J
6 PA--2 169,856 194,001 24,144
7 lC-1 38,870 42,754 :;:.,884
8 D 5,571 5,699 128
9 LS-l 205 205 (I
10 LS-- 2 15 15 (l
11 OL-l 178 178 (l
12 Total "'63,553,91 '7' $7::::.,624,868 $10,0"70,949
Sources :
Line!: 1--6
Exhibit G, Sheet 2
Lines 7-8
W/P 6-2.
Lines 9--11: E:-:hibit D, Sheet '2
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'-'
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Ci tv of Ver'nan
Development of Surcharge tor
Step 2 Rate lncrease
Schedule Demands
-------- -------
(A) (B)
1 TOU-V 1,083,936
'-:\ A-B 332,677
"'-
'" A-7 723,522
-
4 65-2 555,569
5 6S-1 56,088
6 D 727
7 LS'-1 4,845
8 LS-2 594
9 OL-l (I
10 F'A-l 15,258
11 PA-2 8, :399
12 TC-'1 2,906
1-. Total 2,784,521
~~
Demand Surcharge
TOU-V, A-8
14 A-] and 6S-2 2,695,704
15 Net for- Energy Surchcu-ge
16 kWh for Remaining Sch.
Sources :
Demand
Amount
(C)
$180
55
120
92
9
o
1
(I
(I
3
1
o
$463
448
19,528, :T27
Column B
Exhibit C, Sheet 3.
E:-:hibit G
Sheet 4 of 4
U=<evi sed)
Peak
Demand
(D>
$.000
.000
.000
.000
$0.00017
$15
$.00000
Energ. ,
-----
(F,
$('. t.1~.-.... "'~
~). (;("~'. ~
~J. tJt..~ '..-:
('. (j'.-._-..:
t). (),tJlll_- _ -:.
t). (Hj'_.:
(J. '..tt.jl).:
O. t)<".,_ ':
':..'. t..a~,c..__ ....
(J. (JI_"_' _-:
'J. '~U.h}.. ':
t). I.U..h./ .:~
Column C, Line 13: Difference Between Exhibit B.
Sheets :3 & 4.
Column D : .85468/1.1
Line 14, Column B: Exhibit C, Sheet 3.
Line 16 :
Exhibit C, Sheet 3.
* Includes .025 c/kWh for energy component
of step 2 increase .
':ltv
base
i;.ne'-
S c05 t
-. ve'- (
..
~ e.5
i E)( 1
~ toe
So
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-----
-I tv. 0'1 Vernon
;..se kat.e tor .
t".EI-OY Lost I-\dJLtstment
A
cost ot Enerqy Purchase
\'ernon Sal es
~e5e Cost of Energy
" t:.n st i ng Base Cost
~ Increase in Base Cost
~OL'r ces .
.
Line 1 .. E>:hi bi t B~ Sheet 3.
..
Line '-, .. E>:hibi t C, Sheet :!. .
.. ..
E>:hlbi t H
Sheet 1 of 4
(Revised>
t.c
$4~. ~ 989,864
1,003,155,021
$0.04:3:85
$0.05185
($0.00800)
Exhibit H
Sheet 2 of 4
(Revised)
City of Vernon
Procedures for Calculating the
Energy Cost Adjustment Billing Factor
The rate schedules contained herein are to contain 1
addition to the base rates included in the current tariff" i~
Energy Cost Ad j ustment Bi 11 ing Factor (ECABF) to reflect ~~l";'~"
in the cost of fuel and purchased energy.
The ECABF is to be calculated pursuant to the followln}
equation:
ECABF =
EC e + C
--------- - B
S
e
Where,
ECABF = Energy Cost Adjustment Billing Factor per
Kilowatt-hour Sold
EC = Estimated Fuel and Energy Costs for the Current
e Period
,.
.....
= Correction for Previous Period's Ov-r or
Under-recovery*
S = Estimated Kilowatt-hours to be sold in current
e Period
B
= Energy Cost per Kilowatt-hour included in Base
Rates = 4.385 cents/kWh
* If the previous period average costs were less than 4.33S
cents/kWh, C is negative. If such average costS
were greater than 4.385 cents/kWh, C is positiV.'
Ita Co
scfttd IJ
to' 11.
uti.
W
~ %u.S
i ar' t
* tIt ia
'! tare.
~.
I co.pr
,t lad
.uad
eo..1
To ea
utiai
lold
1ft .
i t,ftat
Une
to 0
u d
. en."
prob
It w
oae.
Une
tntr
.rrt
~
:t
!
.
~
~
l
l
J
t
~-
!eel
revI
co 1
11I0 .
~
Energy Clause Adjustment Billing Factor
Exhibit H
Sheet 3 of 4
(Revised)
~
(Continued)
..
'A computation
!;.--
4.ntdl.l1e V-l is
4,'~ .11 periods
,c.
Sheet
attached to provide the computation sheet
once implementation is completed.
wIn9
l.tte.ted Energy Costs (ECel
-
%t..s 1 through 3 represent the estimated energy costs which
,r. to be used 1n computing the period's ECA. This is an
t,ttmate of the costs the City expects to incur for the
tl':rte lIonth period to which this ECA will apply. It is
(o.prtsed only of commodity or energy costs in keeping with
,t.ndards only of commodity or energy costs 1n keeping with
standards established by the Federal Energy Regulatory
Coemission and various state regulatory bodies.
, in
ft, I.
't Chit.;.,
io calculate items 1(a) and 1(b), the City must obtain
f.timates from Edison of the kilowatt hours expected to be
.old to the City of Vernon during the period the ECA will be
In effect. Edison must also provide an estimate of the ECA
thlt they will be charging the City during that period.
rent
Ltne 2 would be comprised of estimated fuei costs required
to operate the City'S generating units. This charge would
~t deSignated on the billing for operating expenses as being
th.rged to FERC account 541. Fuel. At the outset there will
Frobably be no cost associated with this line item. However
It will become a factor when the units become operational
once again.
!nt
Line 3 represents an estimate of the cost of interruptible
.nergy to be purchased during the period the ECA will be in
tfhct.
se
Correction Factor
JSS
lines q through 1 of the computation sheet are used to
c.lcualte the amount needed to correct for over- or under-
recovery of energy costs In previous periods. Line 4
represents a true-up of the previous period's estimate of
tnergy cost~ on Line~ 1 and 2. These amounts can be taken
~ro. the billings of Edison both for purchased power and for
uel used by the Vernon generating unlt~ for the appropriate
periods being corrected.
8~cause there Is a delay in the availability of expense and
revenue data for individual months, the period for which a
~orrection factor is calculated will lag behind by one
Onth.
)st$
:1\'1.
--
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. GS-l
GENERAL SERVICE
RATES
Per I't1eter
Per "1onth
APPLICABILITY
Applicable to single- and three-phase general servi~~
including lighting and power.
TERRITORY
Within the city limits of the City of Vernon.
Energy Charge
All k~h, per kWh.......................... l2.014t
Minimum Charge:
The Energy Charge shall be subject to a monthly ~ini-~'
charge of $5.00.
SPECI~L CONDITIONS
1. Voltage: Service will be supplied at one stan1ar1
volta:;je.
2. X-Ray Installations: Where the Utility installs :~l
standard transformer capacity requested by a customer to sc:.~
separately an X-ray installation, the billing will be in=r~';~
by $l.0~ per kVA of transformer capacity requested.
3. Temporary Discontinuance of Service: Where t~e us~ ~~
energy is seasonal or intermittent, no adjustments wIll b~~'
for a temoorary discontinuance of service. Any custoner rt,..
to resumi~g service within twelve months after such servi=; ....
discontinued will be required to pay all charges which wo~.'
been billed if service had not been discontinued.
i
I
t
I
~
.
.
$
f
I
I
i
t
Effective
F:ffective
Effective
Effective
~
t
i
f
I
1
!
~
~
l
Authorized
by the City of
Ordinance No.
Ordinance No.
Resolution t.,Jo.
Resolution No.
Vernon
- 1 -
I
I
t
I ".'.
Schedule No. SE
SERVICE ESTABLISHMENT Ca~GE
APPLICABILITY
Applicable to General Service and Domestic Service customers.
TERRITORY
Within the City limits of the City of Vernon.
RATE
For each establishment of electric service.... .........$ 5.00
SPECIAL CONDITIONS
1. The service establishment charge provided for herein is in
addition to the charges calculated in accordance with the applicabl~
schedule and may be made each time an account is established. As
used herein. establishment means each time an account is opened.
including a turn on of electric service or a change of name which
requires a meter reading.
2. In case the customer requests that electric service be es-
tablished on the day of his request or outside of regular business
hours. an additional charge of $5.00 may be made.
3. The service establishment charge is not applicable by cus-
tomers of the Company to service rendered through submeters to
tenants.
,
i\llth:)rizeo ':Jy tho? City af V2rn0;1
'Jrdi~ancc "b.
0rdinanc2 ^h.
Resolution "-JO.
R2s:)lution :--Ia.
Effective
Effective
Ef f eC t i \1 e
Eff(~ctive
J
~........
4. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary Statment.
5. In-Lieu of Tax and Franchise Payment: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in-lieu of tax and
franchise payments.
6. Excess Transformer Capacity: The amount of transformer
capacity requested by a customer which is in excess of the
applicable standard transformer size determined by the Utility as
required to serve the customer's measurable kilowatt demand.
Excess transformer capacity shall be available to all customers
under this schedule and shall be billed at $1.00 per kVA per
month.
A~thorized by the City of Vernon
Ordinance "Jo.
Ordin?nce No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
- 2 -
-""'Iili&
I
t
i
~
CITY OF VER~ON
LIGHT ~ND POWER DEPARTM~NT
SChedule No. GS-2
GENERAL SERVICE
APPLICABILITY
Applicable to single- and three-phase general servic~
including lighting and power.
TERRITORY
Within the city limits of the City of Vernon.
R.I\TES
Per .1 ~ t ~ r
Per '''or.,::.-,
Demand Charge:
All kW of billing demand, per kW........
(Subject to Contract Demand. See Special
Condition No. 10).
$ 9.7:;
Energy charge (to be added to Demand Charge):
All kWh per kWh ..........................
S.(l)3t
Minimum Charge:
The Demand Charge plus the energy charge shall be 5~~,-'
a monthly minimum charge of S19S.ea.
SPECIAL CONDITIONS
1. Voltage: Service will be sup?lied at one standad
vol tage.
2. Billing Demand: Billing demand shall be the kilo~l~'~
rnaximumdemand, determined to the nearest kW.
3. Maximum Demand: The maximum demand in any month 5~1::
the measured maximum average kilowatt input, indicated or ~_.
recorded by instruments to be supplied by the Utility, duri;~:
IS-minute metered interval in the month, but shall not be -
than the diversified resistance welder load comouted in 3::=~: .
ance with the section designated Welder Service' in Rule ~~. .'
Authorized
by the City of
Ordinance "Jo.
Ordinance No.
Resol ut ion No.
Resolution "Jo.
Vernon
Effective
Effective
Effective
Effective
- 3 -
~.
1
;
1
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f
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I
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1
1
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t
,
f
~
i
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-
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.
.
... .<,. .... .;:l" ~
~ " .. ..
~ ~ " ~
1 ~ : ~
,.. .;: - .
~ ..
l~o:
... -... .. _.~ .
p .... .... ~
-
). lit *'
.~
..-
4. Voltage Discount: The charges before adjustment will b~
reduced by 3% for service delivered and metered at voltages of
from 2 kV to 10 kV; by 4% for service delivered and metered at
voltages of from 11 kV to 50 kV; and by 5% for service delivered
and metered at voltages over 50 kV; except that when only one
transformation from a transmission voltage level is involved, a
customer normally entitled to a 3% discount will be entitled to 3
4% discount.
5. Power Factor Adjustment: When the billing demand has
exceeded 200 kW for three consecutive months, a kilovar-hour
meter will be installed as soon as practical, and, thereafter,
until the billing demand has been less than 150 kW for twelve
consecutive months, the charges will be adjusted each month for
power factor, as follows:
The Charges will be decreased by 20 cents per kilowatt of
measured maximum demand and will be increased by 2~ cents
per kilovar of reactive demand. However, in no case s~l~ll
the number of kilovars used for the adjustment be less
than one-fifth the number of kilowatts.
The Kilovars of reactive demand shall be calculated by
multiplying the kilowatts of measured maximum demand by
the ratio of the kilovar-hours to the kilowatt-hours.
Demands in kilowatts and kilovars shall be determinej to
the nearest unit. A ratchet device will be installed on
the kilovar-hour meter to prevent its reverse o?eration O~
leading power factors.
6. X-Ray Installations: Where the Utility installs the
standard transformer capacity requested by a customer to serve
separately an X-Ray installation, the minimum charge will be
increased by $l.O~ per kVA of transformer capacity requested.
7. Temporary Discontinuance of Service: Where the use of
energy is seasonal or intermittent, no adjustments will be made
for a temporary discontinuance of service. Any customer prior to
resuming service within twelve months after such service was
discontinued will be required to pay all charges which would have
been billed if service had not been discontinued.
.3. Energy Cost Adjustment: The rates above are subject to
adJustment as provided for in Part G of the Preliminary
Authorized by the City of Vernon
Ordinance No.
Or:-1 inance No.
Resolution No.
Re301ution "lo.
Effective
Effective
Effective
Effective
- 4 -
Statement.
9. Excess Transformer Capacity: The transformer CdQa--.
excess of a customer's contract demand which is either ~~-~::
by the Utility because of the nature of the customer's lo~~"=
requested by the customer. Excess transformer capacity sh'\;'
billed at $1.00 per kVl.. per month. . a..
10. Contract Demand: A contract demand will be esta=>li.s:-.e' \
the Utility, based upon applicant's demand requiremants f~r _ ?
customer newly requesting service on this schedule and for i~,' !
customer of record on this schedule who requests an incc~15e ., I
decrease in transformer capac i ty in accordance wi th Rule ':0 -. - I
A contract demand arrangement is available upon requ~st for'~"- i
customers of record on this schedule. Contract demand i3 :>H:: t
upon the nominal kilovolt-ampere rating of the Utility's 5~!.'~ " t
transforiller(s) or the standard transformer size detemined '::;, !". I'
Utility as required to serve the customer's stated mea3JC3~!d .
kilowatt deilland, whichever is less and is expressed in kil,_~!~~ }
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11. Minimum Demand Charge: Where a contract demnnd is
established, the monthly minimum demand charge shall be 51.':~.
kilowatt of contract demand.
12. In-Lieu of Tax and Franchise Payment: The total Cj1!J~.
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax J~!
franchise payments.
13. Recordinq Meters: A recording-type meter sh~ll be
installed for all customers purchasing under this schedule,~~'
having peak requirements of 500 kV or more. Customers haVl~i
recording-type meters are not eligible to purchase under t~l~
schedule and must be transferred to Schedule No. TaU-V.
Authorized by th~ City of Vernon
Ordinance ~o.
Ordinance No.
Resolution ~o.
Resolutio:1 No.
Effective
Effective
Effective
Effective
- 5 -
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CITY OF VERNON
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ill 11 :.
LIGHT AND POWER DEPART~ENT
Schedule No. TOU-V
GENERAL SERVICE-LARGE
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APPLICABILITY -
Applicable to general service, including lighting and
power. This schedule is applicable for all customers with
demands of 5~0 kW or higher for whom magnetic tape recording
meters have been installed. Any customer whose monthly maximu'l
demand has fallen below 450 kW for 12 consecutive months may
elect to take service on any other applicable schedule.
TERRITORY
Within the city limits of the~ity of Vernon.
RATES
Per 1I1eter
Per !\1onth
:>.4:' ~ ~ *
.~: ;t:,
Customer Charge:...........................
$55~'.0::
.IJ r :';. ~
~~;
a:-....
Demand Charge (to be added to Customer Charge):
All kW of on-peak billing demand, per kW
$9.9':35
Plus all kW of mid-peak billing demand, per kW
$1.55
at'4 -:
Plus all kW of off-peak billing demand, per kW
(Subject to Minimum Demand Charge. See Special
Condition No. l~)
no
char-je
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his
Energy Charge (to be added to
All on-peak kWh, per kWh
Plus all mid-peak kWh, per
Plus all off-peak kWh, per
Demand Charge)
kWh
kWh
. . .
5.03 5~
4.719t
4.247t
. . .
. . . . .
Auth~rized by the City of Vernon
Ordinance No.
Ordinan::::e No.
Resolution ~o.
Resolution No.
Effective
Effective
Effective
Effective
--
- 6 -
SPECIAL CONDITIO~S
1. Time periods:
Time Periods are defined as follows:
On-peak: 1:00 p.m. to 7:00 p.m.
summer weekdays except holid~ys
5:00 p.m. to 10:00 p.m.
winter weekdays except holidays
Mid-Peak: 9:~0 a.m. to 1:00 p.m. and
7:00 p.m. to 11:00 p.m.
summer weekdays except holidays
8:09 a.m. to 5:00 p.m.
winter weekdays except holidays
Off-Peak: all other hours
Off-Peak Holidays are: New Year's Day, Washin1t~n'j
Birthday, Memorial Day, Independence Day, Labor Jal,
Veteran's Day, Thanksgiving Day and Christmas.
When any holiday listed above falls on Sunday, t~~
following Monday will be recognized as an off-pe~(
period. No change in off-peak will be made for h)l1 ..
falling on Saturday.
The summer season time periods shall commence at 1:: '.
a .m. May 1 and continue through October 31 of ea:j t;:~~
and the winter season time periods shall com~ence J~
12:" 1 a .m. November 1 and cont inue through Apr il n ') t
the following year.
2. Billing Demands: Separate billing demands for th.~ . .
on-peak, mid-peak, and off-peak time periods shall be estat~;~
for each monthly billing period. The billing demand for 7~:;
time period shall be the maximum demand for that time peCl).J
occurring during the respective monthly billing period. T~~
billing demand shall be determined to the nearest kW.
3. Maximum Demand: The maximum demands shall be estaoli$'
for the on-peak, mid-peak, and off-peak periods. The m3xi~)'
demand for each period shall be the measured maximum averaJe
kilowatt input indicated or recorded by instruments, durin) if
IS-minute metered interval, but (~xcept for new customers ~r
Authorized by the City of Vernon
Ordinance No.
Ordinan:::-e No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
- 7 -
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existing customers electing Contract Demand as defined in these
special Conditions) not less than the diversified resistance
welder load computed in accordance with the section designated
Welder Service in Rule No.2. Where the demand is intermittent
or subject to violent fluctuations, a 5-minute interval may be
used.
4. Voltage Discount: The charges before adjustment will be
reduced by 3% for service delivered and metered at voltages of
from 2 kV to 10 kVi by 4% for service delivered and metered at
voltages of from 11 kV to 50 kVi and by 5% for service delivered
and metered at voltages over 50 kVi except that when only one
transformation from a transmission voltage level is involved, a
customer normally entitled to a 3% discount will be entitled to 3
4% discount.
Ii
5. Power Factor Adjustment:
a. Service Delivered and Metered at 4 kV or Greater:
The charges will be adjusted each month for rea~tive
de~and as follows:
" .
t i
The charges will be increased by 20 cents per kilovar
of maximum reactive demand imposed on the Utility in
excess of 20 percent of the maximum number of
kilowatts.
:JK
The maximum reactive demand shall be the highest
measured maximum average kilovar demand indicated or
recorded by metering to be supplied by the Utility
during any 15-minute metered interval in the month.
The kilovars shall be determined to the nearest unit.
A ratchet device will be installed on each kilovar
meter to prevent reverse operation of the meter.
, .0"
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b. Service Delivered and Metered at Less than 4 kV:
The charges will be adjusted each month for the power
factor as follows:
~' '
The charges will be decreased by 20 cents per kilowatt
of measured maximum demand and will be increased by 23
cents per kilovar of reactive demand. However, in no
case shall the kilovars used for the adjustment be less
than one-fifth the number of kilowatts.
IF:
The kilovars of reactive demand shall be calculated by
Authorized by the City of Vernon
Ordinance No.
Ordina:1ce No.
Resolution ~o.
Resolutio:1 No.
Effective
Effective
Effective
Effective
- 8 -
-
multiplying the kilowatts of measured 'T'laxi:nu. "
the rati~ of. the kilovar-h~urs to the kilowa~t~~-i~:
Demands In kIlowatts and kllovars shall be det~ ~:'.
to the nearest unit. A ratchet device will be.f". ;:
installed on the kilovar-hour meter to prevent i~1
reverse operation on leading power factors.
6. Temporary Discontinuance of Service: Where the u~~ ,.
energy is seasonal or intermittent, no adjustments will b~ ~:.
for a temporary discontinuance of service. Any Customer ~r",
resuming service within twelve months after such service :~;_.
discontinued will be required to pay all charges which ~~J' .
been billed if service had not been discontinued. .~
7. Energy Cost Adjustment: The rates above are Subje:: .
adjustment as provided for in Part G of the Preliminary
State:nent.
8. Excess Transformer Capacity: The transformer capa:i:... _
excess of a customer's contract demand which is either r~~Ji~~'
by the Utility becaus~ ~f the nature of the customer's lo~~ ,;
requested by the customer. Excess transformer capacity s~a::
billed at $1.00 per kVA per ~onth.
9. Contract Demand: A contract demand will be establi~','
the Uti! i ty, based upon apPl icant' s demand requi re:nents fJr , i
customer newly requesting service on this schedule an1 f~r J_.
customer of record on this schedule who requests an incre15~
decrease in transformer capacity in accordance with Rule ~).
A contract demand arrangement is available upon request for J;;
customers of record on this schedule. Contract demand is =l~-
upon the nominal kilovolt-ampere rating of the Utility's set.;
transformer(s) or the standard transformer size deter~i:1~~ ::! :
Utility as required to serve the customer's stated mea5lJrJ::::'~
kilowatt demand, whichever is less and is express,ed in I(il)~!~~"
13. Minimum Demand Charge: Where a contract demand is
established, the monthly minimum demand charge shall be Sl.~'
kilowatt of contract demand.
11.1" In-Lieu of Tax and Franchise Payment: The total c:,.,r;-:
computed pursuant to the above rates and charges are to b~ ~,
increased by 3 percent to reflect payments in lieu of tax)-
franchise payments.
A:Jthorized
by the City of
Ordinance No.
Ordinance No.
Resolution "lo.
R~solution No.
Vernon
Effective
Effective
Effective
Effective
- 9 -
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12. Contracts: An additional initial three-year facilities
contract may be required where applicant requires new or added
servin3 capacity exceeding 2,Oe~ kVA.
13. Voltage: Service will be supplied at one standard
voltage.
Authoriz~d by the City of Vernon
Ordinance !'Jo.
Ordina:1ce ~o.
Resolution No.
Resolution No.
Effective
Effe::::tive
Effective
Effective
- 10 -
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CI'fY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. LS-I
LIGHTING-STREET AND HIGHWAY
UTILITY-OWNED SYSTEM
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APPLICABILITY
Applicable to street and highway lighting service
from overhead lines where the Utility owns and maintains
street lighting equipment.
TERRITORY
Within the City limits of the City of Vernon.
RATES
Energy Curtailment
Midn ight 0 r
Equivalent
Service
Per La:n?
Per Month
Lamp Size-Lumens
All Night Service
Pe r Lam:>
Per Month
Mercury Vapor La:nps
3,50~ Lumens
7,0:J0 Lumens
Il,O!J~ Lumens
2", iHHJ Lumens
35,000 Lumens
55,0:30 LUr:lens
High Pressure Sodium Vapor
5,800 Lumens
9,500 Lumens
16,000 Lumens
22,01:J L.lmens
25,5"0 Lumens
47,(]00 Lumens
8.04
10.44
13.76
19.86
30.90
44.65
6.80
7.89
9.9~
13.11
18.65
25.28
Lamps
7.78
9.CH
11.26
13.19
14.42
2~.40
6.96
7.61
8.98
10.09
10.78
13.92
Authorized by the City of Vernon
Ordin.::lnce No.
Ordinance ~o.
Resolution ~o.
Resolutio:1 "Jo.
Effective
Effective
Effective
Effective
- 11 -
Faciliti~5
Chaqe
Per L3'=,
Per '1o~t.:
$5.1:-
5.15
5.7~
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5.3)
5.5'
6. ~.~
S. 35
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SPECI~L CON9ITIONS
1. Standard Equipment Furnished: Bracket or mast arm
construction will be furnished. Where feasible with existing
facilities, center suspension construction may be furnished.
Enclosed luminaires will be furnished for lamps of 2,500 lumens,
or larger, and open reflector lighting units will be furnished
for lamps of 1,000 lumens. Such standard lighting equipment will
be attached to wood poles.
~: l t ~
2. Other than Standard Equipment: Where the customer
requests the installation of other than the standard equipment
furnished by the Utility and such requested equipment is
acceptable to the Utility, the Utility will install the request2~
equipment provided the customer agrees to advance the estimated
difference in cost installed between such equipment and standarc1
equipment. Advances made in connection with such agreements
become and remain the sole property of the Utility; as do the
said equipment.
vie..
s
3. Hours of Service: Under the Utility's standard all nig~t
operating schedule approximately 4,149 hours of service per year
will be furnished.
4. Removal or Modification of Equipment: Where street
lighting service and facilities were ordered removed or modifiej
by a custower and such services and facilities, or their
equivalent, are ordered reinstalled within 36 months from the
date of the order to remove or to modify, the customer shall pay
to the Utility in advance of such reinstallation a nonrefundable
amount equal to the cost of removal or modification of the prior
facilities and the estimated cost of such reinstallation.
Facjlities removed or installed remain the sole property of the
Utility.
5. Energy Cost Adjustment: The rates above for all-night
service are subject to adjustment as provided for in Part G of
the Preliminary Statement. The applicable energy cost adjust~ent
billing factors set forth therein will be applied to 29 kWh per
month per 1,090 lumens for incandescent lamps, to 10 kWh per
month per 1,000 lumens for mercury vapor lamps, and to 4 kWh per
month per 1,030 lumens for high pressure sodium vapor lamps.
6. Energy Curtailment Service:
Auth0rized by the City of Vernon
Ordinance No.
Ordinance No.
Resolution "Jo.
Resolution No.
Effective
Effective
Effective
Effective
- 12 -
--
a. Where the Customer requests the installation andl
remov~l of equip~ent in order to obtai~ Ener]y Jr
CurtaIlment SerVIce, and such request IS acc~ot~jl' .
the Utility, the Utility will comply with such r~q=e~:
provided the customer first agrees to pay to the Jti;-.
the estimated installation cost for any additional..'
equipment required and/or the removal cost of any
equipment currently installed. Such payments will ~1'
be refunded and shall be paid in advance or in ins~~'_
ments acceptable to Utility over a period of not t~ '.
exceed three years. Facilities installed in =on~~:t:_-
with such request become and remain the sole pro~e!ti
the Utility.
b.
Under the Utility's midnight (PST) or equivale~t
operating schedule, approximately 2,09~ hours of
per year will be furnished.
5.3,. ,
. 6. .... :
s~r-;~;-=
c. Facilities charges shall be applicable under this
schedule only when the ~tility has been requestei t1
discontinue the existing service by the custo~er 3~: t
customer has stipulated that the facilities are tJ ','
left in place for future use.
d. The rates above for midnight or equivalent servic~ )"
subject to adjustment as provided for in Part G of ':.. "
Preliminary Statement. The applicable energy cost
adjustment billing factors set forth therein will ~~
applied to 15 kWh per month per 1,000 lumens for
incandescennt lamps, to 5 kWh per month per 1,33J IJ':
for mercury vapor lam?s, and to 2 kWh per month ?~r
1,000 lumens for high pressure sodium vapor lamps.
Authorized by the City of Vernon
Ordinance No.
Ordinance No.
Resolution ~o.
Resolutio~ No.
Effective
Effective
Effective
Effective
- 13 -
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CITY OF VERNON
LIGHT AND POWER DEPARTMENT
.
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Schedule No. LS-2
i : . .
LIGHTING-STREET AND HIGHWAY
...~.
....' ~
CUSTOMER-OWNED INSTALLATION
~! :.
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APPLICABILITY
Applicable to service for the lighting of streets, highways,
other publ ic thoroughfares, and publ icly-owned and publ icly-opera te':
automobile parkin9 lots which are open to the general public, W!1er~
the customer owns the street lighting equipment.
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TERRITORY
Within the city limits of the City of Vernon.
t ~.
RATES
:: ...
RATE A-UN~ETERED SERVICE:
Per Month
All Night Service Midnight Servi"
Multiple Series Multiple Serio
; r
For each k~ of lamp load, per kW..$26.19
$34.05
$15.23
$13.:
.- ~ ." ':
RATE B-~ETERED SERVICE: Per Meter
Meter Charge: Per Month
Multiple Service.............................$ 4.50
Series Service............................... 12.00
Energy Charge (to be added to Meter Charge):
All kWh, per kWh.............................
1\,1\
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7.03t 1./
RATE C-~AINTENANCE SERVICE-OPTIONAL:
In addition to the Rate A and Rate B charges
Lamp Rating
Lumens
1,O"~
2,500
4,0:HJ
6,000
Lamp Type
Incandescent Extended
Incandescent Extended
Incandescent Extended
Incandescent Extended
Per Lallp
per Month
Service......$ 0.33
Service...... 0.33
Service...... 0.43
Service...... 0.42
AJthorized by the City of Vernon
Ordinance !\lo.
Ordinance No.
Resolution NQ.
Resolution lb.
Effective
Effective
Effective
Effective
- 14 -
..-.......olIiIIi.~
10,;)00
3,500
7,;':HJ
11,003
2J,003
35,000
55,000
5,800
9,50:1
16,000
22,000
25,500
47,000
Incandescent Extended Service......
Mercury Vapor................. -._...
Mer cu r y Va po. r . . . . . . . . . . . . . . . . . . . . . .
Mercury Vapor......................
Mercury Vapor......................
Mercury Vapor......................
Mercury Vapor......................
High Pressure Sodium Vapor.........
High Pressure Sodium Vapor.........
High Pressure Sodium Vapor.........
High Pressure Sodium Vapor.........
High Pressure Sodium Vapor.........
High Pressure Sodium Vapor.........
SPECIAL CONDITIONS
1. Ownership of Facilities:
C.45
0.35
0.33
0.40
0.35
0.54
0.49
0.9el
0.31
0.79
0.79
0.79
0.81
a. For multiple systems the Utility will deliver
service at 120, 120/240 volts, or, at the opti~n ~:
the Utility, at 240/283 volts, three-wire, sinJ!--
phase. For series systems the Utility will furr.~ "
and maintain constant current regulating
transformers and deliver service at the secondar;
side of such transformers.
b. T~e customer will furnish and maintain all
utilization equipment beyond the point of deliv~ri
except for maintenance service provided by th~
Utility in accordance with Special Conditio~ 3.
c. Meter locations for multiple systems shall be at
points ~utually agreed upon. Meter locations f"
series systems shall be on the primary supply
circuit to the constant current regulating
transformer at a point acceptable to the Utilitt.
2. Lamp Load: The lamp load for regular (general pur?';'
multiple incandescent lamps shall be the manufacturers' lam?
rating in watts.
The lamp load in watts for lumen rated street lightin] 1\--~
shall be as follows:
Authorized by the City of Vernon
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
EffeCtive
Effective
- 15 -
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HIG'i
MERCUR"f PRSSS~.HE
INCANDESCENT VAPOH S ::)1:)1 !J ..., V\D .~
"'1ULTIPLE SERIES
GROUP EXT- GROUP EXT-
RE- EN,!)- RE- EN~-
R~G:.J- PLACE ED REGU- PLACE ED
LUr-1ENS LAR MENT SVC. LAR SVC. SVC. for] LT. ~F:~I:::'.
Watts Watts Watts Watts Watts Watts Watts Watts .~? t t.;-3
6~~ 55 58 42 44
S:J3 57
1,03;) 35 92 lC13 62 65 73
2,5~O 175 139 202 143 152 164
3,501 125
4,~110 258 295 327 210 220 251
,,' 5,8J:l 32 3:>
.. . !),~3:J 37a 4~' 5 443 31 ~ 325 364
~-
1 < , 7,CJ~:J 2a8
.'
9,5(}a 140 121
f 10,01:1 575 520 59:l 525 558 1J~5
11,30a 292
15,0J~ 80;' 8Sfl 755 822 447
1fi,3J:1 202 17 c;
r i 2J,OJrJ 447
22,:J:10 2~3 233
25,001 1,275
25,5:3;' 32:1
3 5 ,DC :1 753
r 47,::}~0 435
,
55,0:D 1,059
Total lamp load shall be determined to the nearest 1 11:~ l< '" .
~.
A~th~rized by the City of Verno~
Ordinance 'lJo.
Ordinance N~.
Re s ~ III t ion ~,Jo.
Resolution No.
Effective
Effective
Effective
Effective
- 16 -
---
3. Maintenance Service: Maintenance service furnis~~~ ~I
the Utility under Rate C for the lamps specified shall incl~~~
the followin]:
a. Renewal of lamps after the original installati~n
the customer.
b. Re)ular inspection.
c. periodic cleaning of globes.
d. Labor of replacing lamps and globes.
Incandescent lamps furnished under this provision will ~e
extended service lamps only. Mercury vapor lamps and hi1h
pressure sodium vapor lamps furnished under this provisio~ ~ill
be as s?e~ified by the Utility. Globes for renewal shall be
furnished by the customer. Maintenance service will be furni5:-
only w~ere, in the opinion of the ~tility, no undue hazard )r
expense will result be~ause of lo~ation, mounting height, ~r
other reasons.
4. Switching Facilities: For all night or midnight (?1:,'.
Standard Time) service under the Utility's standardoperatinJ
schedules, the Utility will furnish, maintain, and operate t~!
necessary switching facilities. For other operating scheJ~l~~,
the customer shall furnish, maintain, and operate switchin)
facilities as specified by the Utility and take metered serv::!
under Rate B.
5. Hours of Service: Under the ~tility's standard all :-.:;:
operating schedule, approximately 4,140 hours of service ?~( i~ir
will be furnished and under the Utility's standard midni1'1!:
(Pacific Standard Time) operating schedule approximately 2,~)'
hours of service per year will be furnished.
6. Removal of Equipment: Where street lighting servi~:_:~'
facilities were ordered removed by a customer and such 5erv~~~
and facilities, or their equivalent, are ordered reinstall~~
within 36 months from the date of the order to remove, th~: ,
customer shall pay to the Utility in advance of reinstallat~)'
nonrefundable amount equal to the cost of removal of the pel)!
Authorized by the City of Vernon
Ordinance ~o.
Ordinance No.
Resolution No.
Resolution \Jo.
Effective
Effective
Effective
Effective
- 17 -
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facilities and the estimated cost of such reinstallation.
Utility owned facilities removed or installed remain the sole
property of the ~tility.
7. Energy Curtailment Service: Where the customer requ~sts
the installation and/or removal of equipment in order to curtail
energy requirements, and such request is acceptable to the
Utility, the Utility will comply with such request provided the
customer first agrees to pay to Utility the estimated cost
installed or any additional equipment required and/or the removal
cost of any equipment currently installed. Such payments .....ill
not be refunded and shall be paid in advance or in installments
acceptable to Utility over a period of not to exceed three ye~rs.
Facilities installed in connection with such requests become an~
re~ain the sole property of the Utility.
8. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing factors
and fuel collection balance adjustment billing factor set forth
therein will be applied to the kWh shown below:
-\"
. -
Type of Service
k!1h Pe r ki-: -
Per Month
All Ni3ht ~ultiple
All Night Series
~idnight Multiple
!Y1idni3ht Series
355
462
180
233
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;>
Authorized ~y the City of Vernon
Jrdi!1ance "lo.
Ordin.::3nce No.
Resolution No.
Resolution :-Jo.
Effective
Effective
Effective
Effective
- 18 -
"'ITY OF Vi::RNJN
LI~HT AND PO',tJER DEPARTMEI-lT
Schedule No. OL-1
OUTDOOR AREA LIGHTING SERVICE
APPLICABILITY
Applicable to outdoor area lighting service, other th~~
street and highway lighting service~ supplied from overhead li~:.
where the Utility owns and maintains the area lighting eq~i?~".~.
'fSHRITORY
Within the city limits of the City of Vernon.
RATES
LU~I~~IaE CHAR;~: ENERGY CURTAIL~E~r S~l~. .
MIDNIGHT OR
EOUIV~LENT FA:IL:::
ALL NIGHT SERVICE SERVICE C;L\ ,--:.~
LA~P SIZE-LUM8NS
PER Ll\!\1P
PER MONTH
PER LA"-1P
PER MON'rH
*
MER:JRY VAPO~ L\~PS
7,0;1J LU'":lens.
2(1,C1~H~ Lumens.
$10.49
$21. 03
$ S.07
$14.17
HI'3n P~ESS:J:lE SODIUM VAPOR LAMPS
5,SJO Lumens.
9,50!J Lumens.
22,300 Lumens.
$ 7.83
$ 9.05
$13.24
$ 7.~5
$ 7.72
$10.31
. .
POLE CHARGE (to be added to
Luminaire Char3e):
For each additional new wood pole installed. . . .
*Clos~d to new installations as of February 1, 1930.
Authorized ~y the City of Vernon
Ordinance ~o.
Ord i nance l-Jo.
Resolution "Jo.
rt2so1ution No.
Effective
Effective
Effective
Effective
- 19 -
P::~ L\"
PE!~ <')'.
SS.l:"}
$'j.l~
$5. ~ '
$5.SS
S'1.4.~
PC;q ?~:.-
PE1 .j;. .~
. $ ~. ').
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SPECIAL CO~9ITIO~S
1. Hours of Service: Area all night lighting service will he
furnished from dusk to dawn, approxi~ately 4,140 hours per year,
by Utility-owned luminaires supplied from the Utility's existin)
120/240 volt overhead circuits and mounted on existin~
Utility-owned wood poles as standard equipment.
." ,
... ... ... .
2. Other Than Standard Equipment: Where the customer
requests the installation of other than the stand3rd equipment
furnished by the Utility and such requested equipment is
acceptable to the Utility, the Utility will install the request~~
equipment provided the customer agrees to advance the estimate~
difference in installation cost installed between such equip~ent
and standard equipment. Advances made for this purpose will not
be refunded. Facilities installed in connection with such
agreements become and re~ain the sole property of the Utility.
1 :". : _
3. Service and Facilities Furnished: This service will be in
accordance with Utility's specifications as to the e~uipment,
installation, maintenance, and operation.
.,. - -,0
. .
. ~ ~-~
" " 4.
4. Replacement of Lamps: The Ut i 1 i ty will repl ace la:n?s 0:1 :;
scheduled basis, and individual lamps will be repla~ed upon
service failure, as soon as practical after notification by
customer, subject to Utility's operating schedules.
5. Contract: A written contract for a term of one year ~ill
be required by the Utility when service is first establis'1e:~
under this schedule.
~. Type of Service: This service will be furnished only
where the installation is considered by the Utility to be of d
permanent And establishe(l chara~ter.
7. Removal or Modification of Equipment: Where area li)htin]
service and facilities were ordered removed or modified by a
custo~er and such service and facilities, or their equivalent,
are ordered reinstalled within 3~months from the date of th?
order to remove or to modify, the customer shall pay to the
Utility in advance of reinstallation a nonrefunda~le amo~~t e~j~l
to the cost of removal or modification of the prior faciliti25
and the estimated cost of such reinstallation. Facilities
removed or installed remain the sole property of the Utility.
A;Jt~lOrizcd by the City of Vernon
Ordinance '..Jo.
Or:jinance No.
Resolution "Jo.
Resolution "Jo.
Effective
Effective
Effective
Effective
- 2:1 -
~
8. Energy ~ost Adjustment: The rates above for all-ni __
service are subject to adjustment as provided for in Part GJ--;
t~~ ~reliminary Statement. The.app~icable ene~gy cost ~~ju3~:'-'
bllllng factors set forth thereln wlll be applled to 10 k~h ~.~ .
month per 1,0n~ lumens for mercury vapor lamps and to 4 ~~~ ~::
month per 1,3JB lumens for high pressure sodium vapor lam?s.' .
9. Energy Curtailment Service:
a. Where the customer requests the installation anj/~r
removal of equipment in order to obtain Energy
Curtailment Service, and such request is acceot3~1. . .
the Utility, the Utility will comply with such re4~:~~
provided the customer first agrees to advance th~
est i:n ate din s tall a t ion co s t 0 f any add i t i on a 1 I?'~ U i :.., .
reqJired and/or the removal cost of any eqJip~e~t .
currently installed. Such advances will not ~~
refunded. Fa~ilities installed in connection wit~; i..l:_
requests become and remain the sole property of t~~
Utility.
b. Under th~ Utility's midnight Pa~ific Standard Ti,e
(PST) or equivalent service operating schedule,
a?proximately 2,090 hours of service per year will ~:
furnished.
c. Facilities charges shall be applicable under this
schedule only when the Utility has bee~ request?~ t)
discontinue the existin3 service by the custo~~r 1~:
the customer has stipulated that the facilities ar~ t)
be left in place for future use.
d. The rates above for midni-Jht or equivalent servi:~3 H-
subject to adjustment as provided for in Part J ): : - .
Preliminary statement: ~ ~
~--- ~(Lp~ ~'7
tz::!f;: ~~~ ::;.:;~-:;%/
! ;t; r ~ f(ltu-t, ~ ~--~/---?
~. /fYZFO_f~~ ~ ~~
/{;r6M~~ ~ & ;J- k~~~
4i--~ ~/~ ~ tf r-7/~LLk.~
l~ /--_~ ~/ L-~~/ / /'
Authorized
by the City elf
Ordinance :-b.
Jrdinan~e ;\l:J.
Resolution >":0.
R~301ution Nel.
Vernon
Effective
Effective
Effective
Effective
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- 21 -
...4
CITY OF VERNON
:. ~ .
LIGHT & Pv~ER DEPARTMENT
r
Schedule No. TC-I
TRAFFIC CONTROL SERVICE
~ .
APPLICABILITY
Applicable to single-phase service for traffic-directional
si'gns or traffic-signal systems located on streets, highways and
other public thoroughfares and to railway crossing and track
si':Jna1s.
t'J
T':::RRITJRY
Within th~ city li~its of the City of Vernon.
..I:
RATES
p~~ "'ETF:1
PE!{ "'Tn~l
Customer Charge: S~.75~
En~rgy Charge (to be added to Customer Charge):
All k~h, per kWh 8.G2;t
~inimum Charge: The monthly minimum charge sh?ll be t~e
monthly Customer charge.
::
t:
SPECIAL CO~ryITIONS
1. Voltage: Service will be supplied at one st?ndrtrJ
voltage not in excess of 243 volts or, at the option of the
Utility, at 24]/43~ volts, three-wire, single-phase.
r! ~.
2. Energy Cost Adjustment: The rates above are subject t~
adjust~ent as provided for in partG of the Prelimin~ry
Sta tellle n t .
al
3. In-Lieu of Tax and Franchise Payment: The total chArge.:;
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax -"Int)
franchise payments.
Auth~rized by the City of Vernon
o r din i) n c e !.J 0 .
Orrli ni)!):;e No.
Resolution !'Jo.
Resolution "l'J.
Effective
Effective
Effective
Effective
- 22 -
--
--
CITY ~F VEq~ON
LIGHT AND POWER DEPARTMENT
Schedule No. S
STANDBY
APPLICABILITY
Applicable to standby or breakdown service where the entir:
electri~al requirements on the customer's premises are not
regularly supplied by the Utility.
TE:{RIf()KY
Within the city liillits of the City of Vernon.
R..'\TES
Pe r '-1e t ~ r
Standby Charge: Per ""Iont:l
First 21 kW of ~ontract demand, per kW........$ 4.00
All ex~ess kW of demand, per kW...............$ 1.71
The standby charge sh~ll not be less than S20.0J ?er n?,t" .
Regular Schedule Charges (to be added to Standby Char]e):
All energy ch~rges of the applicable regular service
schedule designated in the service contract plus a char]~ ~!
$9.25 per kW of on-peak demand in any month.
Minimum Charge: The monthly minimum charge shall be the
standby charge plus the regular schedule minimum charge.
SPECIAL CONDITIONS
1. Contract Demand: In case the customer desires th~ Jti:.:.
to stand ready to supply the entire connected load of the . ,"
customer's plant, or an isolated part thereof, then such maxI.
load will be estimated by the Utility, based on tests and o~~~~ .
information available. In case the customer desires the Utl~:'1
to stand ready to supply a number of kilowatts less than t~d.
maximum demand of the entire customer's plant, or an isolat~:
part thereof, then the customer and the Utility shall agra~ ~~~
the number of kilowatts the Utility will stand ready to sU~?~:
and the custOr.1er shall, at his own expense, furnish 'and inst3 ~.
Authorized by the City of Vernon
Ordi:1ance !'Jo.
Ordin-3:1ce !'Jo.
Resolution "Jo.
Resolution \Jo.
Effective
Effective
Effective
Effective
- 23 -
-'"
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suitable circuit breaker enclosed in a steel box equipped with a
lock, all to be approved by and under the sole control of the
Utility, and adjustment and operation of said circuit breaker to
be in no way interfered with by the customer. This circuit
breaker shall be set to break the connection with the Utility's
service when the customer's maximum demand exceeds the number of
kilowatts which the Utility stands ready to supply, in '.-lhich caS2
the Utility will renew the connections upon due notice.
2. Contract: This schedule will apply only where the
customer will sign a service contract for at least one year.
3. Parallel Operation: This schedule is not ap?licable for
parallel operation of the customer's plant with the service of
the Utility.
4. Maximum Load: The Utility reserves the right to establisl
the maximum load served under this schedule.
,l\ilthori zed by the Ci ty of Vernon
Ordinance ~o.
:)rdinan~e r-Jo.
Resolution No.
Resolutio:1 "Jo.
Effective
Effective
Effective
Effective
- 24 -
CITY JF VE~NJN
LIGHT AND POWER DEPARTMENT
Schedule No. D
DOMESTIC SERVICE
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APPLICABILITY I
Applicable to domestic service including lighting, heatin], :; I
and po~er or combination thereof in a single-family accommod~ti)~. .
!
TERRITJRY I
Within the city li~its of the City of Vernon.
I
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Per Meter Per ~J~t. I
Domestic Servic~ I
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Charge.............................~..
S 1. 5;~
Ra.TES
Ener~y Ch~r3e (to be added to Customer Charge):
All kWh, per kWh...............................
4.5t
~inimum Charge:
The monthly minimu~ charge shall be the
monthly Customer Charge.
2. In-Lieu of Tax and Franchise Payments: The total c~:r1!;
com?uted pursuant to the above rates and charges are to be. l:1:r.. . .
by 3 percent to reflect payments in-lieu of tax and franC~lS!
payments.
SPECIAL CQN~ITIONS
1. Energy Cost Adjustment: The rates a~ove are su~je=t t1
adjustment as provided for in Part G of the Preliminary Stata'~':.
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Effective
Effective
Effective
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Authorize::1
by tho: Ci ty of
Ordin-3nce No.
Jrdin-:lnce ~o.
Resolution 1\10.
q~5olution 'I/o.
Vernon
- 25 -
......."..-
CITY OF VERNOI~
LIGHT .I\ND POWER DEP.I\RTMENT
Schedule No. PA-l
POWER-AGRICULTURAL AND PUMPING
CONNECTED LOAD BASIS
- .
-.~
APPLICABILITY
Applicable to power service for general agricultural purpos~s
or for general water or sewerage pumping.
i y;.
TER~ITJRY
Within the city limits of the City of Vernon.
RATES
~ . ,
..\,. .
Monthl y
Service Char]2
Per ""!eter
Horsepower of
Co:mected Loa1
Per Meter
2 and over
Per hp
$1.00
Energy Charge to be added to Service Charge-Rate
All kWh, per kWh............................ 9.5S3t
~inim~m Charge: The monthly minimum charge shall be the
~o~thly Sarvice Charge.
? t t.
SPECIAL C~NDITIONS
1. Voltage: Service will be supplied at one standard ?o~er
voltage.
? S
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2. Connected Load: Connected load is the sum of tbe rate.l
capacities of all of the customer's equipment that it is ?ossi~l~
to connect to the Utility's lines at the same time, determin~J :'0
the nearest 1/10 hp. In no case will charges be based on less
than 2 hp for sinjle-phase service or no less than 3 hp for
three-phase service. The rated capacity of the customer's
equipment will be the rated horsepower output of standard ratei
Authorized by the City of Vernon
~rdinance "Jo.
Ordinan.:::e :-.lo.
Resolu~ion 11/0.
Resolution "Jo.
Effective
Effective
Effective
Effective
- 2'i -
motors, th~ rated horsepower of welders determined in aCC0r~3~~.
with the section designated Welder Service in Rule ~o. 2, ani "::
rated kilovolt~n~?ere input capacity of other equipment, wit~ -
each kilovol t-ampere of input considered equal to one hors~?').:.r
Normally such ratinJs will be based on the manufacturer's ra~i:~.
as shown on the nameplate or elsewhere but may, at the oPtio~';~
the Utility, be based on tests or other reliable information. .
3. Overloaded Motors: Whenever, upon test, any motor unj0f
normal operating conditions is found to be delivering more t1,',
115 percent of its capacity as indicated by its nameplate rati~:
the Utility may disregard the nameplate rating and base its .1
charges upon the output as calculated from test. Any motor ""::li::.
is billed on a basis in excess of its nameplate rating in
accordance with this special condition shall be tested at
intervals to be deter~ined by the Utility or u?on notificati?~ :/
the customer of a permanent change in operating conditions.
4. Temporary Reduction of Connected Load: Where the us~ )f
energy is seasonable or intermittent, no adjustment will be ~~~!
for any te~?orary reductio~ of connected load. Any cU3to~er,
prior to resuming service o~ such connected load within 12 D?~t~:
after it w~s disconnected, will be required to pay all Char]93
which would have been billed if the temporary reduction of
connected load had not been made.
5. Energy Cost Adjustment: The rates above are subject t~
adjustment as provided for in Part G of the Preliminary
Statement.
s. In-Lieu Tax and Franchise Payments: The total Char]~3
co.ilputed f)ursuant to the above rates and charges are to be
increased by 3 p.:rcent to reflect payments in-lieu of tax n:d
franchise payments.
Authorized by the City of Vernon
Ordinance ~o.
Or::linance No.
Resolution ~o.
qesolution "Jo.
Effective
Effective
Effective
Effective
- 27 -
~
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CITY 8F VERNON
I:.::
t. ".
LIGHT AND PO~-JER DEPoZ\RTI'v1ENT
1-2 r .
Schedule No. P~-2
:: :
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P~WER-ASRICULTURAL AND PUMPIN~
DE~.Z\~D BASIS
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APPLICABILITY
A?plicable to power service for general agricultural purposes
or for general water or sewerage pumping.
.:)j,
TERRIT0RY
Within the city limits of the City of Vernon.
) ~ I
RATES
) f
Demand Charge:
Per ~eter
Per Month
i:; :
. . -
1\"..J I
First 75 kW or less of billing demand..... $
All excess k~ of billing demand, per kW... $
525.01
7.JO
Ener)y Charges (to be added to Demand Charge):
All ko,tJh per kl^lh
7.305t
Minimum Char-]e:
The ~onthly ~inimum charge sh3ll be the ~onthly De~3nJ
Char'je.
SPSCIAL CONDITI')NS
1. Voltage: Service will be supplied at one stand3ra
'''01 tage.
2. Billing Demand: The billing demand shall be the kilo'N3tts
of maximu:n demand but not less than 50% of the highest maximJ;;)
deman~ ~stablished in the preceding eleven months, however, in nJ
case shall the billing demand be less than 75 kW. Billin3 de~an~
sh:'l be determined to the nearest kW.
3. ~aximum Demand: The maximum demand in any month shall be
the measured maximum average kilowatt input, indicated or
recorded by instruments to be supplied by the Utility, durin] ~~y
15-minute metered interval in the month, but not less tha~ th~
^~th'Jrized by the City of Vernon
Ordinan~e No.
Ordinance No.
Resolution ~o.
~':;301ution \lo.
Effective
Effective
Effective
Effective
- 23 -
~~.
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diversified resistance welder load computed in aCCorj3~-~ 4i~.
the section designated Weljer Service in Rule No. 2. '~;0C~
demand is intermittent or su~ject to violent fluctu3tio~s, ]
5-minute interval may be used.
4. Power Factor Adjustment: When the billing demanj ~'5
exceeded 203 kW for three consecutive months, a kilovar-h)u(
meter will be installed as soon as practical, and, therea:~.~
until the billing de~and has been less than 150 kW for t~;i~:'
consecutive months, the charges will be adjusted ea~h mO~t~ !;~
power factor, as follows:
The Charges will be decreased by 20 cents per kilo~3:: ~:
measured maximum demand and will be increased by 2~ =~.:~
per kilovar of reactive demand. However, in no ~a5~ ~.,'
the nu~ber of kilovars used for the adjustment be l~s! .-
than one-fifth the number of kilowatts.
The Kilovars of reactive demand shall be calculat:d ~I
multiplyin] th~ kilowatts of measured maximu~ 1e~~~] ~I
the ratio of the kilovar-hours to the kilowatt-~our5.
Der.1ands in kilowatts -"'nd kilovars shall be deter1in.~' tJ
the nearest unit. A ratchet device will be install~; J.
the kilovar-hour meter to prevent its reverse op~r~ti"
leading power factors.
5.
Temporary 9iscontinuance of Service: Where t~~ J3~ )~
energy is seasonable or intermittent, no adjust1~nt3 11~:
be made for a tem?orary discontinuance of service. ~'i
customer, prior to resuming service within twel'J:?--:).lt.\~
after such service was discontinued will be regJir~1 :1
pay all charges which would have been billed if sec~i:'
had not been rliscontinu~d.
6.
EnerJY Cost Adjustment: The rates above are 5~hj~~t t'
aJjustment as provided for in Part G of the Preli~i1'ri
Statement.
7.
In-Lieu of Tax and Franchise Payments: The total c:':"o
computed ?ursuant to the above rates and ch~r~e~ ~r~l""
increased by 3 percent to reflect payments In-Ileu "
and franchise payments.
8.
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Excess Transformer Capacity: The transformer ca~~- ::
. h . - elt"1c:.
excess of a customer's contract demand whlc l~
Authorizej by th~ ~ity of Vernon
Ordi:1ance "Jo.
Ordina:1ce ~:).
aesolution No.
Resolution 'lJ0.
Effective
Effective
Effective
EffectiVe
- 29 -
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required by the ~tility because of the nature
custo~er's load or requested by the custo~er.
transformer capacity shall be billed at $1.0J
month.
of the
Excess
?er kVA.
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9. Contract Demand: A contract demand will be establishe0 ~j
the Utility, based on applicant's demand requirements for
any customer of record on this schedule who requests an
increase or decrease in transformer capacity in accordan~e
with Rule No. 12u. A contract demand arrangement is
available upon request for all customers of record on this
schedule. Contract demand is based upon the nominal
kilovolt-ampere rating of the Utility's serving
transformer(s) or the standard transformer size determine-]
by the Utility as required to serve the customer's state1
measurable kilow3tt demand, whichever is less and is
expressed in kilowatts.
"
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l~. ~inimum Demand Charge: Where' a contract de~~nd is
established, the monthly minimum demand charge shall be
$1.00 per kilowatt of contract demand.
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A~thorizeJ by the City of Vernon
Jrdinance No.
Ordinan~e "Jo.
Resolution No.
Resolutio:1 No.
Effective
Effective
Effective
Effective
- 3;1 -
f'
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C:1TY.OF VERNON
LIGHT AND.POWER'OEPARTMENT
Schedule N~~ C-l
COGENERATION .SOOR.CE
APPLICABILITY
Applicability - applicable to transportation for cogenerators.
TERRITORY
Within the city limits of the. City: of Vernon.
RATES
Transportation demand rates will: be provided for in ~
transportation agreement with each individual cogenerator in
accordance with recommendations contained in the Rate. Oesign
Report approved herein.
Authorized by the City of Vernon
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
- 31 -
'V (14 ?o g , 9P
BAKER G. CLAY & ASSOCIATES. INC.
REPORT ON RATE DESIGN
CITY OF VERNON,' CALIFORNIA
Municipal Light Department
December 1983
REPORT ON RATE DESIGN
CITY OF VERNON, CALIFORNIA
MUNICIPAL LIGHT DEPARTMENT
December 1983
Prepared by
Baker G. Clay & Associates, Inc.
Section
I.
II.
III.
IV.
V.
VI.
VII.
VIII.
IX.
x.
Table of Contents
Description
Introduction
Adequacy of Revenues
Under Existing Rates
Revenue Requirements
Allocation of Revenue Requirements
Proposed Changes in Rate
Schedule Structure
Edison Rates
The Design of Rates
The Energy Cost Adjustment
Billing Factor (ECABF)
PURPA Standards
Concl us ion
Page
1
5
7
10
12
17
21
27
28
35
I. INTRODUCTION
On November 8, 1983, Southern California Edison Company
(Edison) tendered for filing with the Federal Energy
Regulatory Commission (FERC) in Docket No. ER84-75 a
proposed two-step increase in its wholesale rates for
service to Vernon and seven other wholesale customers. The
Step 1 rates provide for an increase in jurisdictional
revenues of approximately $32.6 million (13.19\) for the
twelve month test period ending December 31, 1984. The
Step 2 rates would result in an additional increase in
revenues above the Step 1 rates of approximately $9.9
million (4.9\), for a total increase of $42.6 million
(17.1\). Edison requested effective dates for the Step 1
and Step 2 rates of January 7, 1984 and January 8, 1984
respectively. The Step 1 rates reflect a return on equity
of 13.25 percent wh~ch, in Edison's opinion, should
encourage the FERC to grant a suspension of only one day,
while Step 2 rates reflect a return on equity of 16 percent.
The Commission may suspend a rate increase for as long as
five months or as little as one day, depending upon the
recommendations of its staff after a preliminary review. We
believe the proposed rate to be so as excessive as to
require a full five month suspension. The Step 1 rates
could become effective as early as January or as late as
June. Likewise, the Step 2 rates could become effective in
January, or be suspended to a date as late as early June. At
this time the Commission has not issued an order and
probably will not until early January, and we will not know
the actual efective dates until that time. We thus
recommend that the rates designed herein to track Edison's
Step 1 and Step 2 rates be made effective on the same dates
-1-
II
that the FERC allows Edison's Step 1 and Step 2 rates. Both
Step 1 and Step 2 rates are subject to ultimate refund
pending FERC action on the merits of the proposed increases.
While Vernon and the other wholesale customers have
vigorously protested the proposed increase, and while such
rates may ultimately be reduced and some refunds required,
Vernon's cost of purchases will increase dramatically with
the proposed increases. Edison's Testimony indicates that
the major reasons for the proposed increase is to reflect
SONGS 2 and SONGS 3 costs and to include 50 percent of
construction work in progress (CWIP) in the rate base.
Under the policy of including CWIP in progress in the rate
base, today's ratepayer is paying plant costs on plant that
will go into service to serve future customers. This is
not allowed at the CPUC, but the FERC has recently adopted a
policy of permitting such practice.
Sheets 2, 3, and 4 of Exhibit B show the calculation of
Vernon's cost of purchases from Edison under existing rates,
Step 1 rates and Step 2 rates, respectively. The following
table shows Edison's estimate of the increases in costs to
Vernon under the Step 1 and Step 2 increases:
Cost
to Vernon
(000's)
Step 1
Step 2
Increased Rates
Existing rates
Increase
$72,983
65,694
$ 7,289
$75,297
65,694
$9,603
The Step 1 increase in the cost of Vernon's purchases
from Edison will ,amount to approximately $7.3 million per
year, assuming the same billing demands experienced during
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12/4/83
the year ending October 31, 1983, while the Step 2 increase
will amount to another $2.3 million per year for a total
increase in the cost of Vernon's purchases from Edison of
$9.6 million per year, or by 14.6 percent.
The increases in the energy component of the rates are
routinely reflected in Vernon's Energy Clause Adjustment
Billing Factor (ECABF) which is changed every three months.
The increases in Edison's demand charges, however, are not
reflected in the ECABF, and Vernon must therefore increase
its base rates to recover these increased costs. This rate
increase follows major rate increases in three other filings
that have yet to be resolved wherein Edison estimated its
increases to be as follows:
No.
Amount of
Increase
(Millions)
Percent of
Increase
Docket
ER79-l50
ER8l-l77
ER82-427
$5.5
$28.6
$34.4
4.0%
7.4%
15.7%
The above noted increases are without the increases
proposed for nuclear stations that had in fact been included
in the proposed increases in Docket Nos. ER81-177 and
ER82-427. The rates established in each of these three
filings are effective subject to judicial determination and
may be rolled back. If so, this will result in refunds to
the cities.
Edison also proposes major changes in its rate design,
including the addition of a demand charge during the mid
peak period and time of use (TOU) energy rates. The new
rates filed by Edison, including the changed rate form, will
also become effective subject to judicial determination and
may be changed. If so, power and energy purchased during
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12/6/83
the period subsequent to the change in rates will be priced
at the rates resulting from the regulatory process and the
excess revenues collected by Edison will be refunded.
This report contains my following recommendations for
the adjustments of Vernon's rates to allow Vernon to recover
its cost of service, including the increased cost of
purchases from Edison, in a fair and equitable manner,
pursuant to costs estimated to be incurred in the estimated
test year ending December 31, 1984: (1) design rates to
become effective January 7, 1984 , or whenever Edison's
rates are allowed to become effective, to recover Vernon's
costs, including the cost of purchased power and energy
under Edison's Step 1 rates, as allocated among the various
classes of service; and, (2) provide for a surcharge to
recover the increase in the cost of purchases under Step 2
rates, to become effective at the time that the FERC allows
Edison's Step 2 rates to become effective.
We also recommend several changes in Vernon's rate
schedules to track Edison's changes in its rate schedule.
Because of Edison's greatly expanded time of use rates, we
recommend the conversion of Schedule A-8 to a time of use
rate, Rate Scehdule TOU-V. With such a rate schedule, it
will be appropriate to eliminate the special contracts with
Byron Jackson and Steel Casting. This new form of rate
should be helpful to our larger customers in several ways.
Because of the favorable load patterns of these customers,
they will enjoy lower overall rates than would exist without
a time of use rate. Also, because the savings realized by
the system because of any improvement in the load patterns
of individual customers will be flowed directly through to
the customers responsible for the savings. This gives each
customer more flexibility in controlling its cost of power
and energy. The metering equipment to make this rate design
feasible is in place, or will shortly be in place.
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12/5/38
II. ADEQUACY OF REVENUES UNDER PRESENT RATES
Vernon's revenues under its existing rates are
approximately equal to its cost of providing utility
service, including its operating costs and cost of purchases
from Edison, as shown in Exhibit A. Column B of Exhibit A
shows Vernon's monthly revenues for the twelve month period
October 1982 through September 1983. Column C shows
Vernon's cost of purchases from Edison during this period,
and Column D shows the excess of Vernon's revenues over its
cost of purchases from Edison. As shown on Line 13, Column
D, Vernon's revenues for the year exceeded its cost of
purchases from Edison by approximately $4.7 million. During
this period, however, Vernon reduced the reserve in its ECAC
account under its Energy Cost Adjustment Clause by $1.1
million. This results in a negative adjustment to
revenues. Also, Vernon flowed through refunds of $2.0
million during this period, which results in a positive
adjustment to revenues. Finally, Vernon's off system
purchases, including all costs, amounted to $1.1 million,
which requires a positive adjustment to costs. The net
result is that Vernon's adjusted revenues exceed its cost of
purchases by $4.4, which was available to cover Vernon's
fixed cost of owning and operating its utility system.
Vernon's annual costs, in addition to its cost of purchased
power and energy, as set forth on Sheet 1 of Exhibit B,
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12/6/83
amounted to $4.0 million, and payments in lieu of taxes and
franchise fees amounts to $1.8 million, for a total of $5.8
million. Vernon's net revenues were thus deficient by
approximately $1,429,000. This comparison is set forth in
the following table:
Revenues
Amount
(000' s)
$60,988
1,985
<1,102>
$61,871
56,268
1,154
$4,449
5,878
$1,429
Refund Flow thru
Increase in ECAC Reserve
Net Revenues
Cost of Purchases from Edison
Other Purchases
Difference
Vernon's Non-purchase Costs
Deficiency
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r
f
I
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12/4/83
III.
REVENUE REQUIREMENTS
." ~
The City of Vernon has certain revenue requirements
(cost of service) associated with the rendering of
electrical service to its customers. These revenue
requirements are made up of the cost of purchases from
Edison, the cost of operations under the operating agreement
with Edison, other miscellaneous costs, depreciation of the
electrical facilities used to provide the service, and
return (or interest) on the investment in the electrical
facilities owned by Vernon. A breakdown of Vernon's annual
revenue requirements including the cost of purchases from
Edison under the filed rates (without giving effect to the
fuel clause adjustment) is shown on Sheet 1 of Exhibit B for
the year ended October 31, 1983. Vernon's annual revenue
requi~ements as estimated for the future with Edison's
Step 1 rate increase in effect is shown in Column C of this
schedule. The cost of purchases from Edison are projected
to increase from $65.7 million per year to $73.0 million per
year assuming the Step 1 rates are to remain in effect for
the entire year. Under the Step 1 rates, the cost of
purchases from Edison of $73.0 million will thus amount to
approximately 95 percent of Vernon's total revenue
requirements of $77 million.
The projected costs of power and energy (purchases from
Edison) under the Step 1 rates are set forth on Line 1,
Column C of Exhibit B, Sheet 1. This projection is based
upon the assumptions: (l) that purchases from Edison during
the year ending December 31, 1984 will be the same as
Vernon's total energy requirements during the year ended
October 31, 1983; (2) that Vernon's billing demand units
will be the same as the billing demand units with Edison
during the year ended October 31, 1983; and, (3) the Step 1
rates will be in effect throughout the projected year. The
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12/4/83
calculation of the cost of purchases from Edison under these
assumptions is set forth on Sheet 3 of Exhibit B.
The computations of the cost of purchases from Edison
under existing rates, under Step 1 rates and under Step 2
rates are set forth in Sheets 2, 3, and 4, respectively of
Exhibit B. The purchases from Edison are set equal to
Vernon's actual energy requirements during the year ending
October 31, 1983.
Exhibit B, Sheet 1, Line 2, Column C shows the
projected cost of contractual services including consulting
engineering, special accounting, engineering, an? legal
counsel of $585,330. Line 3 shows miscellaneous costs of
$152,003 for services of City personnel and supplies and
expenses. Line 4 shows the projected cost of $2,161,030
payable to Edison for operating Vernon's system pursuant to
its Operating Agreement. Line 5 shows a projection of
depreciation of City's electrical facilities of $403,030.
Line 6 shows an allowance for return on net investment in
electric plant of $753,330. This allowance for return was
computed by applying a rate of return of 12.65 percent,
based upon Edison's cost of capital as determined by the
CPUC, to Vernon's gross plant less accumulated depreciation.
Edison's cost of capital was used because Vernon's
experience with financing is too limited to use as a measure
of the cost of capital. A more appropriate measure of the
cost of capital is the requirements of a private utility
that makes frequent transactions in the bond and stock
markets. Edison is, in this instance, an appropriate model
upon which to base Vernon's cost of capital. The retur~
component was thus computed at a rate of 12.65 percent which
is the rate of return allowed for 1984 by the California
Public Utilities Commission in Edison's retail case by
Decision No. 82-12-055 issued December 33, 1980 in Edison's
Application No. 61138.
As shown on Line 7 of this Exhibit the annual revenue
requirements of the City of Vernon from its electrical
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system are approximately $77.~ million under Edison's Step 1
rates.
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/1
IV. ALLOCATION OF REVENUE REQUIREMENTS
Exhibit 0, Sheet 1 shows an allocation of the demand
and energy components of the system's revenue requirements
among the-various classes of service. This allocation of
system revenue requirements among the various customer
classes was made in the following manner. The total revenue
requirements of $77,931,909 as set forth on Exhibit B, Sheet
I were classified as demand or energy and further broken
down as costs associated with service during Edison's on
peak, mid peak and off peak time of use periods. As shown
on Sheet 2 of Exhibit 0, the energy cost of purchases from
Edison were classified to the energy component. All other
costs were classified to the demand component.
Mi~cellaneous revenues ($25,999), demand costs associated
with service to the Special Contract Customers and revenues
from service to LS-I, LS-2, and OL-l customers were then
deducted from the classified cost of service. Revenues from
the lighting class of customers were deducted from the cost
of service, rather than allocating costs to such customers
because, as explained in the Rate Design Section, we have
determined that it is appropriate to base the rates for
these Schedules upon Edison's retail rates rather than upon
allocated costs. The remaining classified costs were then
allocated as set forth on Sheet 1 of Exhibit O. The cost of
energy purchased from Edison as shown in Column C was
allocated between classes of service on the basis of kWh
sales to each class, respectively, as adjusted for losses.
The development of the allocation factors including the
adjustment for losses is shown on Sheet 3 of Exhibit C. For
purposes of this adjustment, it was assumed that some of the
customers purcha~e from secondary lines, some purchase from
primary lines, some purchase from distribution lines and
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II
some purchase from transmission lines. Inasmuch as there
are losses at each step along the way, the percent loss
responsibility varies depending upon the voltage level of
service. Therefore, Sheet 3 of Exhibit C shows an extimate
of the total kWh responsibilityof each class of service
assuming losses to a common point, the transmission system.
(r"~
The other costs, including demand costs associated with
purchases from Edison, Power Factor Adjustments and Voltage
Discounts, were allocaated on the basis of the billing
demands of the respective classes, again at the transmission
level vol tage. Bill ing demands were used for this' purpose
because this is the best information available for this
purpose. It would be preferable to allocate such costs on
the basis of coincident peak.demands, but such data is not
available. In some instances, billing demands were not
recorded, but were imputed. Billing demands for Schedule
no. D and Schedule Nos. GS-l and TC-l were imputed on the
basis of 25 percent load factor purchases while billing
demands for Schedule No. PA-l were imputed on the basis of
6e percent load factor purchases.
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12/4/83
V. PROPOSED CHANGES IN RATE SCHEDULE STRUCTURE
Edison instituted time of use (TOU) rates for Vernon
and the other resale cities on an optional basis in its
filing in Docket No. ER79-1Se by providing that a demand
charge be applied to peak requirements occuring during the
on peak period. A higher requirement during other ti~es of
the day would not result in higher demand charges. The o~F
peak period occurs during the afternoon hours in the winter
and during the evening hours in the summer. This fil ing in
Docket No. ER79-lSe partially tracked the retail time of use
rates, which was based on 3 time periods. At the retail
level, the peak period was generally the same as that filed
for resale customers in Docket No. ER79-lSe. The off peak
period was generally the late night and early morning hours.
The mid peak period included the hours not covered by the on
peak and off peak periods. Edison stated in its filing that
it was its attempt to make its resale rates similar to its
retail rates, and in its new filing in Docket No. ER84-7S,
proposes to levy a demand charge for the peak requirements
during its mid peak period equal to le percent of its demand
charge for on peak requirements and institute time of use
energy rates as well. Vernon, being an industrial city, has
unique features that make this form of rate exceptionally
valuable to it and its customers. Not only will Vernon's
customers realize savings on the basis of their existing
load patterns, they will also be in a position to effect
further reductions in their cost of power and energy by
rescheduling their operations to further improve their load
patterns.
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12/4/83
The proposed Step 2 rates in Edison's proposed R-3 rate
schedule at the FERC by time of use period are set forth in
the table below:
CUSTOMER CHARGE:
Demand Charge (to be added to Customer Charge):
All kW of on-peak billing demand, per kW
Plus all kW of mid-peak billing demand, per kW
Plus all kW of off-peak billing demand, per kW
Energy Charge (to be added to
Customer and Demand Charges):
All on-peak kWh, per kWh
Plus all mid-peak kWh, per kWh
Plus all off-peak kWh, per kWh
Time periods:
Per Meter
Per Month
$490.00
$15.63
1.56
No Charge
4.795t
4.495t
4.045t
Time Periods are defined as follows:
On-Peak: 1:00 p.m. to 7:00 p.m. summer weekdays except
holidays
5:00 p.m. to 10:00 p.m. winter weekdays except
holidays
Mid-Peak: 9:00 a.m. to 1:00 p.m. and 7:00 p.m. to
11:00 p.m. summer weekdays except holidays
8:00 a.m. to 5:00 p.m. winter weekdays except
holidays
Off~Peak: All other hours.
Holidays are: New Year's Day, Washington's Birthday,
Memorial Day, Independence Day, Labor Day,
Veterans Day, Thanksgiving Day, and Christmas.
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12/4/83
1. Schedule TOU-V
Because of Edison's new rate form, with the additional
time of use rate components, we recommend that Vernon
consider the implementation of a new rate form for the
larger customers that will result in a more precise tracking
of the cost of purchases from Edison on behalf of these
customers. Without such a rate form it will not be possible
to design rates that will recover the cost of purchases from
Edison with reasonable accuracy in the event of changes in
the load patterns of the customers because the rates will
necessarily be designed on the basis of an expected mix of
on peak, off peak and mid peak energy, and an expected
relationship between on peak ~nd mid demands. The time of
use rate will also encourage customers to implement load
management techniques to reduce their bills. The existing
rate structure would result in an over or under collection
if load patterns vary from the expected. A time of use
schedule would adjust revenues to reflect this change in
load patterns to meet the cost of purchases from Edison,
however. We are therefore proposing the elimination of rate
schedules now available to the larger customers. These rate
schedules to be eliminated include the special contracts for
Steel Casting and Byron Jackson as well as Rate Schedule
A-8, now mandatory for customers other than the special
contract customers having peak requirements in excess of
1,000 kW, and the substitution of a time of use rate
schedule, TOU-V, for customers having magnetic tape
recording type meters. Approximately 55 customers have such
meters now. These customers include all of the customers
purchasing under Schedule No. A-8, and some of the customers
currently purchasing under Schedule No. A-7. Magnetic tape
recording devices are scheduled to be installed for all
remaining customers purchasing under Schedule No. A-7 in the
near future.
To fully implement this proposal an additional rule
should be included in Vernon's tariff to provide (1) that a
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12/4/83
recording type meter be installed for all customers having
peak requirements in excess of Se0 kW, and (2) that all
customers having recording type meters be required to
receive service under Schedule No. TOU-V. Such a proposed
condition is included in Exhibit E, Page 1.
2. Payment In-Lieu of Taxes and Franchise Fees
Edison has traditionally made franchise fee payments
and various tax payments to the cities in which they render
service at retail, and has included these payments in their
retail rates. In similiar fashion, Vernon has traditionally
made payments from its electric utility operations to its
general fund as a recovery of taxes or in-lieu franchise
fee. This payment has averaged about 3 percent of the total
revenues from electric service and has been built into the
base rates. We propose, however, that rather than build the
tax and in-lieu payment into the rates, an increment be
added to revenues otherwise payable under the rates filed to
provide for the tax and in-lieu franchise fee. A paragraph
has been added to each of the rate schedules to provide that
the total charges computed under the rates and charges of a
rate schedule are to be increased by three (3) percent to
reflect payments in lieu of taxes and franchise fees. This
provlslon is shown in Exhibit E, Sheet 2. These funds when
collected are transferred to the General Fund account to
help defray the cost of general city operations.
3. Excess Transformer Capacity
Rate Schedule Nos. A-8, A-7, and GS-2 now contain
provisions requiring a customer to reimburse Vernon for
transformer capacity in excess of a customer's contract
demand which is either required by the company because of
the nature of the customer's load or requested by the
customer. At the recommendations of Energy Services, Inc.,
we have included such a condition in Rate Schedule GS-l
also. This provision is shown in Exhibit E, Sheet 3.
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12/6/83
4. Determination of GS-2 Billing Demand
Special condition No.2 of Rate Schedule No. GS-2 now
provides that the billing demand shall be determined to the
nearest l/le kW. Vernon's Rate Schedule Nos. A-8 and A-7
provide that the billing demand is to be determined to the
nearest kW. We have thus changed the provision of Rate
Schedule GS-2 to determine billing demands to the nearest
kW, consistent with the other rate schedules. This
provision is shown iQ Exhibit E, Sheet 4.
5. Rules for Schedule No. PA-2.
The City of Vernon has adopted Special Conditions for
Schedule Nos. A-8, A-7 and GS-2 dealing with Excess
Transformer Capacity, Contract Demand and Minimum Demand
Charges. We now recommend that these Special Conditions be
adopted for Schedule No. PA-2 as well. These provisions are
shown on Exhibit E, Sheet 5.
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12/6/83
VI. EDISON RATES
The regulatory methodology of the FERC, which
establishes the rates under which Vernon purchases from
Edison, differs markedly from the regulatory methodology of
theCPUC, which establishes the rates which Edison's retail
customers purchase under. The FERC, for instance, will
allow rate increases to become effective without serious
examination soon after they are filed but will subsequently
require the refunding of the portion of the proposed
increase that is subsequently found to be excessive. The
CPUC, however, must investigate the rates prior to their
effectiveness. If a comparison were made of Edison'S retail
rates with Vernon's rates, one must take into consideration
that Vernon may receive refunds that can be used to reduce
future costs of service. Other major differences exist with
respect to the form of Edison's wholesale and retail rates,
both of which are now undergoing major changes in form.
These problems are discussed below.
1. Edison's Existing Retail Rates -
The rates at which Edison bills its retail customers
are composites of several components. The first is the base
rate under which Edison recovers its projected fixed costs.
These base rates are established in general rate cases which
Edison may file only once every two years. Edison recovers
its projected fixed costs associated with return on
investment, depreciation, income taxes, other taxes, and
operating expenses under its base rates. Next is the Energy
Cost Adjustment Clause (ECAC) under which Edison may file
three times a year; January 1, May 1, and september 1.
Edison recovers 98 percent of its cost of energy under the
ECAC. The other 2 percent of the cost of energy, along with
miscellaneous costs associated mostly with fuel oil
inventory, is recovered under the annual energy rate (AER).
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12/4/83
Edison also has a Major Additions Adjustment Billing Factor
(MAABF) under which it recovers the cost of major additions
prior to their inclusion in the base rates, an Electric
Revenue Adjustment Billing Factor (ERAMF) to adjust revenues
for sales fluctuations, the Steel Surcharge Adjustment
Billing Factor (SSABF) and the Annual Major Additions Rate
(AMAR). The other component presently included in Edison's
rates is the Conservation Load Management Adjustment Clause
(CLMAC) .
Edison included the MAABF to recover the costs of
SONGS 2 that cannot be projected with reasonable accuracy;
and, (b) an Annual Major Additions Rate (AMAR) designed to
recover the SONGS 2 costs that can be projected with
reasonable accuracy. These various components of Edison's
rates are discussed more fully below, with reference to
Exhibit F.
Sheet 1 of Exhibit F shows the composite Edison retail
rates for Schedule Nos. TOU-8, GS-2, GS-1, PA-l, and PA-2
that are to be effective in November 1983. Column A shows
the rate schedules and the functional components of the
rates (demand, energy, and customer components). Columns
B - J show the levels of the various increments of the
functional components of the rates.
Column B shows the base rates that became effective on
January 1, 1983 pursuant to the CPUC Decision No. 82-12-055
issued December 13, 1982 in Edison's Application No.
61138. Edison will be allowed additional increases to be
effective on or after January 1, 1984 to offset the affects
of attrition and to more fully reflect SONGS 2 costs.
The rate levels set forth in Column B are designed to
recover Edison's fixed costs associated with generation,
transmission, and distribution. These costs include return
on investment, depreciation, in<;:ome taxes, other taxes, and
operation and maintenance (O&M) expenses.
The levels of the functional components of Schedule
TOU-8 are shown on Lines 1 - 8. Edison has established a
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12/4/83
base rate demand charge of $5.05 per kW per month for the kW
of demand purchased under this schedule during the on-peak
period. In addition, Edison has established a base rate
demand charge for the mid-peak period of $.65. The customer
charge of $560 per month has been established on the basis
that customers taking as little as 500 kW per month must
purchase under Schedule No. TOU-8. Edison has established
an energy charge of 2.l45t/kWh for the on-peak periods.
the mid-peak period, and the off-peak periods. Edison has
proposed thus a uniform level for the base rate energy
component in its Schedule No. TOU-8 but has provided,
instead, that the ECABF reflect differences in costs between
the on-peak, mid-peak, and off-peak energy.
Column C shows the Energy Cost Adjustment Billing
Factor (ECABF) to be added to the base energy rate of all
rate schedules.
Column D shows the Annual Energy Rate (AER) of
.390t/kWh. The Annual Energy Rate is designed so as to
recover 2 percent of the annual energy costs plus
miscellaneous costs, mostly associated with fuel oil
inventory.
Column F shows the Conservation Load Management
Adjustment Clause (CLMAC) of .027t/kWh to be added to the
energy component of the rates for each rate schedule.
Column F shows the composite rates in effect as of May 4,
1982 for each of these Edison rate schedules.
Edison thus filed a proposal in Application No.
82-02-40 to establish a Major Additions Adjustments Clause
(MAAC) to implement a Major Additions Adjustment Billing
Factor (MAABF) and an Annual Major Additions Rate (AMAR) to
recover the costs of owning, operating, and maintaining
SONGS 2. The surcharges resulting in this filing are set
forth in Columns G and H. Column G shows the surcharge
associated with the MAABF to be .0311t/kWh. The MAABF is to
be based upon an estimate of SONGS 2 costs which cannot be
reasonably estimated. Any variation between the estimated
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12/6/83
level of these expenses and the recorded expenses will be
placed in the MAAC balancing account and adjusted
periodically to reflect any over-collection or
under-collection. The AMAR is designed to recover costs of
SONGS 2 that are fixed or can be reasonably estimated. The
initial AMAR is to be .07lt/kWh. Column I shows the PUC
reimbursement fee and Column J shows the composite rates to
reflect the base rates, the ECAC and the various surcharges
including the surcharges to recover the cost of SONGS 2. It
is expected that these rates will remain in effect until
January 1, 1984 at which time the rates will be adjusted to
reflect attrition and additional SONGS 2 costs.No. 61138.
The MAABF and the AMAR, shown in Columns G and H,
respectively, will remain in effect until December 31, 1985
because Application No. 61138 did not reflect the costs
associated with SONGS 2. Edison has filed -Notice of Intent-
to file a rate increase application with the CPUC at that
time and roll SONGS 2 costs into the base rate as well.
-20-
12/6/83
VII. THE DESIGN OF RATES
1. To Reflect Edison's Step 1 Increase in Rates -
Exhibit G, Sheet 1 shows the revenues at existing
rates, the proposed revenue increase and the resulting
revenues at the proposed rates. The proposed revenue
increase is shown in Column E. With minor exceptions, the
proposed rates are designed to recover the allocated costs
to each customer class, as set forth in Exhibit D, Sheet 1.
Two exceptions are with respect to Schedule No. D and the
lighting schedules. The customer charge in Schedule No. D
(Domestic) of $1.50 per month has been retained and the
energy charge has been increased from' 4.399 to 4.50t per
kWh. The revenues under these rates are less than allocated
costs. Likewise, the lighting rates, Schedule ~os. OL-l,
LS-l, and LS-2, have not been changed from the existing
rates, on the basis of a study comparing the existing rates
with the rates that Edison charges for similiar service.
Edison's rates are based upon studies of the unique
character of the service rendered by these types of
schedules, and thus probably result in a better measure of
the cost to serve under these schedules-than an allocation
of costs. The rates for Schedules OL-l, LS-l and LS-2
designed to track the Edison rates, using Vernon's energy
costs, are very close to the existing rates for these
schedules. We therefore recommended no changes in Rate
Schedule Nos. OL-l, LS-l and LS-2.
Sheet 2 of Exhibit G shows the design of rates for
Schedule Nos. A-7, GS-2, GS-l, PA-l, and PA-2. As noted
above, these rates have been designed to recover the costs
allocated to these classes of service on Sheet.l, Schedule
D. Rates for Schedule TOU-V were likewise designed to
recover the costs al)ocated to such service. As of this
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,
12/6/83
time, there are 30 customers for whom we have data from a
recording metering device for the full year ending October
31, 1983. Annual sales to this group of customers
represents 63.4 percent of the total sales to customers
purchasing under Schedule Nos. A-8 and A-7. While we would
prefer to have data for a complete year for all of the
customers that will soon be purchasing under Schedule TOU-V,
and this includes all of the customers under Schedule Nos.
A-8 and A-7, we feel that under these circumstances it is
necessary to design TOU-V rates on the basis of costs
allocated to these 30 customers. The mid-peak demand charge
under Schedule TOU-V was set equal to Edison's midpeak
demand charges. While there will be losses associated with
deliveries to Schedule No. TOU-V customers, these losses
will be more than offset by diversity among the TOU-V
customers. That is, the sum of the customers peaks during
the mid peak period will be less than Vernon's mid peak
maximum requirements because not all of the customers will
peak at the same time. The mid peak and off peak energy
charges under Schedule No. TOU-V were set equal to Edison's
mid peak and off peak energy charges, respectively, to
reflect losses.
The rates for Standby Service under Schedule No. Shave
been designed to recover Vernon's cost of rendering this
service. The rate for the first 20 kW has been increased
from $4.00 per kW to $4.50 per kW to contribute more toward
the customer costs associated with this service. The rate
for all excess standby demand has been set at $2.30 per kW,
which represents Vernon's unit fixed costs, as set-forth on
Sheet 2 of Schedule C. The rates for demands actually used
has been set at Vernon's incremental costs of $14.64 per kW
under Edison's Step 1 rates. The energy used is to be
billed at the energy rates under the applicable rate
schedule.
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12/6/83
2. To Reflect Edison's Step 2 Increase in Rates -
As pointed out above, Edison's Step 2 rate increase to
Vernon will also result in an increase in Vernon's cost of
purchases from Edison. To enable Vernon to reflect this
increase in its rates, we have designed surcharges to become
effective on the date the Step 2 rates become effective.
The surcharge to reflect the additional cost of
Edison's Step 2 increase is set forth on Sheet 3 of Exhibit
G. The demand surcharge of .777 per kW of on-peak demand
for Schedule Nos. TOU-V, A-7, and GS-2 was calculated by
dividing Vernon's increase in demand costs of $2,374,159 by
the sum of the 12 monthly system demands. The unit
surcharge for the mid-peak demands is calculated as 10
percent of the on-peak demand charge, or $.078. The energy
surcharge for these customers is the increase in Step 2
energy rates (.024t/kWh) adjusted to .025 to reflect the
losses.
The .384t/kWh unit surcharge applicable to the energy
purchased by customers in other classes, most of whom do not
have billing demands, was arrived at by subtracting the
annual demand surcharges to the Schedule Nos. TOU-V, A-7,
and GS-2 customers from the Step 2 increase in demand cost
and dividing by system annual kWh sales to such customers,
and adding the energy surcharge of .025t/kWh. This
calculation is shown on Sheet 3 of Exhibit G.
3. Transportation for Cogeneration
We recognize that Vernon may be asked to perform a
transportation service for cogeneration customers, and while
it is not appropriate to recommend a rate for this service
now, we do recommend a procedure that may be followed, which
is set forth on Sheet 2 of Exhibit C. This schedule shows
the development of a unit cost for transportation by
dividing the sum of Vernon's fixed costs, including Contract
-23-
.,;I.'-...,'...
~
<;.,~c
12/6/83
Services, Miscellaneous Expenses, Operating Agreement Costs,
Depreciation Return and Payments in lieu of taxes and
franchises, by the sum of Vernon's system demands. We
recommend, however, that the contract services portion be
reduced by the amounts paid for ~urchases, to retain the
amounts expended for cogeneration. We also recommend that
the City consider a reduction in the in lieu payments on an
individual basis. The demands of the transportation for
cogeneration customers are to be added to existing system
demands to arrive at the Adjusted System Demands on line 11.
If, for instance, the demands of the cogenerators amount to
l~~ mW, the total annual demand of 1,2~~ mW would be set
forth on Exhibit C, Sheet 1. This 1,2~~ mW added to system
demands of 2,778 mW results in adjusted system demands of
3,978 mW on line 11 of Exhibit C, Sheet 1. Assuming no
change in the cost of contracted services or in lieu
payments, the monthly demand rate ,for transportation for
cogeneration would be $6,348 divided by 3,978 or $1.6~ per
kW.
-- 23a -
12/6/83
Services, Miscellaneous Expenses, Operating Agreement Costs,
Depreciation Return and Payments in lieu of taxes and
franchises, by the sum of Verno~'s system demands. We
recommend, however, that the contract services portion be
reduced by the amounts paid for purchases, to retain the
amounts expended for cogeneration. We also recommend that
the City consider a reduction in the in lieu payments on an
individual basis. The demands of the transportation for
cogeneration customers are to be added to existing system
demands to arrive at the Adjusted System Demands on line 11.
If, for instance, the demands of the cogenerators amount to
100 mW, the total annual demand of 1,200 mW would be set
forth on Exhibit C, Sheet 1. This 1,200 mW added to system
demands of 2,778 mW results in adjusted system demands of
3,978 mW on line 11 of Exhibit C, Sheet 1. Assuming no
change in the cost of contracted services or in lieu
payments, the monthly demand rate for transportation for
cogeneration would be $6,348 divided by 3,978 or $1.60 per
kW.
In develdping this methodology of designing rates for
transportation for cogeneration we were very much concerned
with the need to be consistent in the treatment of sales and
transportation customers. The transportation is to be on a
firm basis and the rate for such transportationshould be
comparable to rates for sales, less the energy increment.
This principle has been followed at the FERC in both gas and
electric cases. In gas cases the Commission routinely
approves rates for transportation services by subtracting
the gas component from comparable sales rates. Similiar
procedures are followed in electric rate cases. When
designed in this manner, the rates for transportation for
cogeneration will recover revenues that will go toward
reducing the sales rates to all customers, including the
rates charges for s~les to the cogeneration customers. The
increased markets resulting from the transportation for
cogeneration will thus not be a burden to other customers on
-24-
the system, under the proposed rate design.
We have also determined that it is appropriate to
develop rates for transportation for cogeneration on a fully
allocated basis, to avoid making a distinction for
cogeneration customers. We have never made a distinction
among services or customers based on the date of institution
of service. Also, Vernon's system was designed and is
operated as an integrated system. We have thus felt that it
is unreasonable to attempt to develop rates for any service
on the basis of a segment of the system.
.4. Comparison of ratemaking at the FERC with the CPUC
There are various differences in the rates as set by
the FERC as compared with the rates as set by the CPUC,
which makes it necessary to carefully study the situations
existing at any point in time when comparing the levels of
Vernon's rates with the levels of Edison's rates. While it
is generally possible to reconcile these diffenences so as
to arrive at meaningful conclusions, care should be taken to
consider all the important differences involved. This
requires a great deal of work, however, and considerable
knowledge of the rate making process. Some of these
differences are as follows:
a. With respect to the energy cost adjustment clauses,
Edison is required to track changes in the cost of
energy on a monthly basis at the FERC while the
CPUC provides for less frequent changes, and
requires that any under or over collections be
retained in a deferred account.
b. There is a fundamental difference between the
methodologies used by the FERC and the CPUC in the
processing of general rate increases. The CPUC
will analyze a rate proposal in detail prior to
allowing it to become effective. The rate that
-25-
does become effective is final and there will be no
refunds. The FERC, on the other hand, will allow
an increased rate to become effective, without much
analysis, but may require substantial refunds
later. Vernon, for instance, has refunded to its
customers approximately $5 million that Edison
refunded to Vernon under the terms of an order in
Docket No. 76-205 with respect to an Edison
wholesale increase in 1976.
c. Other differences exist with respect to the timing
of general rate increases. At the retail level,
one huge rate increase became effective on
January If 1983 and another is to follow on
January 1, 1984. At the wholesale level one rate
increase became effective June 2, 1982 and another
is to become effective on or shortly after
January 7, 1984. Both of these rate increases will
be subject to refund.
d. Edison has filen surcharges to its retail rates to
reflect the cost of SONGS 2. The surcharges (MAABF
and AMAR) became effective on in-service Date of
SONGS 2 to reflect this unit. Surcharges for the
other units will follow. With respect to the
wholesale rates, however, the cost of major new
facilities may be incluned in the rates only during
major rate incrense filings.
-26-
12/6/83
IX. THE ENERGY COST ADJUSTMENT BILLING FACTOR
/'
;",.
Vernon's existing rates include a component of
5.185t/kWh to recover the cost of Energy purchased from
Edison. These rates also contain an Energy Cost Adjustment
Clause under which Vernon tracks increase and decrease in
the energy component of the cost of its purchases from
Edison by applying an Energy Clause Adjustment Billing
Factor (ECABF) to its kWh sales of energy. Vernon presently
makes changes in its ECABF on a quarterly basis to reflect
the estimated cost of energy for the current period,
adjusted to reflect any over.or under collections during the
prior period. This method is working very well and there
appears to be no reason to make substantive changes in such
methodology. All that is necessary is to set forth the
Energy Cost per kWh that is included in Base Rates. As
shown in Exhibit H, the cost of the energy component of
purchases from Edison amounts to 4.363t/kWh. The existing
base cost of energy from which the ECABF is computed is
5.l85t/kWh, resulting in a decrease of .822t/kWh in the base
cost. The change in the base energy rate does not really
change the cost of energy to the customer, of course. It
merely means that more of the cost of energy is to be
collected in the base energy rate and less is to be
collected in the ECABF.
Vernon has made arrangements to purchase interruptible
energy from Nevada Power Company, which may result in
substantial savings in the cost of energy purchases. Any
such savings realized will be flowed-through to the
customers in the ECABF.
-27-
12/6/83
IX. PURPA STANDARDS
While Vernon is not subject to the Public Utility
Regulatory policies Act of 1978 (PURPA), this report
nevertheless addresses the various concerns of this
legislation. Sections III and Il3 of PURPA provide for the
following standards:
1. Cost of Service
2. Declining Block Rates
3. Time-of-Day Rates
4. Seasonal Rates
5. Interruptible Rates
6. Load Management Techniques
7. Master Metering
8. Automatic Adjustment Clauses
9. Information to Consumers
10. Procedures for Termination of Electric Service
11. Advertising
This report has examined all of these standards to
determine what if any action Vernon should take so as to
meet its public service obligations. In some cases we
determined that no action was required because of the nature
of the service area. In the remaining instances we have
concluded that steps taken by Vernon fully meet the
objectives and standards of the legislation.
1. Cost of Service
The Cost of Service Standard provides that the cost of
providing electric service to each class of electric
consumers shall to the maximum extent practicable -
-28-
12/6/83
1. Permit identification of differences in
cost-incurrence for each such class of electric
consumers, attributable to daily and seasonal time
of use of service; and
2. Permit identification of differences in
cost-incurrence attributable to differences in
customer, demand, and energy components of cost.
In prescribing such methods, such State regulatory
authority or nonregulated electric utility shall
take into account the extent to which total costs
to an electric utility are likely to change if--
a. Additional capacity is added to meet peak
demand relative to base demand; and
b. Additional kilowatt-hours of electric
energy are delivered to electric
consumers.
As discussed above, a cost allocation was made to
develop a cost of service for each customer class, using the
best information and techniques available. The rates
proposed herein are based upon the results of this
allocation.
The schedules under which service is rendered to the
larger customers do reflect time of use considerations.
Schedule Nos. A-8 and A-7 provide for an adjustment for
off-peak demand and special contracts have been negotiated
with some customers having the flexibility of operation that
make load management techniques workable.
2. Declining Block Rates
The PURPA Declining Block Rates Standard provides that:
-29-
12/6/83
UThe energy component of a rate, or the amount
attributable to the energy component of a rate, charged
by any electric utility for providing electric service
during any period to any class of electric consumers
may not decrease as kilo-watt-hour consumption by such
class increases during such period except to the extent
that such utility demonstrates that the costs to such
utility of providing electric service to such class
which costs are attributable to such energy component
decrease as such consumption increases during such
period."
The rates proposed in this report do not contain
declining blocks in the energy component.
3. Time-of-Day Rates
The Time-of-Day Rates Standard provides: "The rates
charged by an electric utility for providing electric
service to each class of electric consumers shall be on a
time-of-day basis which reflects the costs of providing
electric service to such class of electric consumers at
different times of the day unless such rates are not
cost-effective with respect to such class, as determined
under Section l15(b)".
As pointed out above, Vernon is extending Time-of-Day
Rates to all customers having demands of 500kW per day or
more. As pointed out in more detail at a later point,
Vernon's sales to smaller customers amount to a relatively
small amount, making it not cost effective to institute
time-of-date rates for these customers.
4. Seasonal Rates
The Seasonal R~tes Standard provides: "The rates
-30-
12/6/83
charged by an electric utility for providing electric
service to each class of electric consumers shall be on a
seasonal basis which reflects the costs of providing service
to such class of consumers at different seasons of the year
to the extent that such costs vary seasonally for such
utility."
This report concludes that because of the relatively
small difference between the winter and summer monthly peaks
and the relatively small difference between costs during the
winter and summer periods, that there is little reason to
differentiate costs by season. This is particularly true
because of the rate structure of Vernon's sole supplier,
Edison. Vernon's billing demands upon which demand charges
payable to Edison are based, are set at the level of
Vernon's highest takes during the on-peak and mid-peak
periods of the day, each month. There is no ratchet in
these billing demands. Thus, there is no basis for a
seasonal demand charge.
5. Interruptible Rates
The Interruptible Rates Standard provides that: "Each
.
electric utility shall offer each industrial and commercial
electric consumer an interruptible rate which reflects the
cost of providing interruptible service to the class of
which such consumer is a member."
The cost savings resulting from interruptible service
has been examined and discussed with potential customers
from time to time in the past, and there is customer
interest in this concept. However, because Vernon purchases
its power and energy from Edison, this concept is feasible
only if Edison makes energy available to Vernon on an
interruptible basis. Vernon has proposed in its testimony
in Edison's FERC ra~e proceeding, Docket Nos. ER81-177 and
-31-
12/6/83
ER82-427, that Edison be required to institute an
interruptible rate for its wholesale customers. If this
effort is successful, Vernon will make such rate available
to its customers where feasible.
6. Load Management Techniques
The Load Management Technique Standard provides that:
Each electric utility shall offer to its electric consumers
such load management techniques as the State regulatory
authority has determined will--
1. be practicable and cost-effective,
2. be reliable, and
3. provide to the electric utility some enhancement in
its ability to manage energy or capacity.
It also provides that: a load management technique
shall be determined, by the State regulatory authority to be
cost-effective if--
a. such technique is likely to reduce maximum kilowatt
demand on the electric utility, and
b. the long-run cost-savings to the utility of such
reductions are likely to exceed the long-run costs
to the utility associated with implementation of
such technique.
As discussed above, Vernon has investigated Time-of-Day
Rates, Interruptible Rates and Special Contracts as a way to
control maximum demands.
These methods are considered to be the most effective
means available of achieving meaningful load management,
because of the nature of Vernon's loads. Vernon, being an
industrial City, has a relatively small number of customers,
-32-
12/6/83
most of which, however, are relatively large. Consequently,
it is feasible to deal with load management on an
individualized basis in areas where there is a potential for
load management. Because of the relative small number of
customers, however, and the limited amount of sales to
smaller customers, it is not economically nor adminis-
tratively feasible to experiment with such techniques as
time-of- use rates for water heating as load management
techniques.
7. Master Metering
The master Metering Standard provides that to the
extent determined appropriate, master metering of electric
service in the case of new buildings shall be prohibited or
restricted. Separate metering shall be determined
appropriate for any new building if--
1. There is more than one unit in such building.
2. The occupant of each such unit has control over a
portion of the electric energy used in such unit,
and
3. With respect to such portion of electric energy
used in such unit, the long-run benefits to the
electric consumers in such building exceed the
costs of purchasing and installing separate meters
in such building.
Because of the nature of Vernon's service area it is
unlikely that this provision will apply in the
foreseeable future, and Vernon has therefore not
adopted a policy in regard to buildings where Master
Metering mmight be an option.
8. Automatic Adjustment Clauses
The provisions of the Automatixc Adjustment Clause
-33-
I
~
l2/6/83
Standard provides that an automatic adjustment clause
meets the requirements of the standard if --
l. The clause is reviewed at least every four years
by the State regulatory authority at an evidentiary
hearing to insure the clause provides incentives
for efficient use of resources by the utility, and
2. The clause is reviewed at least every two years
by the State regulatory authority at an evidentiary
hearing to insure the maximum economics in those
operations and purchases that affect the rates of
the utility. This review shall include an
examination of the practices of the utility which
relate to the costs included in the clause. In
appropriate cases, an audit of such costs may be
required.
Vernon's rates contain an automatic adjustment clause
which adjusts customer's bills up or down to reflect the
actual costs of fuel and purchased energy. Vernon is not
subject to the jurisdiction of a State regulatory authority
and, consequently, its clause has not received such state
regulatory approval. Vernon's automatic adjustment clause
is, however, similar to clauses of investor-owned systems
that have been approved by state and federal regulatory
agencies. Vernon's automatic adjustment clause is thus
consistent with the intent of the legislation.
9. Information to Consumers
The Information to Consumers Standard provides that
each electric utility shall transmit to each of its electric
consumers certain information regarding rate schedules.
Vernon's program of providing information to its customers
includes all of the necessary rate schedule information.
-34-
12/6/83
10. Procedures for Termination of Electric Service
This Standard provides that no electric utility may
terminate electric service to any electric consumer except
pursuant to procedures prescribed by the State regulatory
authority. Vernon has adopted procedures similiar to those
utilized by privately owned systems, including Edison, that
have been approved by state regulatory agencies.
11. Advertising
The Advertising Standard provides that no electric
utility may recover from any person other than the
shareholders (or other owners) of such utility any direct or
indirect expenditures by such utility for promotional or
political advertising. Vernon does not advertise its
electric service.
X CONCLUSION
In our opinion, the rates proposed herein will allow
Vernon to recover its cost-of-service from its customers in
a fair and equitable manner and complies with the intent of
PURPA.
-35-
City of Vernon
Comparison of Purchase Costs With Revenues
Twelve Months Ending September 30~ 198::::
(OOO's)
E:-:hi bi t A
Sheet 1 of 1
Total
Re.'y'enues
Including
ECAC Rev.
Cost of
Purchases
From Edison Remainder
Including for Non-Purchase
* ECAC Charges Costs
------------------------ ---------
A B
C
D
1 October 1982 $5,827,858 $5~225,326 $602,532
2 November 5, 35(J!I 186 5!,395, 153 (44,967)
..,. December 5,387,574 3,902,485 1,485,089
.~.
4 January 198::; 5,080,596 4,763,835 :;:;16,761
0::- February 4, 78:-., 799 3,846~206 937,593
.J
6 March 4,617,623 5,574,774 (957,151)
7 Apl- i I 4,957, 185 ~ 100,036 1,857, 149
"-',
8 1'1e<.Y 4,619,222 4,242,310 376,912
9 June 4,574,704 4,358, 121 216,583
10 July 4,994,522 4,420,068 574,454
1 1 August a=- 123,904 5,549,588 (425,684)
.J.
12 SE?ptember- 5,67'0,714 5.890,395 (219,681)
13 Total $60,987~885 $56,268,297 $4,719,588
1,15::::,508
(1,101~748)
(1,15::.,508)
1,985,265
$4,449,597
14
15
16
17
Increase In ECAC Reserve
Off System Purchases
Refund Flow Through
Net
(1.101,748>
1,985~265
$61,871,402 $57,421,805
Sources
Column B : Computer print out showing Billing
Data by Rate schedule.
Column C : Edison Bills to Vernon.
Line 14 & 15 : W/P A-l
Line 16 :
W/P A-2 - Deductions made to customers bills to
reflect flow through.
* On a billing month basis which, for some
customers is not a calander month.
E:>:hi bi t B
City of Vernon Sheet 1 of 4
Comparison of Revenue Requirements
Actual Yearv.s. Estimated Under Edison's Step 1 Rates
(thousands)
Actual
E:-:penses
as Adjusted
Estimated
E;.:penses
w/Step 1 Rates
A
B
C
-----------------------..--
399
$72~983
585
152
2,161
400
750
$77,031
1 Cost of Power & Energy
2 Contracted Service
3 Miscellaneous
4 Operating Agreement
5 Depreciation
6 Return
7 Total Revenue Requirement *
$65~694
636
113
2, ()92
725
$69,659
Sources :
Col B. Line 1 :
Cost of Purchases for year ending October 31,
1983 from Sheet 2, Reflects Step 2 rates
in Docket No ER82-427.
Col B. Lines
'-, C".
.iI... .-. ..J .
City of Vernon Statement of Revenue and
Expenses for year ending October 31, 1983.
Col D~ Line 6
Average Rate base @ 12.65 %
Col C~ Line 1
Power- and energy purchased dur i ng year- ended
October 31~ 1983 ~ priced at Step 1 rates.
Col C~
Lines
""", 1::' .
..::.. "-..;,..'.
City of Vernon proposed budget for
1983-1984. (~J/P B-4)
Col C, Line 6
Average Rate Base @ 12.65 % Rate of Return.
* Does not include payment in lieu of taxes and franchise fee.
~
E}:hi bi t B
Sheet 2 of 4
City of Vernon
Costs of Purchases from Edison
Under EXISTING Rates
tes
Billing
Units
(thousands)
Amount
(thousands)
------------------------ ---------
A B
C
D
list 500 kW x 12 months
2 Ne:-:t 1 ~ 500 klotJ
3 All E::.:cess
4 Tot a I
6
18
1,837
1 , 861
$6,650
12.65
12.00
$80
228
22,044
22,352
5 Voltage Discount
$0.30
($558)
\...' Power- Factor Adj.
7 Vernon City Hall
8 Subtotal
$24
(11)*
21,806
9 Energ.y'
10 FCA
11 Vernon City Hall
12 Subtotal
1,028~621
$0.04963
51 , 050
($7,097)**
(65)*
$43,888
13 Total
$65~694
Sources :
Col B, Line 4
W/F' B-2.
Col B, Line 9: Exhibit B, Sheet 3.
Col C: Step 2 Rates from filing in Docket No. ER82-427.
Col D, Lines 6,7 & 11
\I.J/P B-2.
~ Total City Hall
Demi::\nd IE! 15 i:
EnEon:!":.' l~ 85 %
$76
$11
$65
*~ Based on negative .69c/kWh from Statement BH in
Docket No. ER84-75.
Citv of Vernon
Costs of Purchases from Edison
Under Step 1 Rates
(Schedul e R--3)
E>: h i bit B
Sheet 3 of 4
Billing
Units
(thousands)
step 1
Rates
Amount
<thoLlsands)
-----------.------------- --------- --------- ---------
ABC D
1 Customer Charge 1 $375.00 $4.50
Demand Charge
2 On Peak
3 I'li d Peak
4 Subtotal
1,861
2,042
$14.64
1.46
27,245
2,981
$30,226
5 Voltage Adjustment
1 , 861
$0.55
($1,024)
6 Power Factor Adjustment
$24
7 Vernon City Hall *
8 Total Demand
(11)*
29!1 22()
Energy Charge
9 On Peak
10 I'h d Peak
11 Off Peak
12 Subtotal
13 FCA
14 Vernon City Hall *
15 Subtotal Enet-gy
196,8'=74
322 !,9f)i8
508,729
1,028,621
$0.04771
0.04471
0.04021
9,394
14,441
2(),456
44,291
(463) *-If
(65)*
$43,764
16
Total
$72,983
Sources :
Col. B
W/P B-2, 12 months ending October 31, 1983.
Col. C
Step 1 rates from filing in Docket No. ER84-75
Col. D, Lines 6, 7 & 14: W/P B-2
.. Total City Hall
Demand 1~ 15~~
Energy @ 85 I.
$76
11
65
*-If Based on negative .045c/kWh from Statement BG
in Docket No. ER84-75.
Ci ty 0+ 'v'ernon
Costs of Purchases from Edison
Under step 2 Rates
(SchedL\le R-3)
E;.:hi bi t B
Sheet 4 of 4
Billing
Units
(thousands)
Step 2
Rates
Amount
(thousands)
A
B
C
D
-----------------------.
1 Customer Charge
1
$490.00
$5.88
Demand Charge
2 On Peak
. , Mi d Peak
4 Subtotal
1,861
2,042
$15.63
1.56
29,087
3,186
$32,273
5 Voltage Adjustment
1 , 861
$0.55
($1,024>
6 Power Factor Adjustmen~
$24
*
7 Vernon City Hall
8 Total Demand
<11>*
31,268
**
*
Enet-gy Charge
9 Un Peak
1 (I t'li d Peak
11 0++ Peak
12 Subtotal
1~. FUi
14 Vernon City Hall
15 Subtotal Energy
196,8(:14
1;0.04795
0.04495
0.04045
9,441
14,519
20,578
44,538
(463)**
(65)*
$44,010
322, ~/98
508,729
1,028,621
16
Total
$.75,279
Sources
Col. B
W/P B-2, 12 months ending October 31, 1983.
'5
Col. C
Step 1 rates from filing in Docket No. ER84-75
Col. D, Lines 6, 7 & 13: W/P B-2
* Total City Hall
Demand l~ 15/~
Energy @ 85 /.
$76
11
65
** Based on negative .045c/kWh from statement BG
in Docket No. ER84-75.
City of Vernon
Billing Demands for
Transportation for Cogeneration
E:.:hi bi t C
Sheet 1 of 3
Bi 11 ing
Demand
A
D
1 Customer 1
.-:> customer ...,
.... ....
Customer ..,.
.-' ..:"
4 Total
'.
'-'
Ci t.y, of. Vernon
Development of Fixed Costs for
Transportation for Cogeneration Customers
E;.:hi bi t C
Sheet 2 of 3
AmoLlnt
(OOO's)
Vernon' 5 Fixed Costs
1 Contracted Services
2 I'H scell aneous
~ Operating Agreement
4 Depreciation
5 Return
6 In Lieu Payment
7 Total Costs
$58~j
152
2~161
400
750
2, ~'::.OO
$6~348
Vernon's System Demands
8 Total system Demand
9 Transportdtion for Cogeneration
10 Additional Firm
2~778
11
Adjusted System Demands (Temporary)
2~778
12 Unit Cost per kW
$2.29
Sour-ce,,;
Lines 1--5
Exhibit B~ Sheet 1.
Line 6 :
Payments to General Fund In-Lieu of
Taxes and Franchise Payments
L.i ne S}
Exhibit C, Sheet 1
""CJ
c:
c: ..
o .
c: 41
..... ""CJ
III
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0:>
0-
"'-
III
'"
'"
o
-J
-"'"
.... ....
-- III 0
o CL.....
>- ""CJ
.... c:
....
""CJ
... CI'
-' c:
'" .-
:::J "CI
.-' c:
~u.l
w
>--
cr-
....
...
r:
u.l
ci
:II:
I
:a
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Sheet 3 of 3
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City of Vernon
Allocation of Cost of Service
Vernon's Costs Under Edison's Step 1 Rates
Deaand
Schedules
Total
A
B
1
2
3
4
5
b
7
8
9
10
TOU-Y $12,9b7,043$11,736,928
A-8 3,979,787 3,1102,246
A-7 8,655,444 7,834,348
65-2 6,501,284 6,015,734
65-1 656,340 607,321
D 8,504 7,869
PiH 99,242 91,830
PA-2 99,262 91,848
T[-1 34,005 31,466
Subtotal $33,OOO,910$30,~19,590
11
12
13
14
15
It;
17
18
19
2(;
21
..."
J.L
Peak
"id
Peak
Exhibit D
Sheet 1 of 2
Energy
Total
------- --------------------------------
Peak
"id
Peak
Off
Peak
$23,103,031
4,209,267
9,355,105
5,610,990
453,605
5,871
164,610
80,980
23,502
$43,607,567
E
F
6
H
TOU-Y 1,083,936 1,407,506 548,554,744 95,921,845 158,664,314 293,968,585
A-8 332,677 431,985 97,414,276 17,034,138 28,176,166 52,203,973
A-7 723,522 939,504 216,517,296 37,860,831 62,625,597 116,030,868
65-2 555,5bQ 555,5b9 125,749,790 36,706,175 58,395,398 30,648,224
65-1 56,082 56,088 10,165,892 2,967,408 4,720,813 2,477,670
D ]"I' 127 131,718 38,448 61,167 32,103
..,
PA-l 8,481 8,481 3,689,136 1,076,853 1,713,152 899,130
P{.j-2 8.482 8,482 1,814,866 529,757 842,783 442~326
Tt-l 2,906 2,906 526,703 153,744 244,589 128.370
Subtotal 2,7i2,38B 3,411,248 1,004,564,426 192,289,199 315,443,978 49b,831,249
142,078,110 41,472,385 65,977,902 34,627,823
lS-1 4,845 (1271 0 1,945,867 120) (81 ISO)
lS-2 594 161 () 241.413 m (1) (6)
Ol-I 0 11091 0 1,711.945 UBi (7) 144}
c
D
$4,402,942 $7,255,713 $12,044,376
781,890 1,288,495 2,138,8B3
1,737,863 2,863,866 4,753,975
1,084,863 2,670,419 1,255,70B
136,208 215,883 101,514
1,765 2,797 1,315
49,429 78,342 36,839
24,317 38,540 18,123
7,057 11,185 5,260
$8,826,333 $14,425,241 $20,355,993
Total 2,777,826 2,772,146 3,411,24B 1,00B,463,051 192,289,159 315,443,962496,831,149
Soure es :
line 10: fxhibit D, Sheet 2.
line 11: ~/P D-2
$1,230,115
377,541
821,096
485,549
49,019
635
7,412
7,413
2,540
$2,981,320
Colulns C , E: Exhibit C, Sheet 3 (Note: line 12 is total A-B less TOU-V).
Colutns D,F,G , H lines 12-13: Sale ratio as TOU-V .
Coluens F,G ~ H lines 14-19 : . Ratio based on total systel less lines 11-13.
llnes 20-22 , Colulns B l E: Exhibit [, Sheet 3 of 4 .
lines 20-22 I [olUlns [,D,F,6 t H: Exhibit D, Sheet 2 of 2 .
City of Vernon Exhibit D
Classification of Revenue Requirelents Sheet 2 of 2
Purchases Frol Edison @ Step 1 Rates
Alount
--------- ----------- ---------- --------- ----------- ----------
Total Deland Energy
Particulars Peak "id-Peak Peak "id-Peak Off-Peak
-------------------- -------- -------- -------- -------- -------- --------
A B C D E F 6
1 Purchased Power 572,983 526,239 52,991 58,866 $1-4,441 520,456
2 Contracted Service 595 585
3 IIi sce 11 aneous 152 152
4 Operating Agreelent 2,161 2,IM
5 Depreci at i on 400 400
6 Return 750 750
7 Total Revenue Req 571,031 530,287 52,961 5S,S66 514,441 S20,456
8 lIiscellaneous Rev. 1$25) (5251
9 LS-l Re't'enues (S205) (S127) (520) (S8) (S501
10 L5-2 Revenues tIS) (6) (21 01 (61
11 OL-l Revenues 1118) 11091 USl (]) (44)
12 Total for Allocation 576. bOB 510,020 $2,981 $8,826 $14,425 $20,356
Sources :
Line 1: Exhibit B, Sheet 3.
Line~ 2-]: Exhibit B, Sheet I.
Line B: NIP C-3.
Lines 9-11: NIP C-4
Exhibit E
Sheet 1 of 5
City of Vernon
Special conditions to add to Schedule Nos. A-7 and GS-2
Recording Meters: A recording type meter shall be
installed for all customers purchasing under this schedule
and having peak requirements of 500 kW or more. Customers
having recording type meters are not eligible to purchase
under this schedule and must be transferred to Schedule No.
TOU-V.
Exhibit E
Sheet 2 of 5
City of Vernon
Special Conditions to add to all Rate Schedules
In-Lieu Tax and Franchise Payment: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Exhibit E
Sheet 3 of 5
City of Vernon
Special Conditions to add to Schedule No. GS-l
Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either
required by the Company because of the nature of the
customers's load or requested by the customer. Excess
transformer capacity shall be billed at $1.00 per kVA per
month.
Exhibit E
Sheet 4 of 5
City of Vernon
Special conditions to add to Rate Schedule No. GS-2
Billing Demand: Billing demand shall be the kilowatts of
maximum demand but not less than Sa% of the highest maximum
demand established in the preceding eleven months, however,
in no case shall the billing demands be less than 20 kW.
Billing demand shall be determined to the nearest kW.
Exhibit E
Sheet 5 of 5
city of Vernon
Special Conditions to Add to
Schedule No. PA-2
8. Excess Transformer Capacity: The transformer
capacity in excess of a customer's contract demand
which is either required by the Company because of
the nature of the customer's load or requested by
the customer. Excess transformer capacity shall be
billed at $1.00 per kVA per month.
9. Contract Demand: A contract demand will be
established by the Company, based on applicant'S
demand requirements for any customer newly
requesting service on this schedule and for any
customer of record on this schedule who requests an
increase or decrease in transformer capacity in
accordance with Rule No. l2D. A contract demand
arrangement is available upon request for all
customers of record on this schedule. Contract
demand is based upon the nominal kilovolt-ampere
rating of the Company's serving transformer(s} or
the standard transformer size determined by the
Company as required to serve the customer's stated
measurable kilowatt demand, whichever is less and
is expressed in kilowatts.
l0. Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall
be computed by multiplying the billing demand by
the demand charge per kilowatt. Where a contract
demand is involved, the monthly minimum demand
charge shall be the greater of:
a. The charge as computed by multiplying the
billing demand by the demand charge per
kilowatt; or
b. A facilities charge of $1.00 per kilowatt of
contract demand.
~
Exhibit F
Sheet 1 of 1
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City of Vernon
Revenues @ Existing Rates
Revenues @ the Proposed Rates
and the Resulting Increase
E:.:hi bi t 8
Sheet 1 of 4
Revenues @
Schedule No. Existing Rates
Revenues @
Proposed Rates
Increase
------......-----.-- --------.------
--------------
A B
c
D
1 TDU-.V $34,598,316 $37,804,279 $3,205,963
2 A-7 16,080,720 18,568,233 2,487,513
3 Gc_r) 11,418,981 12,486,906 1,067,926
--' .....
4 85-1 995,384 1,144,275 148,892
5 PA-1 293,922 272,013 <71,9(8)
6 PA--2 169,856 185,816 15,960
7 1C-1 38,870 42,754 3,884
8 D 5,571 5,699 128
9 LS-l 205 205 0
10 LS-2 15 15 0
11 OL--1 178 178 (I
12 Tota.l $63,602,017 $70,510,374 $6,908,357
Sources :
Lines 1-6 Exhibit G, Sheet 2
Lines 7-8 W/P 6-2.
Lines 9-11: Exhibit D, Sheet 2
12-1lay-83
Ci ty of Vernon
Design of Rates
To BeeDle Effective January 1983
Exhi bit 6
Sheet 2 of 4
tAl
Existing Proposed
Billing -------------------- --------------------
Un its Alount Rates A.aunt Rates
--------- ---.---.--- --------- --------.- ---------
IBI IC) lD) IE) IF)
SCHElIULE A-7
1 Deland-1st 200 kN 1,656 $2,568,456 $1,551.00 $2,898,000 51,750.00
2 -Excess 385,159 2,986,522 7.754 3,370,140 8.75000
3 Energy 214,373,560 10,525,742 0.049 f 11,743,0(~ 0.05478
4 Total $16,080,720 $18,011,148
SCHEDULE 69-2
5 Deland-1st 20 kN 10,020 $1,513,020 $151.00 51,803,600 $180.00
6 -Excess 344,275 2,607,541 7.574 3,098,478 '1.00000
7 Energy 123,284,114 7,298,420 0.05'1 7,210,196 0.05848
8 Total $11,418,981 $12,112,274
SCHEDULE 65-1
9 Cusioler Charge 9,816 $48,098 $4.90 $58,896 $6.00
lQ Energy 9,774,896 947,285 0.097 1,051,049 0.10753
11 Tot al $995,384 $1,109,945
SCHEDULE PA-l
12 Horsepower Charge 18,953 $18,953 51. ()Q tl8,953 $1.00
13 Energy 3,652,610 274,968 0.075 244,899 0.06705
14 lotal $293,922 $263,853
SCHEDULE PA-2
15 Deland-1st 75 kN 48 $20,160 5420.00 $25,2(1(1 5525.00
16 -Excess 4,716 26,410 5.600 33,013 7.00000
17 Energy 1,779,280 123,286 0.Ob9 122,02'1 0.06858
18 lotal tlb9,856 $180,241
Sources :
Coluln B: Fro. Exhibit C, Sheet 3.
Coluln E: Exhibit D, Sheet 1.
f Reflects a negative .69c/kNh FCA.
tit Y of Vernon
Design of Rates for Schedule TOU-V
To Becole Effective January 8, 1984
Exhibi t 6
Sheet 3 of 4
tAl
Exi sting Proposed
Oi lling -------------------- --------------------
Units haunt Rates haunt Rates
--------- --------- --------- --------- ---------
ISI It) ID) IE) IF)
Exi sting Fori
1 Deland-1st 10{lO iN
2 -Excess
3 Energy
4 Total
348 $2,495,856
735,936 5,278,133
548,554,144 26,824,327
$34,598,316
$7,172.00
7.1720
0.0489 I
Proposed Fori
5 Custoler Charge 348 $191,400 $550.00
6 Deaand-Peak 1,083,936 $9,758,974 $9.00
7 -ftid Pl!a~ 1,407,506 2,054,959 1.46000
8 Energy-Peak 95,921,845 $4,805,684 $0.05010
9 -fti d Peak 158,664,314 7,447,703 0.04694
, 10 -Off Peak 293,968,585 12,411,354 0.04222
11 Tlltal haunt $36,610,074
Sources :
lines 1-4
ColUln B: line 1 frot lonthly distribution report X 12; line 2
frat Exhibit D, Page 1 less 348,000.
Coluln D: Existing Vernon tariff.
lines 6-11
Coluln B: Exhibit D! Page 1.
Coluln E: Exhibit D, Page 1.
f Reflects a negati ve. 69c/ilfh FCA
City of Vernon
Development of Surcharge for
Step 2 Rate Increase
Demand
Schedule Demands Amount
-------- -------- --------
(A) (B) (C)
1 lOU-V 1~083~936 $895~651
2 A-8 332~677 274~889
A-7 7'")c <='":,., 597~843
- ......_., ..J.....
4 85-2 555,569 459~O64
5 65-1 56~088 46~345
6 D 727 600
7 LS-1 4~845 4~OO3
8 LS-2 594 490
'1 OL-1 0 (I
10 PA-.1 8,481 7,008
1 1 PA--2 8~482 7~OO9
12 TC.-1 2,906 2~401
1.::. Total 2,777,826 $2~295~305
Demand Surcharge
TOU--V, A-8
14 A-7 and 6S-2 2~695,704
2,227~448
15 Net for Energy Surcharge
$67~857
16 kWh for Remaining Sch.
19, 528, ~327
SOUI-ces :
Column
D .
J.:.' .
Exhibit C~ Sheet 3.
E:.:hibit G
Sheet 4 of 4
Peak
Demand
(D)
$0.751
0.751
0.751
0.751
$0.82630
$0.00347
Energy *
(F)
$0.00025
0.00025
0.00025
0.00025
0.00372
0.00372
0.00372
0.00372
0.00372
0.00372
0.00372
0.00372
Column C~ Line 13: Difference Between Exhibit B~
Sheets 3 ~< 4.
Column D
.85468/1.1
Line 14~ Column B: Exhibit C, Sheet ~.
Line 16 :
Exhibit C~ Sheet 3.
* Includes .025 c/kWh for energy component
of Step 2 increase.
City of Vernon
Base Rate for
Energy Cost Adjustment
A
1 Cost of Energy Purchase
..:;. Vernon Sales
~ Base Cost of Energy
4 Existing Base Cost
5 Increase in Base Cost
Sources :
Line 1: Exhibit B, Sheet 3.
Line 2 Exhibit C~ Sheet 3.
E>: h i bit H
Sheet 1 of 4
B
$43,764,000
1,003,155,021
$0.04363
$0.05185
($0.00822)
Exhibit H
Sheet 2 of 4
City of Vernon
Procedures for Calculating the
Energy Clause Adjustment Billing Factor
The rate schedules contained herein are to contain, in
addition to the base rates included in the current tariff,
an Energy Clause Adjustment Billing Factor (ECABF) to
reflect changes in the cost of fuel and purchased energy.
The ECABF is to be calculated pursuant to the following
equation:
ECABF =
EC + C
e
- B
Se
Where,
ECABF = Energy Cost Adjustment Billing Factor per Kilowatt
Hour Sold
EC
e
= Estimated Fuel and Energy Costs for the Current
Period
C
= Correction for Previous period's Over or
Under-recovery*
Se
= Estimated Kilowatt hours to be sold in Curent
Period
B
= Energy Cost per Kilowatt Hour included in Base
Rates = 4.363 centslkWh
* If the previous period average costs were less than 4.363
cents IkWh, C is negative. If such average costs
were greater than 4.363 cents/kWh, C i~ positive.
Exhibit H
Sheet 3 of 4
Energy Clause Adjustment Billing Factor
(Continued)
ECA Computation Sheet
Schedule V-1 is attached to provide the computation sheet
for all periods once implementation is completed.
Estimated Energy Costs (ECel
Items 1 through 3 represent the estimated energy costs which
are to be used iin computing the period's ECA. This is an
estimate of the costs the City expects to incur for the
three month period to which this ECA will apply. It is
comprised only of commodity or energy costs in keeping with
standards only of commodity or energy costs in keeping with
standards established by the Federal Energy Regulatory
Commission and various state regulatory bodies.
To calculate items l(a) and l(b). the City must obtain
estimates from Edison of the kilowatt hours expected to be
sold to the City of Vernon during the period the ECA will be
in effect. Edison must also provide an estimate of the ECA
that they will be charging the City during that period.
Line 2 would be comprised of estimated fuel costs required
to operate the City's generating units. This charge would
be designated on the billing for operating expenses as being
charged to FERC account 547. Fuel. At the outset there will
probably be no cost associated with this line item. However
it will become a factor when the units become operational
once again.
Line 3 represents an estimate of the cost of interruptible
energy to be purchased during the period the ECA will be in
effect.
Correction Factor
Lines ~ through 7 of the computation sheet are used to
calcualte the amount needed to correct for over- or under-
recovery of energy costs in previous periods. Line 4
represents a true-up of the previouS period'S estimate of
energy costs on Lines 1 and 2. These amounts can be taken
from the billings of Edison both for purchased power and for
fuel used by the Vernon generating units for the appropriate
periods being corrected.
Because there is a delay in the availability of expense and
revenue data for individual months. the period for which a
correction factor is calculated will lag behind by one
month.
City of Vernon
Energy Cost Adjustment
Computation.Sheet
For Three Months Ending
Estimated Energy Costs
1. purchased power from SCE
(a) Energy Charge
(b) Energy Cost Adjustment
2. Generation Fuel Costs (Account 547)
3. Costs of Interruptible Purchases
4. Total Energy Costs (1+2+3)
Correction Factor
5. Actual Energy Expenses for
Previous Period $
6. Unrecovered Energy Expenses
from Previous Periods $
7. Less: Billed Base Rate and ECA
Revenues from Previous Period $
8. Unrecovered (Over-recovered)
Energy Expenses (4+5-6)
9. Total Costs to be Recovered (3+7)
Calculation of Factor
10. Estimated Kwhr Sales
11. Total Energy Cost per Kwhr
(8~9)
12. Less: Amount in Base Rates
13. Energy Cost Adjustment Factor
(10-11)
Exhibit H
Sheet 4 of 4
, 19
$
$
$
$
$
$
$
$~4363
$ t
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. GS-l
GENERAL SERVICE
APPLICABILITY
Applicable to single- and three-phase general service
including lighting and power. This schedule is not
applicable when, in the opinion of the Company, the
customer's load and use characteristics indicate that the
maximum demand may exceed 20 kW.
TERRITORY
Within the city limits of the City of Vernon.
RATES Per Meter
Per Month
Customer Charge..............................$ 6.00
Energy Charge (to be added to Customer Charge):
All kWh, per kWh........................... le.753t
Minimum Charge:
The monthly minimum charge shall be the
monthly Customer Charge.
SPECIAL CONDITIONS
l. Voltage: Service will be supplied at one standard voltage.
2. X-Ray Installations: Where the Company installs the
standard transformer capacity requested by a customer to
serve separately an X-ray installation, the customer charge
will be increased by $1.00 per kVA of transformer capacity
requested.
3. Temporary Discontinuance of Service: Where the use of
energy is seasonal or intermittent, no adjustments will be
made for a temporary discontinuance of service. Any
customer prior to resuming service within twelve months
after such service was discontinued will be required to pay
all charges which would have been billed if service had not
been discontinued.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.----
Resolution No.
Effective
Effective
Effective
Effective
4. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this schedule.
5. In-Lieu of Tax and Franchise Payments: the total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
6. Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either
required by the Company because of the nature of the
customer's load or requested by the customer. Excess
transformater capaciaty shall be billed at $l.e0 per KVA
per month.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. GS-2
19
GENERAL SERVICE
APPLICABILITY
Applicable to single and three-phase general service
including lighting and power.
Ie
TERRITORY
Within the city limits of the City of Vernon.
RATES Per Meter
Demand Cha rge: Per Month
First 20 kW or less of billing demand.... $180.00
All excess kW of billing demand, per kW.. $ 5.848
Energy charge (to be added to Demand Charge): 6.027j!!
Minimum Charge:
The monthly minimum charge shall be the monthly Demand
Charge.
SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard voltage.
2. Billing Demand: Billing demand shall be the kilowatts of
maximum demand but not less than 50% of the highest maximum
demand established in the preceding eleven months, however,
in no case shall the billing demand be less than 20 kW.
Billing demand shall be determined to the nearest kW.
3. Maximum Demand: The maximum demand in any month shall be
the measured maximum average kilowatt input, indicated or
recorded by instruments to be supplied by the Company,
during any IS-minute metered interval in the month, but
shall not be less than the diversified resistance welder
load computed in accordance with the section designated
Welder Service in Rule No.2.
4. X-Ray Installations: Where the Company installs the
standard transformer capacity requested by a customer to
serve separately an X-Ray installation, the minimum charge
will be increased by $1.00 per kVA of transformer capacity
requested.
Authorized by City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
5. Temporary Discontinuance Service: Where the use of energy
is seasonal or intermittent, no adjustments will be made
for a temporary discontinuance of service. Any customer
prior to resuming service within twelve months after such
service was discontinued will be required to pay all
charges which would have been billed if service had not
been discontinued.
6. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this schedule.
7. Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either
required by the Company because of the nature of the
customer's load or requested by the customer. Excess
transformer capacity shall be billed at $1.00 per kVA per
month.
8. Contract Demand: A contract demand will be established by
the Company, based on applicant's demand requirements for
any customer newly requesting service on this schedule and
for any customer of record on this schedule who requests an
increase or decrease in transformer capacity in accordance
with Rule No. 120. A contract demand arrangement is
available upon request for all customers of record on this
schedule. Contract demand is based upon the nominal
kilovolt-ampere rating of the Company's serving
transformer(s) or the standard transformer size determined
by the Company as required to serve the customer's stated
measurable kilowatt demand, whichever is less and is
expressed in kilowatts.
9. Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall be
computed by multiplying the billing demand by the demand
charge per kilowatt. Where a contract demand is involved,
the monthly minimum demand charge shall be the greater of:
a. The charge as computed by multiplying the billing
demand by the demand charge per kilowatt; or
b. A facilities charge of $1.00 per kilowatt of
contract demand.
Authorized By City of Vernon:
Ordinance No.
Ordinance No.
Resolutio1'"\ No.
Resolution No.
Effective
Effective
Effective
Effective
l0. In-Lieu Tax and Franchise Payment: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Authorized By City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. A-7
GENERAL SERVICE
APPLICABILITY
Applicable to single and three-phase general service
including lighting and power.
TERRITORY
Within the city limits of the City of Vernon.
RATES
Per Meter
Demand Charge: Per Month
First 200 kW or less of billing demand.... $1,750.00
All excess kW of billing demand, per kW........$ 8.750
Energy Charge (to be added to Demand Charge):....
5.478t
Minimum Charge:
The monthly minimum charge shall be the monthly Demand
Cha rge .
J':
~.
SPECIAL CONDITIONS
l. Voltage: Service will be supplied at one standard voltage.
2. Billing Demand: The billing demand shall be the kilowatts
of maximum demand but not less than 50% of the highest
maximum demand established in the preceding eleven months,
however, in no case shall the billing demand be less than
200 kW. Billing demand shall be determined to the nearest
kW.
3. Maximum Demand: The maximum demand in any month shall be
the measured maximum average kilowatt input, indicated or
recorded by instruments to be supplied by the Company,
during any 15 minute metered interval in the month, but
shall not be less than the diversified resistance welder
load computed in accordance with the section designated
Welder Service in Rule No.2. Where the demand is
intermittent or subject to violent fluctuations, a 5-minute
interval may be used.
Authorized by City of Vernon:
Ordinance No.
Ordinance No.
Resol ut ion No.
Resolutiol) No.
Effective
Effective
Effective
Effective
- 1 -
4. Voltage Discount: The charges before adjustments will be
reduced by 3% for service delivered and metered at voltages
of from 2 kV to 10 kV; and by 5% for service delivered and
metered at voltages over SO kV; except that when only one
transformation .from a transmission voltage level is
involved, a customer normally entitled to a 3% discount
will be entitl~d to a 4% discount.
5. Power Factor Adjustment: The charges will be adjusted each
month for powe~ factor as follows:
The charges wil!l be decreased by 20 cents per kilowatt of
measured maximum demand and will be increased by 20 cents
per kilovar of reactive demand. However, in no case shall
the kilovars u~ed for the adjustment be less than one-fifth
the number of kilowatts.
The kilovars of reactive demand shall be calculated by
multiplying th~ kilowatts of measured maximum demand by the
ratio of the ktlovar-hours to the kilowatt hours. Demands
in kilowatts a~d kilovars shall be determined to the
nearest unit. 'Aa rachet device will be installed on the
kilovar-hour m~ter to prevent its reverse operation on
leading power ~actors.
6. Temporary Discontinuance of Service: Where the use of
energy is seasonable or intermittent, no adjustment will be
made for a temporary discontinuance of service. Any
customer prior 'to resuming service within twelve months
after such service was discontinued will be required to pay
all charges Wh1Ch would have been billed if service had not
been discontinqed.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resol utiQn No.
Effective
Effective
Effective
Effective
- 2 -
7. Adjustment for Off-Peak Demand: Upon application by the
customer in any month where the maxium demand exceeds
500kW, and kilowatts of maxim,um demand in excess of the on
peak demand will not be considered in establishing the
billing demand for computing the energy charge, but will be
considered in establishing the billing demand for computing
the demand charge, by adding one half of the amount that
the maximyum demand exceeds the on peak demand, to the on
peak demand. The on peak demand will be the maximum demand
occurring between the hours of 6:30 A.M. and 10:30 P.M.,
Pacific Standard Time, of any day except Sundays and the
following holidays: New Years Day, Washington's Birthday,
Memorial Day. Independence Day, Labor Day, Thanksgiving Day
and Christmas.
8. Contracts: An initial three year contract may be required
where applicant requires new or added serving capacity
exceeding 2,000 KVA.
9. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therin will be applied to kWh billed under
this Schedule.
10. Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either
required by the Company because of the nature of the
customer's load or requested by the customer. Excess
transformer capacity shall be billed at $1.00 per kVA per
month. .
ll. Contract Demand: A contract demand will be established by
the Company, based on applicant's demand requirements for
any customer newly requesting service on this schedule and
for any customer of record on this schedule who requests an
increase or decrease in transformer capacity in accordance
with Rule No. 120. A contract demand arrangement is
available upon request for all customers of record on this
schedule. Contract demand is based upon the nominal
kilovolt-ampere rating of the Company's serving
transformer(s) or the standard transformer size determined
by the Company as required to serve the customer's stated
measurable kilowatt demand, whichever is less and is
expressed in kilowatts.
Authorized by the City of Vernon:
Ordinance No. Effective
Ordinance No. Effective
Resolution No:--- Effective
Resolution No. Effective
- 3 -
12. Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall be
computed by multiplying the billing demand by the demand
charge per kilowatt. Where a contract demand is involved,
the monthly minimum demand charge shall be the greater of:
a. The charge as computed by multiplying the billing
demand by the demand charge per kilowatt; or
b. A facilities charge of $1.00 per kilowatt of
contract demand.
13. In-Lieu of Tax and Franchise Payments: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Authorized
by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.-
Resolution No.
Effective
Effective
Effective
Effective
- 4 -
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. TOU-V
GENERAL SERVICE-LARGE
APPLICABILITY
Applicable to general service, including lighting and
power. This schedule is applicable for all customers of
record on April 3, 1980 and thereafter to all customers for
whom magnetic tape recording meters have been installed.
Any customer whose monthly maximum demand has fallen below
500 KW for 12 consecutive months may elect to take service
on any other applicable schedule.
TERRITORY
Within the city limits of the City of Vernon.
Customer Charge:...........
Per Meter
Per Month
$550.00
RATES
Demand Charge(to be added to Customer Charge):
All kW of on peak billing demand, per kW
Plus all kW of mid peak billing demand, per
Plus all off peak billing demand, per kWh
$9.00
kW $1.46
no charge
(Subject to Minimum Demand Charge. See Special Condition No.6)
Energy Charge (to be added to
All on peak kWh, per kWh
Plus all mid peak kWh, per
Plus all off peak kWh, per
Demand Cha rg e)
kWh
kWh
. . . . .
5.010$t
4.694t
4.222t
. . . . . . .
. . . . . . .
Time Periods:
Time Periods are defined as follows:
On peak: 1:00 p.m. to 7:00 p.m.
summer weekdays except holidays
5:00 p.m. to 10:00 p.m.
winter weekdays except holidays
Mid Peak: 9:00 a.m. to l:00 p.m. and
7:00 p.m. to 11:"0 p.m.
summer weekdays except holidays
8:00 a.m. to 5:00 p.m.
winter weekdays except holidays
Off Peak: all other hours
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
- 1 -
Holidays are: New Year's Day, Washington's Birthday,
Memorial Day, Independence Day, Labor Day, Veteran's
Day, Thanksgiving Day and Christmas.
When any holiday listed above falls on Sunday, the
following Monday will be recognized as an off peak period.
No change in off peak will be made for holidays falling on
Saturday.
The summer season time periods shall commence at 12:0l a.m.
May 1 and continue through October 31 of each year and the
winter season time periods shall commence at 12:01 a.m.
November 1 and continue through April 30 of the following
year.
2. Billing Demand: The billing demand shall be the kilowatts
of maximum demand but not less than 50% of the highest
maximum demand established in the preceding 11 months,
however, in no case shall the on peak billing demand be
less than lOOO KW. Billing demand shall be determined to
the nearest KW.
3. Maximum Demand: The maximum demand in any month shall be
measured maximum average kilowatt input indicated or
recorded by instruments to be supplied by the Company,
during any l5-minute metered interval in the month, but not
less than the diversified resistance welder load ~omputed
in accordance with the section designated Welder Service in
Rule No.2. Where the monthly demand exceeds 5000 KW per
month, the maximum demand shall be based on a 30-minute
interval. Where the demand is intermittent or subject to
violent fluctuations, a 5-minute interval may be used.
4. Voltage Discount: The demand charges before adjustment
will be reduced by 3% for service delivered and metered
at voltages of from 2kV to l0kV; by 4% for service
delivered and metered at voltages of from llkV to 50kV; and
by 5% for service delivered and metered at voltages over
50kV; except that when only one transformation from a
transmission voltage level is involved, a customer normally
entitled to a 3% discount will be entitled to a 4%
discount.
5. Power Factor Adjustment: The charges will be adjusted
each month for the power factor as follows:
The charges will be decreased by 20 cents per kilowatt of
measured maximum demand and will be increased by 20 cents
per kilovar of reactive demand. However, in no case shall
the kilovars used for the adjustment be less than one fifth
of the number of kilowatts.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
- 2 -
The kilovars of reactive demand shall be calculated by
multiplying the kilowatts of measured maximum demand by the
ratio of the kilovar-hours to the kilowatt hours. Demands
in kilowatts and kilovars to the kilowatt hours. Demand in
kilowatts and kilovars shall be determined to the nearest
unit. A ratchet device will be installed on the
ki1ovar-hour meter to prevent its reverse operation on
leading power factors.
6. Temporary Discontinuance of Service: Where the use of
energy is seasonal or intermittent, no adjustment will be
made for a temporary discontinuance of service. Any
customer prior to resuming service within twelve months
after such service was discontinued will be required to pay
all charges which would have been billed if the service had
not been discontinued.
7. In-Lieu of Tax and Franchise Payments: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
8. Contracts: An additional initial three year facilities
contract may be required where applicant requires new or
added serving capacity exceeding 2,0~0kVA.
9. Customer's Right to Terminate: In the event the net
bill for electric service to the customer is increased
during the term of the requirements contract, provided for
herein, as a result of changes in this schedule, the
customer shall have the right to terminate the requirements
contract on not less than 30 months notice to the utility.
Such notice shall be given within 180 days after the
effective date of such change.
10. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this schedule.
11. Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either
required by the Company because of the nature of the
customer's load or requested by the customer. Excess
transformer capacity shall be billed at $1.00 per kVA per
month.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
---= 3 -
l2. Contract Demand: A contract demand will be established by
the Company, based upon applicant's demand requirements for
any customer newly requesting service on this schedule and
for any customer of record on this schedule who requests an
increase or decrease in transformer capacity in accordance
with Rule 12D. A contract demand arrangement is available
upon request for all customers of record on this schedule.
Contract demand is based upon the nominal kilovolt-ampere
rating of the Company's serving transformer(s) or the
standard transformer size determined by the Company as
required to serve the customer's stated measurable kilowatt
demand, whichever is less and is expressed in kilowatts.
13. Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall be
computed by multiplying the billing demand by the demand
charge per kilowatt. Where a contract demand is involved,
the monthly minimum demand charge shall be the greater of:
a) The charge as computed by multiplying the billing
demand by the demand charge per kilowatt; or
b) A facilities charge of $1.09 per kilowatt of contract
demand.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
---= 4 -
3. Overloaded Motors: Whenever, upon test, any motor under
normal operating conditions is found to be delivering more
than lIS percent of its capacity as indicated by its
nameplate rating, the Company may disregard the nameplate
rating and base its charges upon the output as calculated
from test. Any motor which is billed on a basis in excess
of its nameplate rating in accordance with this special
condition shall be tested at intervals to be determined by
the Company or upon notification by the customer of a
permanent change in operating conditions.
4. Temporary Reduction of Connected Load: Where the use of
energy is seasonable or intermittent, no adjustment will be
made for any temporary reduction of connected load. Any
customer resuming service on such connected load within 12
months after it was disconnected, will be required to pay
all charges which would have been billed if the temporary
reduction of connected load had not been made.
5. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this schedule.
6. In-Lieu Tax and Franchise Payments: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Authorized by The City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
- 2 -
-
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. D
DOMESTIC SERVICE
APPLICABILITY
Applicable to domestic service including lighting, heating,
cooking and power or combination thereof in a single-family
accommodation; also to domestic farm service when supplied
through the farm operator's domestic meter.
TERRITORY
Within the city limits of the City of Vernon.
RATES
Per Meter Per Month
Domestic Service
Customer Charge............................$
$1. 50
Energy Charge (to be added to Customer
Charge): ........................... ... . . . . . .
4.5QJt
Minimum Charge:
The monthly minimum charge shall be the
monthly Customer Charge.
SPECIAL CONDITIONS
1. Seasonal Service: For summer cottage customers and others
who normally require service for only part of the year, the
schedule is applicable only on annual contract.
2. Energy Cost Adjustment: The rates above include the ad-
justment as provided for in Part G of the Preliminary
Statement.
3. In-Lieu of Tax and Franchise Payments: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution no.
Effective
Effective
Effective
Effective
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. PA-l
POWER-AGRICULTURAL AND PUMPING
CONNECTED LOAD BASIS
,
APPLICABILITY
Applicable to power service for general agricultural
purposes or for general water or sewerage pumping.
y
TERRITORY
Within the city limits of the City of Vernon.
:h
Horsepower of
Connected Load
Per Meter
2 and over
Monthly
Service Charge
Per Meter
RATES
Per hE
$1. 00
Energy (Charge to be added to Service
Charge) Rate Per kWh ...................
6.705t
Minimum Charge: The annual minimum charge shall be the annual
Service Charge.
SPECIAL CONDITIONS
l. Voltage: Service will be supplied at one standard power
vol tage.
Ie
2. Connected Load: Connected load is the sum of the rated
capacities of all of the customer's equipment that it is
P?ssible to connect to the Company's lines at the same
tlme, determined to the nearest 1/10 hp.. Ip no case will
charges be based on ess than 2 hp for slng e-phase
service or no less than 3 hp for three-phase service. The
rated capacity of the customer's equipment will be the
rated horsepower output of standard rated motors, the rated
horsepower of welders determined in accordance with the
section designated Welder Service in Rule No.2, and the
rated kilovolt-ampere input capacity of other equipment,
with each kilovolt-ampere of input considered equal to one
horsepower. Normally such ratings will be based on the
manufacturer's rating as shown on the nameplate or
elsewhere but may, at the option of the Company, be based
on tests or other reliable information.
Authorized by City of Vernon:
Ordinance No.
Ordinance No. ----
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
- 1 -
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. PA-2
POWER-AGRICULTURAL AND PUMPING
DEMAND BASIS
APPLICABILITY
Applicable to power service for general agricultural purposes
or for general water or sewerage pumping.
TERRITORY
Within the city limits of the City of Vernon.
RATES
Demand Charge:
First 75 KW or less of billing demand.....
All excess KW of billing demand, per KW...
Per Meter
Per Month
$ 525.00
$ 7.00
Energy Charges {to be added to Demand Charge):
6.S58t
Minimum Charge:
The monthly minimum charge shall be the monthly Demand
Charge.
SPECIAL CONDITIONS
l. Voltage: Service will be supplied at one standard voltage.
2. Billing Demand: The billing demand shall be the kilowatts
of maximum demand but not less than 50% of the highest
maximum demand established in the preceding eleven months,
however, in no case shall the billing demand be less than
75 KW. Billing demand shall be determined to the nearest
1/10 KW.
3. Maximum Demand: The maximum demand in any month shall be
the measured maximum average kilowatt input, indicated or
recorded by instruments to be supplied by the Company,
during any l5-minute metered interval in the month, but not
less than the diversified resistance welder load computed
in accordance with the section designated Welder Service
in Rule No.2. Where demand is intermittent or subject to
violent fluctuations, a 5-minute interval may be used.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
-1-
4. Power Factor Adjustment: When the billing demand has
exceeded 200 KW for three consecutive months, a
kilovar-hour meter will be installed as soon as practical,
and, therefore, until the billing demand has been less than
150 KW for twelve consecutive months, the charges will be
adjusted each month for power factor, as follows:
The Charges will be decreased by 20 cents per kilowatt of
measured maximum demand and will be increased by 20 cents
per kilovar of reactive demand. However, in no case shall
the number of kilovars used for the adjustment be less than
one-fifth the number of kilowatts.
The Kilovars of reactive demand shall be calculated by
multiplying the kilowatts of measured maximum demand by the
ratio of the kilovar-hours to the kilowatthours. Demands
in kilowatts and kilovars shall be determined to the
nearest one-tenth (0.1) unit. A ratchet device will be
installed on the kilovar-hour meter to prevent its reverse
operation on leading power factors.
5. Tempora~y Discontinuance of Service: Where the use of
energy IS seasonable or intermittent, no adjustments will
be made for a temporary discontinuance of service. Any
customer resuming service within twelve months after such
service was discontinues will be required to pay all
charges which would have been billed if service had not
been discontinued.
6. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this schedule.
7. In-Lieu Tax and Franchise Payments: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
8. Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either
required by the Company because of the nature of the
customer's load or requested by the customer. Excess
transformer capacity shall be billed at $1.00 per kVA per
month.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.----
Resolution No.
Effective
Effective
Effective
Effective
-2-
9. Contract Demand: A contract demand will be established by
the Company, based on applicant's demand requirements for
any customer of record on this schedule who requests an
increase or decrease in transformer capacity in accordance
with Rule No. 12D. A contract demand arrangement is
available upon request for all customers of record on this
schedule. Contract demand is based upon the nominal
kilovolt-ampere rating of the Company's serving
transformer(s) or the standard transformer size determined
by the Company as required to serve the customer's stated
measurable kilowatt demand, whichever is less and is
expressed in kilowatts.
l0. Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall be
computed by multiplying the billing demand by the demand
charge per kilowatt. Where a contract demand is involved,
the monthly minimum demand charge shall be the greater of:
a. The charge as computed by multiplying the billing
demand by the demand charge per kilowatt; or
b. A facilities charge of $l.00 per kilowatt of
contract demand.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
-3-
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. S
STANDBY
APPLICABILITY
Applicable to standby or breakdown service where the entire
electrical requirements on the customer's premises are not
regularly supplied by the utility.
TERRITORY
Within the city limits of the City of Vernon.
RATES
Standby Charge:
First 20 kW of contract demand, per kW...
All excess kW of demand, per kW..........
Per Meter
Per Month
$ 4.5~
$ 2.30
The standby charge shall not be less than $20.00 per month.
Regular Schedule Charges (to be added to Standby Charge) :
All energy charges of the applicable regular service
schedule designated in the service contract plus a charge
of $14.64 per kW of on-peak demand in any month.
Minimum Charge: The monthly minimum charge shall be the
standby charge plus the regular schedule minimum
charge.
SPECIAL CONDITIONS
l. Contract Demand: In case the customer desires the utility
to stand ready to supply the entire connected load of the
customer's plant, or an issolated part thereof, then such
maximum load will be estimated by the utility, based on
tests and other information available. In case the
customer desires the utility to stand ready to supply a
number of kilowatts less than the maximum demand of the
entire cus~omer's plant, or an isolated part thereof, then
the customer and the utility shall agree upon the number of
kilowatts the utility will stand ready to supply; and the
customer shall, at his own expense, furnish and install a
suitable circuit breaker enclosed in a steel box equipped
with a lock, all to be approved by and under the sole
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Re sol ut ion No.
Effective
Effective
Effective
Effective
- 1 -
SPECIAL CONDITIONS
1. (continued)
control of the utility, and adjustment and operation of
said circuit breaker to be in no way interfered with by the
customer. This circuit breaker shall be set to break the
connection with the utility's service when the customer's
maximum demand exceeds the number of kilowatts which the
re utility stands ready to supply, in which case the utility
t will renew the connections upon due notice.
2. Contract: This schedule will apply only where the customer
will sign a service contract for at least one year.
3. Parallel Operation: This schedule is not applicable for
parallel operation of the customer's plant with the service
of the utility.
.h.
4. Maximum Load: The utility reserves the right to establish
the maximum load served under this schedule.
5. In-Lieu of Tax and Franchise Payments: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Authorized
by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
:y
1
~n
of
3
I
- 2 -
CITY OF VERNON
LIGHT & POWER DEPARTMENT
Schedule No. TC-l
TRAFFIC CONTROL SERVICE
APPLICABILITY
Applicable to single-phase service for traffic directional
signs or traffic signal systems located on streets,
highways and other public thoroughfares and to railway
crossing and track signals.
TERRITORY
Within the City limits of the City of Vernon.
RATES
PER METER
PER MONTH
Customer Charge: $4.750
Energy Charge (to be added to Customer Charge):
All kWh, per kWh 8.254t
Minimum Charge: The monthly minimum charge shall be the
monthly Customer charge.
SPECIAL CONDITIONS
l. Voltage: Service will be supplied at one standard
voltage not in excess of 240 volts or, at the option of the
Company, at 240/480 volts, three wire, single phase.
2. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this scnedule.
3. In-Lieu Tax and Franchise Payment: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.----
Resolution No.
Effective
Effective
Effective
Effective
STEP 2 RATES
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. GS-l
GENERAL SERVICE
APPLICABILITY
Applicable to single and three-phase general service
including lighting and power. This schedule is not
applicable when, in the opinion of the Company, the
customer's load and use characteristics indicate that the
maximum demand may exceed 20 kW.
TERRITORY
Within the city limits of the City of Vernon.
RATES Per Meter
Per Month
Customer Charge..............................S 6.90
Energy Charge (to be added to Customer Charge):
All kWh, per kWh........................... 11.l25t
Minimum Charge:
The monthly minimum charge shall be the
monthly Customer Charge.
SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard voltage.
2. X-Ray Installations: Where the Company installs the
standard transformer capacity requested by a customer to
serve separately an X-ray installation, the customer charge
will be increased by Sl.OO per kVA of transformer capacity
requested.
3. Temporary Discontinuance of Service: Where the use of
energy is seasonal or intermittent, no adjustments will be
made for a temporary discontinuance of service. Any
customer prior to resuming service within twelve months
after such service was discontinued will be required to pay
all charges which would have been billed if service had not
been discontinued.
Authorized by the City of Vernon:
Ordinance No.
Ord inance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
- 1 -
4. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this schedule.
5. In-Lieu of Tax and Franchise Payments: the total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
6. Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either
required by the Company because of the nature of the
custome,'s load or requested by the customer. Excess
transformater capaciaty shall be billed at $l.00 per KVA
per month.
Authorized by the City of Vernon:
Ord inance No.
Ordinance No.
Resolution No.----
Resolution No.
Effective
Effective
Effective
Effective
- 2 -
STEP 2 RATES
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. GS-2
GENERAL SERVICE
APPLICABILITY
Applicable to single and three-phase general service
including lighting and power.
TERRITORY
Within the city limits of the City of Vernon.
RATES Per Meter
Demand Charge: Per Month
First 20 kW or less of billing demand.... $180.00
All excess kW of billing demand, per kW.. $ 9.75
Energy charge (to be added to Demand Charge): 5.873t
Minimum Charge:
The monthly minimum charge shall be the monthly Demand
Charge.
SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard voltage.
2. Billing Demand: Billing demand shall be the kilowatts of
maximum demand but not less than 50% of the highest maximum
demand established in the preceding eleven months, however,
in no case shall the billing demand be less than 20 kW.
Billing demand shall be determined to the nearest kW.
3. Maximum Demand: The maximum demand in any month shall be
the measured maximum average kilowatt input, indicated or
recorded by instruments to be supplied by the Company,
during any l5-minute metered interval in the month, but
shall not be less than the diversified resistance welder
load computed in accordance with the section designated
Welder Service in Rule No.2.
4. X-Ray Installations: Where the Company installs the
standard transformer capacity requested by a customer to
serve separately an X-Ray installation, the minimum charge
will be increased by $1.00 per kVA of transformer capacity
requested.
Authorized by City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
- 1 -
5. Temporary Discontinuance Service: Where the use of energy
is seasonal or intermittent, no adjustments will be made
for a temporary discontinuance of service. Any customer
prior to resuming service within twelve months after such
service was discontinued will be required to pay all
charges which would have been billed if service had not
been discontinued.
6. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this schedule.
7. Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either
required by the Company because of the nature of the
customer's load or requested by the customer. Excess
transformer capacity shall be billed at $l.0~ per kVA per
month.
8. Contract Demand: A contract demand will be established by
the Company, based on applicant's demand requirements for
any customer newly requesting service on this schedule and
for any customer of record on this schedule who requests an
increase or decrease in transformer capacity in accordance
with Rule No. 12D. A contract demand arrangement is
available upon request for all customers of record on this
schedule. Contract demand is based upon the nominal
kilovolt-ampere rating of the Company's serving
transformer(s) or the standard transformer size determined
by the Company as required to serve the customer's stated
measurable kilowatt demand, whichever is less and is
expressed in kilowatts.
9. Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall be
computed by multiplying the billing demand by the demand
charge per kilowatt. Where a contract demand is involved,
the monthly minimum demand charge shall be the great.er of:
a. The charge as computed by multiplying the billing
demand by the demand charge per kilowatt; or
b. A facilities charge of $1.00 per kilowatt of
contract demand.
Author\zed By City of Vernon:
Ordinance No.
Ordinance No.
Resol ut ion No.
Resolution No.
Effective
Effective
Effective
Effective
- 2 -
10. In-Lieu Tax and Franchise Payment: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Authorized By City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resol ution No.
Effective
Effective
Effective
Effective
- 3 -
STEP 2 RATES
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. A-7
GENERAL SERVICE
APPLICABILITY
Applicable to single and three-phase general service
including lighting and power.
TERRITORY
Within the city limits of the City of Vernon.
RATES
Per Meter
Demand Charge: Per Month
First 200 kW or less of billing demand.... $1,750.00
All excess kW of billing demand, per kW........$ 9.501
Energy Charge (to be added to Demand Charge) :....
5.503t
Minimum Charge:
The monthly minimum charge shall be the monthly Demand
Charge.
SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard voltage.
2. Billing Demand: The billing demand shall be the kilowatts
of maximum demand but not less than 50% of the highest
maximum demand established in the preceding eleven months,
however, in no case shall the billing demand be less than
200 kW. Billing demand shall be determined to the nearest
kW.
3. Maximum Demand: The maximum demand in any month shall be
the measured maximum average kilowatt input, indicated or
recorded by instruments to be supplied by the Company,
during any 15 minute metered interval in the month, but
shall not be less than the diversified resistance welder
load computed in accordance with the section designated
Welder Service in Rule No.2. Where the demand is
intermittent or subject to violent fluctuations, as-minute
interval may be used.
Authorized by City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution, No.
Effective
Effective
Effective
Effective
- 1 -
4. Voltage Discount: The charges before adjustments will be
reduced by 3% for service delivered and metered at voltages
of from 2 kV to 10 kV; and by 5% for service delivered and
metered at voltages over 50 kVi except that when only one
transformation from a transmission voltage level is
involved, a customer normally entitled to a 3% discount
will be entitled to a 4% discount.
5. Power Factor Adjustment: The charges will be adjusted each
month for power factor as follows:
The charges will be decreased by 20 cents per kilowatt of
measured maximum demand and will be increased by 20 cents
per kilovar of reactive demand. However, in no case shall
the kilovars used for the adjustment be less than one-fifth
the number of kilowatts.
The kilovars of reactive demand shall be calculated by
multiplying the kilowatts of measured maximum demand by the
ratio of the kilovar-hours to the kilowatt hours. Demands
in kilowatts and kilovars shall be determined to the
nearest unit. Aa rachet device will be installed on the
kilovar-hour meter to prevent its reverse operation on
leading power factors.
6. Temporary Discontinuance of Service: Where the use of
energy is seasonable or intermittent, no adjustment will be
made for a temporary discontinuance of service. Any
customer prior to resuming service within twelve months
after such service was discontinued will be required to pay
all charges which would have been billed if service had not
been discontinued.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
- 2 -
7. Adjustment for Off-Peak Demand: Upon application by the
customer in any month where the maxium demand exceeds
500kW, and kilowatts of maxim,um demand in excess of the on
peak demand will not be considered in establishing the
billing demand for computing the energy charge, but will be
considered in establishing the billing demand for computing
the demand charge, by adding one half of the amount that
the maximyum demand exceeds the on peak demand, to the on
peak demand. The on peak demand will be the maximum demand
occurring between the hours of 6:30 A.M. and l~:30 P.M.,
Pacific Standard Time, of any day except Sundays and the
following holidays: New Years Day, Washington's Birthday,
Memorial Day. Independence Day, Labor Day, Thanksgiving Day
and Christmas.
8. Contracts: An initial three year contract may be required
where applicant requires new or added serving capacity
exceeding 2,000 KVA.
9. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therin will be applied to kWh billed under
this Schedule.
l0. Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either
required by the Company because of the nature of the
customer's load or requested by the customer. Excess
transformer capacity shall be billed at $1.00 per kVA per
month.
11. Contract Demand: A contract demand will be established by
the Company, based on applicant's demand requirements for
any customer newly requesting service on this schedule and
for any customer of record on this schedule who requests an
increase or decrease in transformer capacity in accordance
with Rule No.12D. A contract demand arrangement is
available upon request for all customers of record on this
schedule. Contract demand is based upon the nominal
kilovolt-ampere rating of the Company's serving
transformer(s) or the standard transformer size determined
by the Company as required to serve the customer's stated
measurable kilowatt demand, whichever is less and is
expressed in kilowatts.
Authorized by the City of Vernon:
Ordinance No. Effective
Ordinance No. Effective
Resolution No:--- Effective
Resolutiort No. Effective
- 3 -
12. Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall be
computed by multiplying the billing demand by the demand
charge per kilowatt. Where a contract demand is involved,
the monthly minimum demand charge shall be the greater of:
a. The charge as computed by multiplying the billing
demand by the demand charge per kilowatt; or
b. A facilities charge of $l.00 per kilowatt of
contract demand.
13. In-Lieu of Tax and Franchise Payments: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resol ution No.
Effective
Effective
Effective
Effective
- 4 -
STEP 2 RATES
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. TOU-V
GENERAL SERVICE-LARGE
APPLICABILITY
Applicable to general service, including lighting and
power. This schedule is applicable for all customers of
record on April 3, 1980 and thereafter to all customers for
whom magnetic tape recording meters have been ~nstalled.
Any customer whose monthly maximum demand has fallen below
500 KW for 12 consecutive months may elect to take service
on any other applicable schedule.
TERRITORY
Within the city limits of the City of Vernon.
Customer Charge:...........
Per Meter
Per Month
$550.00
RATES
Demand Charge(to be added to Customer Charge):
All kW of on peak billing demand, per kW
Plus all kW of mid peak billing demand, per
Plus all off peak billing demand, per kWh
$9.751
kW $1.46
no charge
(Subject to Minimum Demand Charge. See Special Condition No.6)
Energy Charge (to be added to
All on peak kWh, per kWh
Plus all mid peak kWh, per
Plus all off peak kWh, per
Demand Charge)
kWh
kWh
. . . . . . .
5.035~
4.119t
4.247t
. . . . . . .
. . .
Time periods:
Time Periods are defined as follows:
On peak: l:00 p.m. to 1:00 p.m.
summer weekdays except holidays
5:00 p.m. to l0:00 p.m.
winter weekdays except holidays
Mid Peak: 9:00 a.m. to 1:00 p.m. and
7:00 p.m. to 11:00 p.m.
summer weekdays except holidays
8:00 a.m. to 5:00 p.m.
winter weekdays except holidays
Off Peak: all other hours
Holidays are: New Year's Day, WaShington's Birthday,
Authorized by the City of Vernon:
Ordinance No. Effective
Ordinance No. Effective
Resolution No. Effective
Resolution No. Effective
Memorial Day, Independence Day, Labor Day, Veteran's
Day, Thanksgiving Day and Christmas.
When any holiday listed above falls on Sunday, the
following Monday will be recognized as an off peak period.
No change in off peak will be made for holidays falling on
Saturday.
The summer season time periods shall commence at 12:01 a.m.
May 1 and continue through October 31 of each year and the
winter season time periods shall commence at l2:01 a.m.
November 1 and continue through April 30 of the following
year.
2. Billing Demand: The billing demand shall be the kilowatts
of maximum demand but not less than 50% of the highest
maximum demand established in the preceding 11 months,
however, in no case shall the on peak billing demand be
less than lOOO KW. Billing demand shall be determined to
the nearest KW.
3. Maximum Demand: The maximum demand in any month shall be
measured maximum average kilowatt input indicated or
recorded by instruments to be supplied by the Company,
during any l5-minute metered interval in the month, but not
less than the diversified resistance welder load computed
in accordance with the section designated Welder Service in
Rule No.2. Where the monthly demand exceeds 5000 KW per
month, the maximum demand shall be based on a 30-minute
interval. Where the demand is intermittent or subject to
violent fluctuations, a 5-minute interval may be used.
4. Voltage Discount: The demand charges before adjustment
will be reduced by 3% for service delivered and metered
at voltages of from 2kV to l0kV; by 4% for service
delivered and metered at voltages of from llkV to 50kV; and
by 5% for service delivered and metered at voltages over
50kV; except that when only one transformation from a
transmission voltage level is involved, a customer normally
entitled to a 3% discount will be entitled to a 4%
discount.
5. Power Factor Adjustment: The charges will be adjusted
each month for the power factor as follows:
The charges will be decreased by 20 cents per kilowatt of
measured maximum demand and will be increased by 20 cents
per kilovar of reactive demand. However, in no case shall
the kilovars used for the adjustment be less than one fifth
of the number of kilowatts.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
The kilovars of reactive demand shall be calculated by
multiplying the kilowatts of measured maximum demand by the
ratio of the kilovar-hours to the kilowatt hours. Demands
in kilowatts and kilovars to the kilowatt hours. Demand in
kilowatts and kilovars shall be determined to the nearest
unit. A ratchet device will be installed on the
kilovar-hour meter to prevent its reverse operation on
leading power factors.
6. Temporary Discontinuance of Service: Where the use of
energy is seasonal or intermittent, no adjustment will be
made for a temporary discontinuance of service. Any
customer prior to resuming service within twelve months
after such service was discontinued will be required to pay
all charges which would have been billed if the service had
not been discontinued.
7. In-Lieu of Tax and Franchise Payments: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
8. Contracts: An additional initial three year facilities
contract may be required where applicant requires new or
added serving capacity exceeding 2,00ekVA.
l
~.
9. Customer's Right to Terminate: In the event the net
bill for electric service to the customer is increased
during the term of the requirements contract, provided for
herein, as a result of changes in this schedule, the
customer shall have the right to terminate the requirements
contract on not less than 30 months notice to the utility.
Such notice shall be given within 18e days after the
effective date of such change.
10. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this schedule.
ll. Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either
required by the Company because of the nature of the
customer's load or requested by the customer. Excess
transformer capacity shall be billed at $1.0e per kVA per
month.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
l2. Contract Demand: A contract demand will be established by
the Company, based upon applicant's demand requirements for
any customer newly requesting service on this schedule and
for any customer of record on this schedule who requests an
increase or decrease in transformer capacity in accordance
with Rule 12D. A contract demand arrangement is available
upon request for all customers of record on this schedule.
Contract demand is based upon the nominal kilovolt-ampere
rating of the Company's serving transformer(s) or the
standard transformer size determined by the Company as
required to serve the customer's stated measurable kilowatt
demand, whichever is less and is expressed in kilowatts.
13. Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall be
computed by multiplying the billing demand by the demand
charge per kilowatt. Where a contract demand is involved,
the monthly minimum demand charge shall be the greater of:
a) The charge as computed by multiplying the billing
demand by the demand charge per kilowatt: or
b) A facilities charge of $1.00 per kilowatt of contract
demand.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
STEP 2 RATES
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. LS-l
LIGHTING-STREET AND HIGHWAY
UTILIITY-OWNED SYSTEM
Appl icabil i ty
Applicable to street and highway lighting service supplied
from overhead lines where the Company owns and maintains
the street lighting equipment.
Terri tory
Within the City limits
Rates
Energy Curtailment Service
Midnight or
Equivalent
Service
Per Lamp
Per Month
Facilities
Charge
Per Lamp
Per Month
All Night Service
Per Lamp
Lamp Size-Lumens Per Month
Mercury Vapo r Lamps
3,500 Lumens 8.04 6.80 $5.l0
7,000 Lumens 10.44 7.89 5.10
11,000 Lumens l3.76 9.90 5.75
20,000 Lumens 19.86 13.11 6.05
35,000 Lumens 30.90 18.65 6.40
55,000 Lumens 44.65 25.28 6.45
High Pressure Sod i um Vapor Lamps
5,800 Lumens 7.78 6.96 5.35
9,500 Lumens 9.01 7.61 5.50
l6,00eJ Lumens 11. 26 8.98 6.00
22,000 Lumens 13.19 l0.09 6.40
25,500 Lumens l4.42 10.78 6.40
47,000 Lumens 20.40 13.92 6.70
STEP 2 RATES
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. LS-2
LIGHTING-STREET AND HIGHWAY
CUSTOMER-OWNED INSTALLATION
APPLICABILITY
Applicable to service for the lighting of streets, highways,
other public thoroughfares, and publicly-owned and publicly-
operated automobile parking lots which are open to the general
public, where the customer owns the street lighting equipment.
TERRITORY
Within the city limits of the City of Vernon.
Per Month
All Niiht Service Midnight Service
Multip e Series Multiple Series
RATE A-UNMETERED SERVICE:
For each kW of lamp load,
per kW.. $26.l9
$34.06
$l5.23
RATE B-UNMETERED SERVICE: Per Meter
Meter Charge: Per Month
Multiple Service.............................$ 4.50
Series Service............................... 12.1210
Energy Charge (to be added to Meter Charge):
All kWh, pe r kWh.............................
7.377t
RATE C-UNMETERED SERVICE-OPTIONAL:
In addition to the Rate A and Rate B charges
$18.5l
Per Lamp
Per Month
Lamp Rating
Lumens
1,0121121
2,500
4,121121121
6,00121
10,00121
3,50121
7,1210121
ll,000
20,01210
35,1211210
5 5, 121 0 0
5,81210
9,5121121
Lamp Type
Incandescent Extended
Incandescent Extended
Incandescent Extended
Incandescent Extended
Incandescent Extended
Service......$
Service......
Service......
Service......
Service......
Mercury Vapor......................
Mercury Vapor......................
Mercury Vapor......................
Mercury Vapor......................
Mercury Vapor......................
Mercury Vapor......................
High Pressure Sodium Vapor.........
High Pressure Sodium Vapor.........
121.33
0.38
0.40
121.42
0.45
121.36
121.33
0.40
121.36
0.54
121.49
121.8121
121.80
16,000 High Pressure Sodium Vapor......... 0.78
22,000 High Pressure Sodium Vapor......... 0.79
25,500 High Pressure Sodium Vapor......... 0.79
47,000 High Pressure Sodium Vapor......... 0.81
STEP 2 RATES
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. OL-l
OUTDOOR AREA LIGHTING SERVICE
APPLICABILITY
Applicable to outdoor area lighting service, other than
street and highway lighting service, supplied from overhead lines
where the Company owns and maintains the area lighting equipment.
TERRITORY
Within the City limits of the City of Vernon.
RATES
LUMINAIRE CHARGE: ENERGY CURTAILMENT SERVICE
MIDNIGHT OR
EQUIVALENT FACILITIES
ALL NIGHT SERVICE SERVICE CHARGE
PER LAMP
PER MONTH
PER LAMP
PER MONTH
PER LAMP
PER MONTH
LAMP SIZE-LUMENS
*
MERCURY VAPOR LAMPS
7,000 Lumens. . . . .
20,000 Lumens. . . .
. . . $l0.49
. . $21.08
$ 8.07
$14.17
$5.1S
$6.10
HIGH PRESSURE SODIUM VAPOR LAMPS
5,800 Lumens.
9,500 Lumens.
22,000 Lumens.
. . .
$ 7.83
$ 9.06
$13.24
$ 7.06
$ 7.72
$10.31
$5.40
$5.55
$6.40
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. . . . .
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POLE CHARGE (to be added to
Luminaire Charge):
PER POLE
PER MONTH
For each additional new wood pole installed.
. . .
. $ 2.59
*Closed to new installations as of February l, 1980.
SPECIAL CONDITIONS
1. Area all night lighting service waill be furnished from dusk
to dawn, approximately 4,140 hours per year, by Company- owned
luminaries supplied from the Company'sexisting 120/240 volt
overhead circuits and mounted on exis'ting Company-owned wood
poles as standard equipment.
2. Where the customer requests the installation of other than
STEP 2 RATES
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. D
DOMESTIC SERVICE
APPLICABILITY
Applicable to domestic service including lighting, heating,
cooking and power or combination thereof in a single-family
accommodation; also to domestic farm service when supplied
through the farm operator's domestic meter.
TERRITORY
Within the city limits of the City of Vernon.
Per Meter Per Month
Domestic Service
RATES
Customer Charge..........................
$l.50
Energy Charge (to be added to Customer
Charge): ..................................
4.50t
Minimum Charge:
The monthly minimum charge shall be the
monthly Customer Charge.
SPECIAL CONDITIONS
l. Seasonal Service: For summer cottage customers and others
who normally require service for only part of the year, the
schedule is applicable only on annual contract.
2. Energy Cost Adjustment: The rates above include the ad-
justment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this schedule.
3. In-Lieu of Tax and Franchise Payments: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No. ----
Resolution No.----
Resolution' no.
Effective
Effective
Effective
Effective
STEP 2 RATES
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. PA-l
POWER-AGRICULTURAL AND PUMPING
CONNECTED LOAD BASIS
APPLICABILITY
Applicable to power service for general agricultural
purposes or for general water or sewerage pumping.
TERRITORY
Within the city limits of the City of Vernon.
Horsepower of
Connected Load
Per Meter
2 and over
Monthly
Service Charge
Per Meter
RATES
Per hp
$1. 00
Energy (Charge to be added to Service
Charge) Rate Per kWh ...................
7.077t
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Minimum Charge: The annual minimum charge shall be the annual
Service Charge.
SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard power
voltage.
2. Connected Load: Connected load is the sum of the rated
capacities of all of the customer's equipment that it is
possible to connect to the Company's lines at the same
time, determined to the nearest 1/10 hp. In no case will
charges be based on less than 2 hp for single-phase
service or no less than 3 hp for three-phase service. The
rated capacity of the customer's equipment will be the
rated horsepower output of standard rated motors, the rated
horsepower of welders determined in accordance with the
section designated Welder Service in Rule No.2, and the
rated kilovolt-ampere input capacity of other equipment,
with each kilovolt-ampere of input considered equal to one
horsepower. Normally such ratings will be based on the
manufacturer's rating as shown on the nameplate or
elsewhere but may, at the option of the Company, be based
on tests or other reliable information.
Authorized by City of Vernon:
Ordinance No.
Ordinance ,No.
Effective
Effective
- 1 -
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3. Overloaded Motors: Whenever, upon test, any motor under
normal operating conditions is found to be delivering more
than 115 percent of its capacity as indicated by its
nameplate rating, the Company may disregard the nameplate
rating and base its charges upon the output as calculated
from test. Any motor which is billed on a basis in excess
of its nameplate rating in accordance with this special
condition shall be tested at intervals to be determined by
the Company or upon notification by the customer of a
permanent change in operating conditions.
4. Temporary Reduction of Connected Load: Where the use of
energy is seasonable or intermittent, no adjustment will be
made for any temporary reduction of connected load. Any
customer resuming service on such connected load within 12
months aEter it was disconnected, will be required to pay
all charges which would have been billed if the temporary
reduction of connected load had not been made.
5. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this schedule.
6. In-Lieu Tax and Franchise Payments: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Authorized by The City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
- 3 -
STEP 2 RATES
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. PA-2
POWER-AGRICULTURAL AND PUMPING
DEMAND BASIS
APPLICABILITY
Applicable to power service for general agricultural purposes
or for general water or sewerage pumping.
TERRITORY
Within the city limits of the City of Vernon.
RATES
Demand Charge:
First 75 KW or less of billing demand.....
All excess KW of billing demand, per KW...
Per Meter
Per Month
$ 525.013
$ 7.00
Energy Charges (to be added to Demand Charge):
7.2313t
Minimum Charge:
The monthly minimum charge shall be the monthly Demand
Charge.
SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard voltage.
2. Billing Demand: The billing demand shall be the kilowatts
of maximum demand but not less than 513% of the highest
maximum demand established in the preceding eleven months,
however, in no case shall the billing demand be less than
75 KW. Billing demand shall be determined to the nearest
1/113 KW.
3. Maximum Demand: The maximum demand in any month shall be
the measured maximum average kilowatt input, indicated or
recorded by instruments to be supplied by the Company,
during any lS-minute metered interval in the month, but not
less than the diversified resistance welder load computed
in accordance with the section designated Welder Service
in Rule No.2. Where demand is intermittent or subject to
violent fluctuations, a 5-minute interval may be used.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No. ----
Resolution No.----
Resolution No.
Effective
Effective
Effective
Effective
-1-
4. Power Factor Adjustment: When the billing demand has
exceeded 200 KW for three consecutive months, a
kilovar-hour meter will be installed as soon as practical,
and, therefore, until the billing demand has been less than
150 KW for twelve consecutive months, the charges will be
adjusted each month for power factor, as follows:
The Charges will be decreased by 20 cents per kilowatt of
measured maximum demand and will be increased by 20 cents
per kilovar of reactive demand. However, in no case shall
the number of kilovars used for the adjustment be less than
one-fifth the number of kilowatts.
The Kilovars of reactive demand shall be calculated by
multiplying the kilowatts of measured maximum demand by the
ratio of the kilovar-hours to the kilowatthours. Demands
in kilowatts and kilovars shall be determined to the
nearest one-tenth (0.1) unit. A ratchet device will be
installed on the kilovar-hour meter to prevent its reverse
operation on leading power factors.
5. Temporary Discontinuance of Service: Where the use of
energy is seasonable or intermittent, no adjustments will
be made for a temporary discontinuance of service. Any
customer resuming service within twelve months after such
service was discontinues will be required to pay all
charges which would have been billed if service had not
been discontinued.
6. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy adjustment billing
factors and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this schedule.
7. In-Lieu Tax and Franchise Payments: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
8. Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either
required by the Company because of the nature of the
customer's load or requested by the customer. Excess
transformer capacity shall be billed at $1.00 per kVA per
month.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.----
Resolution No.
Effective
Effective
Effective
Effective
-2-
9. Contract Demand: A contract demand will be established by
the Company, based on applicant's demand requirements for
any customer of record on this schedule who requests an
increase or decrease in transformer capacity in accordance
with Rule No. 12D. A contract demand arrangement is
available upon request for all customers of record on this
schedule. Contract demand is based upon the nominal
kilovolt-ampere rating of the Company's serving
transformer(s) or the standard transformer size determined
by the Companyy as required to serve the customer's stated
measurable kilowatt demand, whichever is less and is
expressed in kilowatts.
10. Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall be
computed by multiplying the billing demand by the demand
charge per kilowatt. Where a contract demand is involved,
the monthly minimum demand charge shall be the greater of:
a. The charge as computed by multiplying the billing
demand by the demand charge per kilowatt; or
b. A facilities charge of $l.00 per kilowatt of
contract demand.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
-3-
STEP 2 RATES
CITY OF VERNON
LIGHT AND POWER DEPARTMENT
Schedule No. S
STANDBY
APPLICABILITY
Applicable to standby or breakdown service where the entire
electrical requirements on the customer's premises are not
regularly supplied by the utility.
TERRITORY
Within the city limits of the City of Vernon.
RATES
Standby Charge:
First 20 kW of contract demand, per kW...
All excess kW of demand, per kW..........
Per Meter
Per Month
$ 4.50
$ 2.30
The standby charge shall not be less than $20.00 per month.
Regular Schedule Charges (to be added to Standby Charge):
All energy charges of the applicable regular service
schedule designated in the service contract plus a charge
of $15.63 per kW of on-peak demand in any month.
Minimum Charge: The monthly minimum charge shall be the
standby charge plus the regular schedule minimum
charge.
SPECIAL CONDITIONS
1. Contract Demand: In case the customer desires the utility
to stand ready to supply the entire connected load of the
customer's plant, or an issolated part thereof, then such
maximum load will be estimated by the utility, based on
tests and other information available. In case the
customer desires the utility to stand ready to supply a
number of kilowatts less than the maximum demand of the
entire customer's plant, or an isolated part thereof, then
the customer and the utility shall agree upon the number of
kilowatts the utility will stand ready to supply; and the
customer shall, at his own expense, furnish and install a
suitable circuit breaker enclosed in a steel box equipped
with a lOCk, all to be approved by and under the sole
Authorized by the City of Vernon:
Ordinance No.
Ordinance No. ----
Resolution No.----
Resolution No.
Effective
Effective
Effective
Effective
- 1 -
SPECIAL CONDITIONS
1. (continued)
control of the utility, and adjustment and operation of
said circuit breaker to be in no way interfered with by the
customer. This circuit breaker shall be set to break the
connection with the utility's service when the customer's
maximum demand exceeds the number of kilowatts which the
utility stands ready to supply, in which case the utility
will renew the connections upon due notice.
2. Contract: This schedule will apply only where the customer
will sign a service contract for at least one year.
3. Parallel Operation: This schedule is not applicable for
parallel operation of the customer's plant with the servic~
of the utility.
4. Maximum Load: The utility reserves the right to establish
the maximum load served under this schedule.
5. In-Lieu of Tax and Franchise Payments: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.
Resolution No.
Effective
Effective
Effective
Effective
- 2 -
STEP 2 RATES
CITY OF VERNON
LIGHT & POWER DEPARTMENT
Schedule No. TC-l
TRAFFIC CONTROL SERVICE
APPLICABILITY
Applicable to single-phase service for traffic directional
signs or traffic signal systems located on streets,
highways and other public thoroughfares and to railway
crossing and track signals.
TERRITORY
Within the City limits of the City of Vernon.
RATES
PER METER
PER MONTH
Customer Charge: $4.750
Energy Charge (to be added to Customer Charge):
All kWh, per kWh 8.626t
Minimum Charge: The monthly minimum charge shall be the
monthly Customer charge.
SPECIAL CONDITIONS
l. Voltage: Service will be supplied at one standard
voltage not in excess of 24~ volts or, at the option of the
Company, at 240/480 volts, three wire, single phase.
2. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary
Statement. The applicable energy cost adjustment billing
factors' and fuel collection balance adjustment billing
factor set forth therein will be applied to kWh billed
under this schedule.
3. In-Lieu Tax and Franchise Payment: The total charges
computed pursuant to the above rates and charges are to be
increased by 3 percent to reflect payments in lieu of tax
and franchise payments.
Authorized by the City of Vernon:
Ordinance No.
Ordinance No.
Resolution No.----
Resolution No.
Effective
Effective
Effective
Effective
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BAKER G. CLAY & ASSOCIATES. INC.
REPORT ON RATE DESIGN
CITY OF VERNON, CALIFORNIA
Municipal Light Department
JULY 1982
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REPORT ON RATE DESIGN
CITY OF VERNON, CALIFORNIA
MUNICIPAL LIGHT DEPARTMENT
JULY 1982
prepared by
Baker G. Clay & Associates, Inc.
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TABLE OF CONTENTS
Section
Description
Introduction
Adequacy of Revenues Under
Existing Rates
Revenue Requirements
Rates For Special Contract
Customers
Allocation of Revenue
Requirements
Proposed Changes in Rate
Schedule Structure
Edison Rates
The Design of Rates
The Energy Cost Adjustment
Billing Factor (ECABF)
PURPA Standards
1. Cost of Service
2. Declining Block Rates
3. Time-of-Day Rates
~. Seasonal Rates
5. Interruptible Rates
6. Load Management Techniques
7. Master Metering
8. Automatic Adjustment Clauses
9. Information to Consumers
10. Procedures for Termination
of Electric Service
11. Advertising
Conclusion
I.
II.
III.
IV.
V.
VI.
VII.
VIII.
IX.
X.
XI.
Page
1
5
6
10
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17
22
31
36
38
39
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47
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48
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I. INTRODUCTION
On March 3', 1982, Southern California Edison Company
(Edison) tendered for filing with the Federal Energy
Regulatory Commission (FERC) in Docket No. ER82-427 a
proposed two-step increase in its wholesale rates for
service to Vernon and seven other wholesale customers. The
step one rates provide for an increase in jurisdictional
revenues of approximately $38.5 million (15.8%) for the
twelve month test period ending August 31, 1983. The step
two rates would result in an additional increase in rev~nues
above the step one rates of approximately $22 million
(7.7%). Edison requested effectiv~ dates for the step one
and step two rates of June 1, 1982, and June 2, 1982,
respectively. Edison stated that while it believed no
suspension of its step two rates is warranted, Edison would
not object to an effective date of the earlier of the
in-service date of its San Onofre Nuclear Generating Station
Unit No.2 (SONGS 2) (anticipated to be August 15, 1982) or
five months after the June 2 proposed effective date, i.e.,
November 2, 1982.
By its order issued May 28, 1982 the FERC suspended the
Step 1 increase for one day and allowed it to become
effective, subject to refund, on June 2, 1982. The FERC
suspended the Step 2 increase to the earlier of November 2,
-1-
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1982 or the in-service date of SONGS 2. Both Step 1 and
Step 2 rates are subject to ultimate refund pending FERC
action on the merits of the proposed increases.
While Vernon and the other wholesale customers have
vigorously protested the proposed increase, and while such
rates may ultimately be reduced and some refunds required,
Vernon's cost of purchases have increased dramatically with
the Step 1 increase effective June 2. and will increase
again when Edison's Step 2 increase becomes effective.
These rate increases result in increases in both the demand
and energy components of Edison's rates under which Vernon
is billed.
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Sheets 2, 3, and 4 of Exhibit B show the calculation of
Vernon's cost of purchases from Edison under existing rates,
Step 1 rates and Step 2 rates, respectively. The following
table shows the increases in demand costs to Vernon under
the Step 1 and Step 2 increases:
Demand Cost
to Vernon
(ODD's)
Step 1
Step 2
Increased Rates
Existing Rates
Increase
$18.297
13.557
$ 4.740
$23,346
13,557
$ 9,789
The proposed Step 1 and Step 2 rate increases will
thus almost double the demand cost component of
Vernon's purchases from Edison. In addition, the cost
of energy will increase by $7.8 million. or by almost
as much as the demand cost.
The Step 1 increase in the demand component of
Vernon's purchases from Edison will amount to
approximately $4.7 million per year. assuming the same
billing demands experienced during the year ending
March 31. 1982. while the Step 2 increase will amount
-3-
-4-
to another $5.1 million per year for a total increase
in the demand component of Vernon's purchases from
Edison of $9.8 million per year.
The increases in the energy component of the rates
are routinely reflected in Vernon's Energy Clause
Adjustment Billing Factor (ECABF) which is changed
every three months. The increases in Edison's demand
charges. however. are not reflected in the ECABF. and
Vernon must therefore increase its base rates to
recover these increased costs.
This report contains the following recommendations
for the adjustments of Vernon's rates to allow Vernon
to recover its cost of service. including the increased
cost of purchases from Edison. in a fair and equitable
manner: (1) design rates to become effective
September 1. 1982 to recover Vernon's costs. including
the cost of purchased power and energy under Edison's
Step 1 rates. as allocated among the various classes of
service; (2) provide for a surch~rge to recover the
.
increase in the cost of purchases under Step 2 rates.
to become effective on September 1. 1982 or when SONGS
~ is placed in service. whichever is later; and. (3)
provide for a method of reimbursing Vernon for the
increases in the demand costs of its purchases from
Edison prior to September 1. 1982. when Vernon's
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increased rates are to become effective.
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II. ADEQUACY OF REVENUES UNDER PRESENT RATES
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Vernon's revenues under its existing rates are
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approximately equal to its revenue requirements, including
its operating costs and cost of purchases from Edison, as
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shown in Exhibit A. Column B of Exhibit A shows Vernon's
monthly revenues for the twelve month period April 1981
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through March 1982. Column C shows Vernon's cost of
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purchases from Edison during this period, and Column D shows
the excess of Vernon's revenues over its cost of purchases
from Edison. As shown on Line 13, Column D, Vernon's
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revenues for the year exceeded its cost of purchases from
Edison by approximately $6.9 million. During this period,
.
however, Vernon over-collected under its Energy Cost
Adjustment Clause by $1.2 million which will result in
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decreased revenues to Vernon in subsequent months. The net
excess of Vernon's revenues over its cost for this period
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was thus $5.7. Vernon's annual costs in excess of the cost
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of purchases from Edison, projected in the May 28, 1981
report, including the in-lieu payment of $2.16 million, was
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$5.5 million. Vernon's net revenues thus exceed its
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projected costs by less than $200,000. This comparison is
set forth in the following table:
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Vernon's Projected Costs
Excess
5,546
$ 188
Amount
(OOO's)
Revenues
Increase in ECAe Reserve
Net Revenues
$71,096
_<1,162>
$69,934
Cost of Purchases from Edison
Difference
64,200
$ 5,734
The rates which Vernon has had in effect for the year
ending March 31, 1982 have thus been properlY designed to
allow Vernon to recover its cost of rendering electric
service.
III. REVENUE REQUIREMENTS
The City of Vernon has certain revenue requirements
(cost of service) associated with the rendering of
electrical service to its customers. These revenue
requirements are made up of the cost of purchases from
Edison, the cost of operations under the operating agreement
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with Edison, other miscellaneous costs, depreciation of the
electrical facilities used to provide the service, and
return (or interest) on the investment in the electrical
facilities owned by Vernon. A breakdown of Vernon's annual
revenue requirements including the cost of purchases from
Edison under the filed rates (without giving effect to the
fuel clause adjustment) is shown on Sheet 1 of Exhibit B for
the year ended January 31, 1982. Vernon's annual revenue
requirements as estimated for the future with Edison's
Step 1 rate increase in effect is shown in Column C of this
schedule. The cost of purchases from Edison are projected
to increase from $66.0 million per year to $78.5 million per
year assuming the Step 1 rates are to remain in effect for
the entire year. Under the Step 1 rates, the cost of
purchases from Edison of $78.5 million will thus amount to
approximately 95 percent of Vernon's total revenue
requirements of $82.5 million. When the additional Step 2
increase of $5 million becomes effective, on or before
November 2, 1982 to partially reflect SONGS 2, the cost of
purchases from Edison will amount to 95.4 percent of
Vernon's total revenue requirements.
The projected costs of power and energy (purchases from
Edison) under the Step 1 rates are set forth on Line 1,
Column C of Exhibit B, Sheet 1. This projection is based
upon the assumptions: (1) that purchases from Edison during
the year ending March 31, 1983 will be the same as the
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actual purchases during the projected year, as adjusted to
reflect the projected on-peak demand of the Special Contract
Customers; and, (2) the Step 1 rates will be in effect
throughout the projected year. The calculation of the cost
of purchases from Edison under these assumptions is set
forth on Sheet 3 of Exhibit B.
The computations of the cost of purchases from Edison
under eXisting rates, under Step 1 rates and under Step 2
rates are set forth in Sheets 2, 3, and 4, respectively of
Exhibit B. The purchases from Edison are set equal to
actual purchases during the year ending March 31, 1982. as .
adjusted downward to reflect reductions in the on-peak
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demands of the Special Contract Customers.
Line 2, Column C of Exhibit B, Sheet 1 shows the
projected cost of contractual services including consulting
engineering, special accounting, engineering, and legal
counsel of $425,000. Line 3 shows miscellaneous costs of
$116,000 for services of City personnel and supplies and
expenses. Line 4 shows the projected cost of $2,500,000
payable to Edison for operating Vernon's system pursuant ot
its Operating Agreement. Line 5 shows a projection of
depreciation of City's electrical facilities of $400,000.
Line 6 shows an allowance for return on net investment in
electric plant of $536,000. This allowance for return was
computed by applying a rate of return of 11.20 percent,
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based upon Edison's cost of capital, to Vernon's gross plant
less accumulated depreciation. Edison's cost of capital was
used because Vernon's experience with financing is too
limited to use as a measure of the cost of capital. A more
appropriate measure of the cost of capital is the
requirements of a private utility that makes frequent
transactions in the bond and stock markets. Edison is, in
this instance, an appropriate model upon which to base
Vernon's cost of capital. The return component was thus
computed at a rate of 11.20 percen~.which is the rate of
return allowed by the California Public Utilities Commission
in Edi~on's retail case by Decision No. 92549 issued
December 30, 1980 in Edison's Application No. 59351.
As shown on Line 7 of this Exhibit the annual revenue
requirements of the City of Vernon from its electrical
system are approximately $82.5 million under Edison's Step 1
rates. The revenues at existing rates (including the ECABF
charges) as shown on Exhibit A amount to approximately $69.9
million resulting in a revenue deficiency of approximately
$12.6 million, or 15.3 percent. This deficiency, of course,
is based upon a projection of future increases in costs.
The existing rates, including the Energy Cost Adjustment
Clause, are adequate to recover existing costs.
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IV. RATES FOR SPECIAL CONTRACT CUSTOMERS
Because of the nature of their requirements, Bethlehem
Steel Corporation (Bethlehem), Byron Jackson Pump Division,
Borg-Warner Corporation (Byron Jackson), and Steel Casting
Company (Steel Casting) have entered into special contracts
with Vernon. Byron Jackson has two accounts with Vernon;
Kinetic and Bee Jay. These special contracts arise from the
nature of Schedule TOU-R under which Vernon purchases from
Edison. Under the terms of this rate schedule, Vernon pays
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a demand charge based upon the maximum level of its
purchases during a designated "on-peak" period of time. By
arranging their operations so as to minimize their takes
during Edison's pre-designated "on-peak" period, while
operating freely during the pre-designated "off-peak"
period, these customers enable Vernon to realize significant
savings in the demand component of the cost of purchased
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power. The rates included in these special contracts are
designed to pass along to the customers the savings to
Vernon resulting from their revised operations. The
following table shows the "on-peak" and "off-peak" demands
assumed for these customers in the design of their
r~spective rates:
Demand in kW
On-Peak Off-Peak
Demand Demand
850
60,000
8,000
18,000
4,000
Bethlehem
Bee Jay
Kinetic
Steel Casting
6,000
The on-peak demands are included in the existing
contracts and the off-peak demands have been added to the
new contracts.
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Monthly Charges
New Existing
Rates Rates
Monthly
Increase
Exhibit C, Sheet 1 shows the design of the monthly
charges for these Special Contract Customers. The table
below shows a comparison of the new rates with the existing
rates for these customers:
Bethlehem $135,000 $136,000 $<1,000>
Bee Jay 13,680 12,000 1,680
Kinetic 30,180 28,000 2,780
Steel Casting 12,240 12,222 18
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As shown on Sheet 1 of Exhibit C, Bethlehem and Steel
Casting have retained the right to take a small amount of
power during the on-peak period, while Bee Jay and Kinetic
are operating entirely off-peak. 8ethlehem gets a decrease
in the new rates because we have reflected their actual
demands on Vernon during the on-peak period rather than the
contract amount. The cost of this on-peak power to
Bethlehem and Bee Jay has been computed, not on the basis of
Edison on-peak demand rates, but on the basis of Vernon's
demand costs divided by the total billing demands of
Vernon's customers. Because of diversity the sum of the
billing demands of Vernon's customers is greater than the
billing demands that Vernon establishes with Edison. The
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average on-peak demand cost assessed against Bethlehem and
Steel Casting is thus only $6.357 per kW per month, which is
considerably less than Edison's demand rate, of
approximately $9.20 per month. This practice can be
justified, however, only if these customers contribute
diversity to the system (by taking less than their contract
demands at the time Vernon establishes its billing demand
with Edison. In the future, only the customers who actually
contribute diversity to the system will receive the benefit
of this"diversified (lower) on-peak'demand charge. The on-
peak demand charge of the other Special Contract Customers
will be based upon Edison's demand rates, because these
rates reflect the cost to Vernon of serving these customers.
As shown on Exhibit C, Sheet 1, Line 1, Column C,
Bethlehem's demands during the on-peak period has been
averaging 5,095 kW. We have used this value to compute
Bethlehem's monthly charge rather than the contract amount
of 6,000 kW. We have used Steel Casting's on-peak contract
amount in computing the monthly charge because we have no
reason to believe that they will not establish billing
demands at this level.
The energy cost to be included in the special contracts
is computed on Sheet 4 of Exhibit C. The monthly charges to
these Special Contract Customers have been designed to
recover all of the fixed costs allocable to such customers
because the energy charge has been designed to recover the
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V. ALLOCATION OF REVENUE REQUIREMENTS
cost of energy and associated losses only.
Exhibit D, Sheet 1 shows an allocation of the demand
and en~rgy components of the system's rev~nue requirements
among the various classes of service. This allocation of
system revenue requirements among the various customer
classes was made in the following manner. The total revenue
requirements of $82,460,000 as set forth on Exhibit B, Sheet
1 were classified as demand or energy. As shown on Sheet 2
of Exhibit D, the energy cost of purchases from Edison were
classified to the energy component. All other costs were
classified to the demand component. Miscellaneous revenues
($25,000), demand costs associated with service to the
Special Contract Customers and revenues from service to
LS-l, LS-2, and OL-l customers were then deducted from the
classified cost of service. Revenues from the lighting
class of customers were deducted from the cost of service,
rather than allocating costs to such customers because, as
explained in the Rate Design Section, we have determined
that it is appropriate to base the rates for these Schedules
upon Edison's retail rates rather than upon allocated costs.
The remaining classified costs were then allocated as set
forth on Sheet 1 of Exhibit D. The cost of energy purchased
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from Edison as shown in Column C was allocated between
classes of service on the basis of kWh sales to each class,
respectively, as adjusted for losses. The development of
the allocation factors including the adjustment for losses
is shown on Sheet 3 of Exhibit C. For purposes of this
adjustment, it was assumed that some of the customers
purchase from secondary lines, some purchase from primary
lines, some purchase from distribution lines, and some
purchase from transmission lines. Inasmuch as there are
losses at each step along the way, the percent loss
responsibility varies depending upon the voltage level of
service. Therefore, Sheet 3 of Exhibit C shows an estimate
of the total kWh responSibility of each class of service
assuming losses to a common point; the transmission system.
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The other costs, including demand costs associated with
purchases from Edison, Power Factor Adjustments and Voltage
Discounts, were allocated on the basis of the billing
demands of the respective classes, again at the transmission
level voltage. Billing demands were used for this purpose
because this is the best information available for this
purpose. It would be preferable to allocate such costs on
the basis of coincident peak demands, but such data is not
available. In some instances, billing demands were not
recorded, but were imputed. Billing demands for Schedule
No. D and Schedule Nos. GS-1 and TC-1 were imputed on the
basis of 25 percent load factor purchases while billing
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demands for Schedule No. PA-l were imputed on the basis of
50 percent load factor purchases.
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VI. PROPOSED CHANGES IN RATE SCHEDULE STRUCTURE
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1. Charges for the Installation of Excess Capacity- -
Provisions have been added to Schedule Nos. A-8, A-7,
and GS-2 to require that customers purchasing under such
schedules who ask for service facilities having capacities
in excess of their billing demands pay an additional charge
to cover the cost of these facilities. Examples of these
provisions are set forth in Exhibit E. Sheet 1. They are to
be contained in Special Conditions 11, 12, and 13 of
Schedule No. A-8. Special Conditions 10. 11. and 12 of
Schedule No. A-7 and Special Conditions 7, 8. and 9 of
Schedule No. GS-2. and are entitled "Contract Demand",
"Minimum Demand Charge", and "Excess Transformer Capacity",
respectively. These provisions are identical to provisions
contained in the existing Edison Tariff for comparable
service.
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(kW)
2. The Inclusion of Contract Demands in Rate Schedules -
Consistent with the above provisions, contract demands
have been included in the Special Contracts to establish the
maximum kW of entitlements by these ctlstomers during the
off-peak periods. These contract demands are set forth in
the table below:
Maximum
Demands
Bethlehem
Kinetic
Bee Jay
Steel Casting
60,000
18,000
8,000
4.000
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3. Payment In-Lieu of Franchise Fees -
This report recommends a change in the method of
including a payment to the city in lietl of a franchise fee.
Edison has traditionally made franchise fee payments to the
cities in which they render service at retail. and has
included these payments in their retail rates. In similar
fashion, Vernon has traditionally made payments from its
electric utility operations to its general fund as an
in-lieu franchise fee. This payment has been set at 3
percent and has been built into Vernon's rates and charges.
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This report proposes, however, that, rather than build
the in-lieu payment into the rate, an increment be added to
revenues otherwise payable under the rates filed to provide
for the in-lieu franchise fee. The increment to be added to
the revenues under the filed rate to allow for the in-lieu
payment is .03 x revenues at the filed rate. We recognize
that the use of a 3 percent surcharge on the filed rates
will not allow the city to realize a 3 percent tax on total
revenues. To collect 3 percent on total revenues, a
tax-on-tax factor would have to be added to the 3 percent
surcharge.
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The provision to be included in all of the filed rate
schedules to provide for the in-lieu payment is included in
Exhibit E, Sheet 2. Note the following:
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b. Because the tax factor is to be applied to the
actual revenues under the filed rates, it is no
longer necessary to adjust the ECABF to reflect the
in-lieu payments. The ECABF has been adjusted
accordingly.
a. This provision does not apply to the Special
Contract Customers because the in-lieu payment has
been built into their rates; and,
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4. Deferred Account to Recover Edison's Increases Prior to
Vernon's Increases -
Edisonfs Step 1 rate increase became effective on
June 2, 1982 and Edison's Step 2 rates may become effective
prior to the September 1, 1982 effective date of Vernon's
increased rates. Vernon will thus begin paying Edison the
increased rates prior to the time it can recover the
increased costs from its customers. In order to make Vernon
whole without imposing a burden on its customers, it is
proposed that such undercollections, along with associated
interest, be deducted from any refunds received from Edison
arising from such Step 1 and Step 2 increases. The
procedure for retaining such refunds is set forth in
Exhibit E, Sheet 3.
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VII. EDISON RATES
The regulatory methodology of the FERC, which
establishes the rates under which Vernon purchases from
Edison, differs markedly froom the regulatory methodology of
the CPUC, which establishes the rates which Edison's retail
customers purchase under. The FERC, for instance, will
allow rate increases to become effective without serious
examination soon after they are filed but will subsequently
require the refunding of the portion of the proposed
increase that is subsequently found to be excessive. The
CPUC, however, must investigate the rates prior to their
effectiveness.
If a comparison were made of Edison's retail
rates with Vernon's rates, one must take into consideration
that Vernon may receive refunds that will be flowed-through
to its customers. Other major differences exist with
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respect to the form of Edison's wholesale and retail rates,
both of which are now undergoing major changes in form. The
uncertainity as to the level and form of rates that will
stlbsequently be allowed makes it difficult, and in some
instances impossible, for Vernon to design rates for its
customers that are comparable to Edison's rates. These
problems are discussed below.
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1. Edison's Existing Retail Rates -
The rates at which Edison bills its retail customers
are composites of several components. The first is the base
rate under which Edison recovers its projected fixed costs.
These base rates are established in general rate cases which
Edison may file only once every two years. Edison recovers
its projected fixed costs associated with return on
investment, depreciation, income taxes, other taxes, and
operating expenses under its base rates. Next is the Energy
Cost Adjustment Clause (ECAC) under which Edison may file
three times a year; January 1, May 1, and September 1.
Edison recovers 98 percent of its cost of energy under the
ECAC. The other 2 percent of the cost of energy, along with
miscellaneous costs associated mostly with fuel oil
inventory, is recovered under the annual energy rate (AER).
The other component presently included in Edison's rates is
the Conservation Load Management Adjustment Clause (CLMAC).
When SONGS 2 is placed into service, now projected to
be August 15, 1982, Edison will include two additional
components in its rates: (a) The Major Additions Adjustment
Billing Factor (MAABF) under the Major Additions Adjustment
Clause (MAAC) to recover the costs of SONGS 2 that cannot be
projected with reasonable accuracy; and, (b) an Annual Major
Additions Rate (AMAR) designed to recover the SONGS 2 costs
that can be projected with reasonable accuracy. These
various components of Edison's rates are discussed more
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fully below, with reference to Exhibit F.
Sheet 1 of Exhibit F shows the composite Edison retail
rates for Schedule Nos. TOU-8, A-7, GS-2. GS-1, PA-1, and
PA-2 that were effective as of May 4, 1982 and as requested
to become effective on or after August 15. 1982 to reflect
the costs of SONGS 2. Column A shows the rate schedules and
the functional components of the rates (demand. energy, and
customer components). Columns B-I show the levels of the
various increments of the functional components of the
rates.
Column Bshows the base rates that became effective on
January 1, 1981 pursuant to the CPUC Decision No. 92549
issued December 30, 1980 in Edison's Application No. 59351.
In this application Edison had requested increased rates
amounting to $340 million, excluding the costs of SONGS 2,
which was then projected to be placed in service by July 1,
1981. The costs associated with SONGS 2 were to be
recovered by another filing. The Commission's Decision No.
92549 allowed Edison an increase of $294.2 million effective
January 1, 1981 and a further increase of $91.9 million to
be effective January 1, 1982, to offset the affects of
attrition. As will be explained in more detail later, these
base rates will be superseded on January 1, 1983 by rates to
be established in a Commission order in Edison's Application
No. 61138 for a $1.25 billion increase in its retail rates.
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(Note that the rates to be established in this proceeding
will not reflect the costs of SONGS 2 and 3. These costs
are to be established in Application No. 82-02-40 and will
be additive to the base rates).
The rate levels set forth in Column B are designed to
recover Edison's fixed costs associated with generation,
transmission, and distribution. These costs include return
on investment, depreciation, income taxes, othe~ taxes, and
operation and maintenance (O&M) expenses.
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The levels of the functional components of Schedule
TOU-8 are shown on Lines 1 - 8. Edison has established a
base rate demand charge of $5.05 per kW per month for the kW
of demand purchased under this schedule during the on-peak
period. In addition, Edison has established a base rate
demand charge for the mid-peak period of $.65. The customer
charge of $560 per month has been established on the basis
that customers taking as little as 500 kW per month must
purchase under Schedule No. TOU-8. Edison has established
energy charges for the on-peak period, the mid-peak period,
and the off-peak period. The differences in the cents per
kWh charges for energy purchased in these periods are based
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upon the differences in the incremental costs of generation
and transmission during such periods. In its most recent
retail filing, Edison has made a change from its existing
retail rate design that apparently has no practical effect,
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Column C shows the Energy Cost Adjustment Billing
FActor (ECABF) to be 4.286~/kWh to be added to the base
energy rate of all rate schedules. This ECABF was
established by the CPUC's interim opinion issued as Decision
No. 82-04-119 on Apri1 28, 1982 in Application No. 82-03-04.
Edison had proposed a rate stabilization plan in that
application under which the large savings resulting from
purchases of large amounts of hydro-power during the early
part of 1982 be used to offset the increased costs
associated with SONGS 2 through 1983. This rate
stabilization proposal was to be in-lieu of immediate
flow-through of these savings through the ECABF and
subsequent rate increases to reflect SONGS 2 costs. The
Commission declined to adGpt Edison's Rate Stabilization
Plan in total, but did not require the immediate large
reductions in the ECABF. Instead, it provided for somewhat
smaller ECABF reductions (from 5.390~/kWh to 4.286c/kWh)
but better reflects the theoretical support for
differentials between the on-peak, mid-peak, and off-peak
energy charges. Edison has proposed a uniform level for the
base rate energy component in its Schedule No. TOU-8 but has
provided, instead, that the ECABF reflect differences in
costs between the on-peak, mid-peak, and off-peak energy.
These rates are to be effective on January 1, 1983 pursuant
to Edison's filing in Application No. 61138, as discussed
below.
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that would remain in effect throughout the remainder of
1982. (ECABF filings are normally to be made so as to
become effective three times a year; January 1, May 1, and
September 1).
Column D shows the Annual Energy Rate (AER) of
.236t/kWh which was also reduced (from .452t/kWh to
.236t/kWh) by Decision No. 82-04-119. The Annual Energy
Rate is designed so as to recover 2 percent of the annual
energy costs plus miscellaneous costs, mostly associated
with fuel oil inventory..
Column F shows the Conservation Load Management
Adjustment Clause (CLMAC) of .004t/kWh to be added to the
energy component of the rates for each rate schedule.
Column F shows the composite rates in effect as of May 4,
198~ for each of these Edison rate schedules.
As noted above the composite rates now in effect do not
include the cost associated with SONGS 2 which Edison now
projects to place in service on August 15.1982. Edison has
thus filed a proposal in Application No. 82-02-40 to
establish a Major Additions Adjustments Clause (MAAC) to
implement a Major Additions Adjustment Billing Factor
(MAABF) and an Annual Major Additions Rate (AMAR) to recover
the costs of owning, operating, and maintaining SONGS 2.
The surcharges proposed in this filing are to become
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effective on the in-service date of SONGS 2 (now projected
to be August 15, 1982) and are to be added to the composite
rates shown in Column F. Column G shows the surcharge
associated with the MAABF to be .071c/kWh. The MAABF is to
be based upon an estimate of SONGS 2 operation and
maintenance expenses and associated payroll tax and
employee's pension and benefits, which cannot be reasonably
estimated. Any variation between the estimated level of
these expenses and the recorded expenses will be placed in
the MAAC balancing account and adjusted periodically to
reflect any over-collection or under-collection. The AMAR
is designed to recover costs of SONGS 2 that are fixed or
can be reasonably estimated. Such SONGS 2 expenditures to
be recovered through the AMAR are depreciation, property
taxes. income taxes, the administrative and general expenses
associated with injuries, damages, and property insurance,
and return on rate base. ,The initial AMAR is to be
.591c/kWh. Column I shows the composite rates to be
effective August 15, 1982 to reflect the base rates, the
ECAC and the various surcharges inclUding the surcharges to
recover the cost of SONGS 2. It is expected that these
rates will remain in effect until January 1, 1982 at which
time the rates contained in Columns B - F will be replaced
by rates subject to the filing in Application No. 61138.
The MAABF and the AMAR, shown in Columns G and H,
respectively, will remain in effect until December 31, 1985
because Application No. 61138 did not reflect the costs
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associated with SONGS 2.
2. Proposed January 1, 1983 Increase in Base Rates -
Edison proposes in Application No. 61138 to increase
its base rates by $1.25 billion per year to be effective for
the two year periOd January 1, 1983 - December 31, 1985.
Hearings on this application are now being held before the
CPUC and a decision on this filing will be issued in time
for the rates to become effective January 1, 1983. The
proposed increases in base rates are to occur in two steps;
the first increase is to take effect on January 1, 1983 and
the second is to take effect on January 1, 1984.
Sheet 2 of Exhibit F sets forth the level of Edison's
Schedule TOU-8, Schedule No. GS, Schedule No. PA-1, and
Schedule No. PA-2 rates as Edison proposes that become
effective on January 1, 1983. Schedule No. GS contains two
parts; Part A and Part B. This rate schedule replaces
Schedule No. A-7, Schedule No. GS-2 and Schedule No. GS-1.
Column A sets forth the rate schedule and the functional
components of the rate schedules. Column B sets forth for
these rate schedules the base rates proposed in Application
No. 61138. Column C sets forth the Energy Cost Adjustment
Billing Factor, as proposed in Application No. 61138.
Column D sets forth the Annual Energy Rate, also as proposed
in Application No. 61138 and Column E sets forth the
Conservation Load Management Billing Factor as proposed by
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to occur on January 1, 1983.
Edison in Application No. 61138. Column F shows the
composite rate filed in such application. Column G shows
the sum of the Major Additions Adjustment Billing Factor
(.071~/kWh) and the Annual Major Additions Rate (.591~/kWh).
The total rate which Edison proposes to be effective on
January 1, 1983 is thus shown in Column H. A comparison of
the rates effective May 4, 1982, as shown on Sheet 1 of
Exhibit F. with the rates proposed to be effective on
Jan uary 1 , 1983, as shown in Column H of Sheet 2 of Exhibit
F shows the huge increases in Ed i son's retail rates that are
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VIII. THE DESIGN OF RATES
1. To Reflect Edison's Step 1 Increase in Rates -
Exhibit G, Sheet 1 shows the revenues at existing
rates, the proposed revenue increase and the resulting
revenues at the proposed rates. The proposed revenue
increase is shown in Column E. With minor exceptions, the
proposed rates are designed to recover the allocated costs
to each customer class, as set forth in Exhibit D, Sheet 1.
Two exceptions are with respect to Schedule No. D and the
lighting schedules. The customer charge in Schedule No. D
has been decreased from $1.62 per month to $1.50 per month,
and the energy charge has been reduced to 3.6~ per kWh. The
revenues under these rates are less than allocated costs.
Likewise, the lighting rates, Schedule Nos. OL-l, LS-l, and
LS-2, have not been based upon allocated costs. Instead
they have been based upon the rates that Edison charges for
similiar service. Edison's rates are based upon studies of
the unique character of the service rendered by these types
of schedules, and thus probably result in a better measure
of the cost to serve under these schedules than an
allocation of costs. The resulting rates are higher than
would result from an allocation of costs.
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Sheet 2 of Exhibit G shows the design of rates for
Schedule Nos. A-8, A-7, GS-2, GS-1, PA-l, and-PA-2. As
noted above, these rates have been designed to recover the
costs allocated to these classes of service on Sheet 1,
Schedule D. The rates for Standby Service under Schedule
No. S have been designed to recover Vernon's cost of
rendering this service. The rate for the first 20 kW has
been increased from $2.16 per kW to $4.00 per kW to
contribute more toward the customer costs associated with
this service. The rate for all excess standby demand has
been set at $1.71 per kW, which represents Vernon's unit
fixed costs, as set-forth on Sheet 2 of Schedule C. The
rates for demands actually used has been set at Vernon's
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incremental costs of $9.25 per kW under Edison's Step 1
rates. The energy tlsed is to be billed at the energy rates
under the applicable rate schedule.
2. To Reflect Edison's Step 2 Increase in Rates -
As pointed out above, Edison's Step 2 rate increase to
Vernon will occur on the earlier of November 2, 1982 or the
date SONGS 2 becomes effective. To enable Vernon to reflect
The surcharge to the Special Contract Customers and to
this increase in its rates, we have designed surcharges to
become effective on September 1, 1982 if SONGS 2 is
operational at that time, or such later date as the STEP 2
rates become effective.
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Schedule Nos. A-8, A-7, and GS-2 to reflect the additional
cost of their on-peak demands is set forth on Sheet 3 of
Exhibit G. The surcharge of $1.754 per kW of on-peak demand
was calculated by dividing Vernon's increase in demand costs
of $5,049,000 by the sum of the 12 monthly system demands.
This unit surcharge was applied to the on-peak demands of
Bethlehem and Steel Casting to arrive at monthly surcharges
of $8,937 for Bethlehem and $1,491 fQr Steel Casting. Bee
Jay and Kinetic have no on-peak billing demands and
therefore receive no increase in their monthly charges under
the Step 2 increase, which is entirely in the demand
component.
The .637~/kWh unit surcharge applicable to the energy
purchased by customers in other classes, most of whom do not
have billing demands, was arriv~d at by subtracting the
annual demand surcharges to the Special Contract Customers,
Schedule Nos. A-8, A-7, and GS-2 customers from the Step 2
increase in demand cost and dividing by system annual kWh
sales, less sales to such customers. This calculation is
shown on Sheet 4 of Schedule No.1.
3. Comparison of the Level of Vernon Rates With the Level
of Edison's Rates -
It is not feasible to make a meaningful comparison
between the level of Vernon's rates with the level of
Edison's rates at this time. While such comparisons can be
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b. There is a fundamental difference between the
methodologies used by the FERC and the CPUC in the
processing of general rate increases. The CPUC
will analyze a rate proposal in detail prior to
allowing it to become effective. The rate that
does become effective is final and there will be no
refunds. The FERC, on the other hand, will allow
an increased rate to become effective, without much
analysis, but may require substantial refunds
made for any point-in-time during the period January 1,
1982 - January 2, 1983 such comparisons are meaningless
because of the various changes that are occuring, at
different times, in these rates. Some of these differences
are as follows:
a. Edison has realized substantial savings in the cost
of energy by purchasing energy from the Northwest
that was produced by hydro-plants. Edison reduced
its rates to Vernon, by reducing the charges under
its fuel clause adjustment, as these savings were
realized in the winter and spring of 1982. Edison
did not reduce its retail rates to reflect these
savings, however. Instead, the CPUC has allowed
Edison to "husband" these savings and use them to
allow for lower rates for the period of May 1982
through Decembe~ 1982.
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later. It is thus misleading to compare Edison's
retail rates with Vernon's rates because Vernon
will probably receive refunds that will flow back
to its customers. Vernon is now in the process of
refunding to its customers approximately $5 million
that Edison refunded to Vernon under the terms of
an order in Docket No. 76-205 with respect to an
Edison wholesale increase in 1916.
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c. Other differences exist with respect to the timing
of general rate increases, at the retail level, one
huge rate increase is to become effective on
January 1, 1983 and another is to follow on
January 1, 1984. At the wholesale level one rate
increase became effective June 2, 1982 and another
is to become effective on or shortly after
November 1, 1982. Another wholesale filing is to
be made in November. All of these rate increases
will be subject to refund.
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d. Edison will file surcharges to its retail rates to
reflect the cost of SONGS 2 and 3 and Palo Verde.
The surcharges (MAABF and AMAR) are to become
effective on in-service Date of SONGS 2 (August 15,
1982) to reflect this unit. Surcharges for the
other units will follow. With respect to the
wholesale rates, however, portions of the costs of
.
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all three units were included in the Step 1 rates
becoming effective June 2, 1982. All of the
SONGS 2 costs and increased portions of the other
two units will be included in the rates to be filed
in November.
IX. THE ENERGY COST ADJUSTMENT BILLING FACTOR
Vernon's existing rates include a component of
4.411~/kWh to recover the cost of Energy purchased from
Edison. These rates also contain an Energy Cost Adjustment
Clause under which Vernon tracks increase and decrease in
the energy component of the cost of its purchases from
Edison by applying an Energy Clause Adjustment Billing
Factor (ECABF) to its kWh sales of energy. Vernon presently
makes changes in its ECABF on a quarterly basis to reflect
the estimated cost of energy for the current period,
adjusted to reflect any over or under collections during the
prior period. This method is working very well and there
appears to be no reason to make substantive changess in such
methodology. All that is necessary is to set forth the
Energy Cost per kWh that is included in Base Rates. As
shown in Exhibit H, the cost of the energy Component of
purchases from Edison amounts to 5.185~/kWh. The existing
base cost of energy from which the ECABF is computed is
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4.411~/kWh, resulting in an increase of .774~/kWh in the
base cost. The change in the base energy rate does not
really change the cost of energy to the customer, of course.
It merely means that more of the cost of energy is to be
collected in the base energy rate and less is to be
collected in the ECABF.
Vernon has made arrangements to purchase interruptible
energy from Nevada Power Company, which may result in
substantial savings in the cost of energy purchases. Any
such savings realized will be flowed-through to the
customers in the ECABF.
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x. PURPA STANDARDS
While Vernon is not subject to the Public Utility
Regulatory Policies Act of 1978 (PURPA), this report
nevertheless addresses the various concerns of this
legistation. Sections 111 and 113 of PURPA provide for the
following standards:
1. Cost of Service
2. Declining Block Rates
3. Time-of-Day Rates
4. Seasonal Rates
5. Interruptible Rates
6. Load Management Techniques
7. Master Metering
8. Automatic Adjustment Clauses
9. Information to Consumers
10. Procedures for Termination of Electric Service
11. Advertising
This report has examined all of these standards to
determine what if any action Vernon should take so as to
meet its public service obligations. In some cases we
determined that no action was required because of the nature
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of the service area. In the remaining instances we have
concluded that steps taken by Vernon fully meet the
objectives and standards of the legislation.
1. Cost of Service
The Cost of Service Standard provides that the cost of
providing electric service to each class of electric
consumers shall to the maximum exten~ practicable -
1. Permit identification of differences in
cost-incurrence for each such class of electric
consumers, attributable to daily and seasonal time
of use of service; and
2. Permit identification of differences in
cost-incurrence attributable to differences in
customer, demand, and energy components of cost.
In prescribing such methods, such State regulatory
authority or nonregulated electric utility shall
take into account the extent to which total costs
to an electric utility are likely to change if--
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a. Additional capacity is added to meet peak
demand relative to base demand; and
b. Additional kilowatt-hours of electric
energy are delivered to electric
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consumers.
As discussed above, a cost allocation was made to
develop a cost of service for each customer class, using the
best information and techniques available. The rates
proposed herein are based upon the results of this
allocation.
The schedules under which service is rendered to the
larger customers do reflect time of use considerations.
Schedule Nos. A-8 and A-7 provide for an adjustment for
off-peak demand and special contracts have been negotiated
with some customers having the flexibility of operation that
make load management techniques workable.
2. Declining Block Rates
The PURPA Declining Block Rates Standard provides that:
"The energy component of a rate, or the amount
attributable to the energy component of a rate, charged
by any electric utility for providing electric service
during any period to any class of electric consumers
may not decrease as kilo-watt-hour consumption by such
class increases during such period except to the extent
that such utility demonstrates that the costs to such
utility of providing electric service to such class
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which costs are attributable to such energy component
decrease as such consumption increases during such
period."
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The rates proposed in this report do not contain
declining block~ in the energy component.
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3. Time-of-Day Rates
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The Time-of-Day Rates Standard provides: "The rates
charged by an electric utility for providing electric
service to each class of electric consumers shall be on a
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time-of-day basis which reflects the costs of providing
electric service to such class of electric consumers at
different times of the day unless such rates are not
cost-effective with respect to such class, as determined
under Section 115(b)".
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As pointed out above, the existing schedules A-8 and
A-7 provide for an adjustment in billing demands for maximum
demands taken during the off peak periods. In addition,
Vernon has exhibited a willingness to enter into special
contracts with customers who desire to institute load
management techniques. Upon installation of additional,
more sophisticated, metering equipment at the point of
delivery of more of its customers, Vernon will be able to
extend its efforts at load management. As pointed out in
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more detail at a later point, Vernon's sales to smaller
customers amount to a relatively small amount, making it not
cost effective to institute time-of-date rates for these
customers.
4. Seasonal Rates
The Seasonal Rates Standard provides: "The rates
charged by an electric utility for providing electric
service to each class of electric consumers shall be on a
seasonal basis which reflects the costs of providing service
to such class of consumers at different seasons of the year
to the extent that such costs vary seasonally for such
utility."
This report concludes that because of the relatively
small difference between the winter and summer monthly peaks
and the relatively small difference between costs during the
winter and summer periods, that there is little reason to
differentiate costs by season. This is particularly true
because of the rate structure of Vernon's sole supplier,
Edison. Vernon's billing demands upon which demand charges
payable to Edison are based, are set at the level of
Vernon's highest takes during the on-peak period of the day,
each month. There is no ratchet in these billing demands.
Thus, there is no basis for a seasonal demand charge.
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5. Interruptible Rates
The Interruptible Rates Standard provides that: "Each
electric utility shall offer each industrial and commercial
electric consumer an interruptible rate which reflects the
cost of providing interruptible service to the class of
which such consumer is a member."
The cost savings resulting from interruptible 3ervice
has been examined and discussed with potential customers
from time to time in the past, and there is customer
interest in this concept. However~ because Vernon purchases
its power and energy from Edison, this concept is feasible
only if Edison makes energy available to Vernon on an
interruptible basis. Vernon has proposed in its testimony
in Edison's FERC rate proceeding, Docket No. ER81-177, that
Edison be required to institute an interruptible rate for
its wholesale customers. If this effort is successful,
Vernon will make such rate available to its customers where
feasible.
6. Load Management Techni~ues
The Load Management Technique Standard provides that:
Each electric utility shall offer to its electric consumers
such load management techniques as the State regulatory
authority has determined will--
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1. be practicable and cost-effective,
2. be reliable, and
3. provide to the electric utility some enhancement in
its ability to manage energy or capacity.
It also provides that: a load management technique
shall be determined, by the State regulatory authority to be
cost-effective if--
a. such technique is likely to reduce maximum kilowatt
demand on the electric utility, and
b. the long-run cost-savings to the utility of such
reductions are likely to exceed the long-run costs
to the utility associated with implementation of
such technique.
As discussed above, Vernon has investigated Time-of-Day
Rates, Interruptible Rates and Special Contracts as a way to
control maximum demands.
These methods are considered to be the most effective
means available of achieving meaningful load management,
because of the nature of Vernon's loads. Vernon, being an
industrial City, has a relatively small number of customers,
most of which. however, are relatively large. Consequently,
it is feasible to deal with load management on an
individualized basis in areas where there is a potential for
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load management. Because of the relative small number of
customers, however, and the limited amount of sales to
smaller customers, it is not economically nor adminis-
tratively feasible to experiment with stlch techniques as
time-of- use rates for water heating as load management
techniques.
7. Master Meterina
The master Metering Standard provides that to the
extent determined appropriate, master metering of electric
service in the case of new buildings shall be prohibited or
restricted. Separate metering shall be determined
appropriate for any new building if--
1. There is more than one unit in such building.
2. The occupant of each such unit has control over a
portion of the electric energy used in such unit,
and
3. With respect to such portion of electric energy
used in such unit, the long-run benefits to the
electric consumers in such building exceed the
costs of purchasing and installing separate meters
in such building.
Because of the nature of Vernon's service area it is
unlikely that this provision will apply in the foreseeable
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1. The clause is reviewed at least every four years
by the State regulatory authority at an evidentiary
hearing to insure the clause provides incentives
for efficient use of resources by the utility, and
2. The clause is reviewed at least every two years
by the State regulatory authority at an evidentiary
hearing to insure the maximum economics in those
operations and purchases that affect the rates of
the utility. This review shall include an
examination of the practices of the utility which
relate to the costs included in the clause. In
appropriate cases, an audit of such costs may be
required.
future, and Vernon has therefore not adopted a policy in
regard to buildings where Master Metering might be an
option.
8. Automatic Adjustment Clauses
The provisions of the Automatic Adjustment Clause
Standard provides that an automatic adjustment clause meets
the requirements of the standard if--
Vernon's rates contain an automatic adjustment clause
which adjusts customer's bills up or down to reflect the
actual costs of fuel and purchased energy. Vernon is not
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subject to the jurisdiction of a State regulatory authority
and, consequently, its clause has not received such state
regulatory approval. Vernon's automatic adjustment clause
is, however, similar to clauses of investor-owned systems
that have been approved by state and federal regulatory
agencies. Vernon's automatic adjustment clause is thus
~onsistent with the intent of the legislation.
9. Information to Consumers
The Information to Consumers Standard provides that
each electric utility shall transmit to each of its electric
consumers certain information regarding rate schedules.
Vernon's program of providing information to its customers
includes all of the necessary rate schedule information.
10. Procedures for Termination of Electric Service
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This Standard provides that no electric utility may
terminate electric service to any electric consumer except
pursuant to procedures prescribed by the State regulatory
authority. Vernon has adopted procedures similiar to those
utilized by privately owned systems, including Edison, that
have been approved by state regulatory agencies.
11.
Advertising
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The Advertising Standard provides that no electric
utility may recover from any person other than the
shareholders (or other owners) of such utility any direct or
indirect expenditures by such utility for promotional or
political advertising. Vernon does not advertise its
electric service.
XI. CONCLUSION
In our opinion, the rates proposed herein will allow
Vernon to recover its cost-of-service from its customers in
a fair and equitable manner and complies with the intent of
PURPA.
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Exhibit A
Sheet 1 of 1
City of Vernon
Comparison of Costs With Revenues
Twelve Months Ending March 31, 1982
(OOO's)
Cost of
Total Purchases
Revenues From Edison Remainder
Including Including
ECAC Rev. ECAC Charges
A B C D
1 April 1981 $ 5,880 $ 5,427 $ 453
2 May 5,369 5,114 255
3 June 5,269 5,090 179
4 July 5,561 6,188 <627>
5 August 5,544 4,560 984
6 September 5,662 4,944 718
7 October 5,978 7,411 <1,433>
8 November 6,327 6,368 <41>
9 December 6,442 5,408 1,034
10 January 1982 6,235 4,647 1,588
1 1 February 6,190 4,469 1,721
12 March 6,639 4,574 2,065
13 Total $71,096 $64,200 $6,896
14 Increase In ECAC Reserve <1,162> <1,162>
15 Net $69,934 $64,200 $5,734
Sources:
Column B: Computer printout showing Billing Data by Rate
Schedule.
Column C: Edison Bills to Vernon.
Line 14: W/P A-l.
Exhibit B
Sheet 1 of 4
City of Vernon
Comparison of Revenue Requirements
Actual Year vs. Estimated Under Edison's Step 1 Rates
(OOO's)
Ac t ua 1 Estimated
Expenses Expenses
as Adjusted w/Ste~ 1 Rates
A B C
Cost of Power and Ene.rgy $65,961 $18,483
2 Contracted Service 302 425
3 Miscellaneous 65 116
4 Operating Agreement 1,494 2,500
5 Depreciation 398 400
6 Return 527 536
7 Total Revenue Requirements 1 $68,747 $82,460
Sources:
Col. B, Line 1: Cost of Purchases for year ending March 31,
1982 from Sheet 2.
Col. B, Lines 2-5: Cityof Vernon Statement of Revenue and
Expenses for year ending January 31, 1982.
Col. B, Line 6: Average Rate Base @ 11.2$.
Col. C, Line 1: Power and energy purchased during year ended
March 31, 1982 priced at Step 1 rates to be
effective June 2, 1982.
Col. C, Lines 2-5: City of Vernon proposed budget for
1982-1983. (W/P B-4).
Col. C, Line 6: Average Rate Base @ 11.2$ Rate of Return.
1
Does not include payment in lieu of franchise fee.
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Exhibit B
Sheet 2 of 4
City of Vernon
Cost of Purchases From Edison
Under Existing Rates
Existing
Units Rates Amount
(OOO's)
A B C D
1 1st 500 kW 6,000 $3,950 $ 47
2 Next 1,500 kW 18,000 7.50 135
3 Next 8,000 kW 96,000 7.40 710
4 All Excess 1,866,096 7.08 13,212
5 Total 1,986,096 $14,104
6 Voltage Discount $ .32 <636>
7 Power Factor Adj. 100 11
8 Vernon City Hall <11>1 _
9 Subtotal $13.557
10 Energy (mWh) 1,213.974.2 4.3229! $52,468 2.J
1 1 Vernon City Hall <64>
12 Subtotal $52,404
13 Total $65,961
Sources:
Col. A, Line 5: W/P B-1. Billing Demands include the
projected on-peak demands only of the
special contract customers.
Col. A, Line 9: W/P B-2.
Col. C: Rates from filing in Docket No. ER81-177.
Col. D, Lines 6, 7 & 10: W/P B-2.
Jl
Total City Hall
Demand @ 15 ~
Energy @ 85 ~
$75
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64
Exhibit B
Sheet 3 of 4
City of Vernon
Cost of Purchases From Edison
Under Step 1 Rates
Step 1
Units Rates Amount
(000'5)
A B C D
1 1st 500 kW 6,000 $ 5,650 $ 68
2 Next 1.500 kW 18,000 10.80 194
3 Excess 1,962,096 9.45 18,542
4 Total Demand 1,986,096 $18,804
5 Voltage Discount $ .30 <596>
6 Power Factor Adj. 100
7 Vernon City Hall < 11 >11
8 Subtotal $18,297
9 Energy (mWh) 1,213,974.2 4.963~ $60,250 11
10 Vernon City Hall <64>
11 Subtotal $60,186
12 Total $78,483
CO
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Sources:
Col. A, Line 5: W/P B-1. Billing Demands include the
projected on-peak demands only of the
special contract customers.
Col. A, Line 9: W/P B-2.
Col. C: Step 1 rates from filing in Docket No. ER82-47.
Col. D, Lines 6, 7 & 10: W/P B-2.
j/ Total Ci ty Hall
Demand @ 15 S
Energy @ 85 S
$15
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Exhibit B
Sheet 4 of 4
City of Vernon
Cost of Purchases From Edison
Under Step 2 Rates
Step 2
Units Rates Amount
(OOO's)
A B C D
1 1st 500 kW 6,000 $ 6,650 $ 80
2 Next 1,500 kW 18,000 12.65 228
3 Excess 1,962,096 12.00 23,545
4 Total Demand 1,986,096 $23,853
5 Voltage Di scoun t $ .30 <596>
6 Power Factor Adj. 100 JJ
7 Vernon City Hall < 11>
8 Subtotal $23,346
9 Energy (mWh) 1,213,974.2 4.963t $60,250y
10 Vernon City Hall <64>
1 1 Subtotal $60,186
12 Total $83,532
Sources:
Col. A, Line 5: W/P B-1/ Billing Demands include the
projected on-peak demands only of the
special contract customers.
Col. A, Line 9: W/P B-2.
Col. C: Step 1 rates from filing in Docket No ER82-47.
Col. D, Lines 6, 7 & "10: W/P B-2.
11 Total City Hall
Demand @ 15 ~
Energy @ 85 ~
$75
1 1
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Exhibit C
Sheet 1 of 4
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Exhibit C
Sheet 2 of 4
City of Vernon
Development of Fixed Costs for
Special Contract Customers
Amount
(OOO's)
Vernon's Fixed Costs
1 Contracted Services
2 Miscellaneous
3 Operating Agreement
4 Depreciation
5 Return
6 In Lieu Payment
7 Total Costs
$ 425
116
2,500
400
536
2,550
$6,527
2,818
<57>
648
96
216
30
3,811
$ 1. 71
Vernon's System Demands
8 Total System Demand
9 Spec. Cust. Excess over on-peak
10 Additional Firm - Bethlehem
11 Bee Jay
12 Kinetic
13 Steel Casting
14 To~al (mW)
15 Unit Cost per kW
Sources:
Lines 1-5: Exhibit B, Sheet 1.
Line 6: Total costs less In-Lieu Payment equals
$82,460,000 (Exhibit B, Sheet 1). In-Lieu
Payment = .03 x (82,460,OOO).
Line 8: Sheet 3.
Line 9: Excess of peaks of Special Contract Customers
over on-peak demands included in Line 8 demands.
(W/P B-1).
Lines 10, 11 & 12: Excess of Special Customer off-peak
demands over on-peak demands x 12.
IV)
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Sheet 3 of 4
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Exhibit C
Sheet 4 of 4
City of Vernon
Development of Energy Charges For
Special Contract Customers
Step 1 Rates
De 1 i v e r y Loss Edison Vernon
Voltage Factor Rate Rate
A B C D E
Bethlehem 66 kV 1.01 4.963tt 5.013t
Kinetic 66 kV 1. 02 4.963t 5.062t
Bee Jay 4 kV 1.06 4.96315 5.261t
Steel Casting 66 kV 1. 02 4.963t 5.062t
Sources:
Column D: W/P D-3.
Exhibit D
Sheet 1 of 2 ~
City of Vernon
Allocation of Cost of Service
Vernon's Costs Under Edison's Step 1 Rates
Demand Energy Total
Schedules Units Amount Units Amount Amount
kW-Mo. mWh
A B C D E F
1 A-8 1,349,269 $ 9,696,755 607,922.5 $31,472,975 $41,169,730
2 A-7 761,194 5,470,452 244,007.0 12,632,574 18, 103,026
3 GS-2 569,142 4,090,238 131,176.7 6,791,196 10,881,434
4 GS-1 43,376 311,729 7,916.2 409,832 721,561
5 D 672 4,829 122.7 6,352 11,181
6 PA-1 11,436 82, 187 4,174.3 216,109 298,296
7 PA-2 9.154 65,786 1.818.0 94,120 159,906
8 TC-1 2,880 20,698 525.7 27,216 47,9143
9 Total 2,747,123 $19,742,674 997.663.1 $51,650,376 $71,393.051
10.._"., Spec. Con t . 113 . 521 $ 2, 300, 000 165.287.0 $ 8,290,000 $10,590,000
J~. .'LS-1 6,417 92,072 2,612.6 134,657 226.729
12' LS-2 639 5,045 256.5 13,220 18,265
13 OL-1 10,369 109,596 1,892.4 97,537 207,133
14 Total 2,878,069 $22,249,388 1, 167.711.6 $60,185,790 $82,435,178
)ources:
Column B: Exhibit C, Sheet 3.
Column C, Line 9-13: Exhibit D, Sheet 2.
Column D: Exhibit C, Sheet 3.
Column E, Line 9-13: Exhibit D, Sheet 2.
. Exhibit D
Sheet 2 of 2
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Exhibit E
Sheet 1 of 3
City of Vernon
Special Conditions to Add to
Schedule Nos. A-8. A-7. and GS-2
Excess Transformer Capacity: The transformer capacity
in excess of a customer's contract demand which is either
required by the Company because of the nature of the
customer's load or requested by the customer. Excess
transformer capacity shall be billed at $1.00 per kVA per
month.
Contract Demand: A contract demand will be established
by the Company, based on applicant's demand requirements for
any customer newly requesting service on this schedule and
for any customer of record on this schedule who requests an
increase or decrease in transformer capacity in accordance
with Rule No. 120. A contract demand arrangement is
available upon request for all customers of record on this
schedule. Contract demand is based upon the nominal
kilovolt-ampere rating of the Company's serving
transformer(s} or the standard transformer size determined
by the Company as required to serve the customer's stated
measurable kilowatt demand, whichever is less and is
expressed in kilowatts.
Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall be
computed by multiplying the billing demand by the demand
charge per kilowatt. Where a contract demand is involved.
the monthly minimum demand charge shall be the greater of:
a. The charge as computed by multiplying the billing
demand by the demand charge per kilowatt; or
b. A facilities charge of $1.00 per kilowatt of
contract demand.
I
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Exhibit E
Sheet 2 of 3
City of Vernon
Special Condition to Add to
All Rate Schedules
Other than Special Contracts
In-Lieu Payments: The amount payable under the rates
filed herin shall be multiplied by 1.03 to reflect payments
in-lieu of a franchise fee.
.
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.
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.
.
Exhibit E
Sheet 3 of 3
City of Vernon
Procedures for Calculating the
Amount of Refunds to be Retained
A deferred account shall be established in which to
accumulate Vernon's additional costs and associated interest
resulting from Southern California Edison's increased rates
in ~ocket No. ER82-427 becoming effective prior to the
increase in Vernon's rates. The deferred amount is to be
computed by multiplying Vernon's billing demandsiduring the
months of June, July, and August by $2.35 per kW of billing
demand, which is the approximate average increase in the
demand ~harge resulting from the Step 1 increase. Interest
on this amount shall be computed at the interest rate which
the FERC requires Edison to pay on its refunds to Vernon.
The amount accumulated in this deferred account is to be
deducted from any refunds which Vernon receives from Edison
in Docket No. ER82-427 prior to flowing such refunds through
to Vernon's customers.
Exhibit F
Sheet 2 of 2
v
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Exhibit G
Sheet 1 of 3
City of Vernon
Revenues @ Existing Rates,
Revenues @ the Proposed Rates
and the Resulting Increase
Revenues @ Revenues @
Schedule No. Existing Rates Froposed Rates Increase
A B C D
1 A-8 $36,004,623 $42.469,386 $ 6,464,763
2 A-7 15,617,899 18,617,479 2.999,580
3 GS-2 9,235,079 11,195,385 1,960,306
4 GS-l 690,785 742,017 51,232
5 PA-1 261,560 306,515 44.955
6 PA-2 120,135 164,449 44,314
7 TC-l 37,875 45,264 7,389
8 D 7,769 7,924 155
9 LS-l 234,012 258,066 23,994
10 LS-2 6,026 7,530 1,504
1 1 OL-1 611,206 735,667 58,461
12 Total $62,893,029 $74,481,493 $11.588,464
Sources:
Lines 1 _ 6: Exhibit G, Sheet 2 (Column C has been adjusted
to include in-lieu payment by multiplying Colum
E, Sheet 2 totals by 1.03093).
Lines 7 - 8: W/P G-2.
Line 9: W/P G-12.
Line 10: W/P G-13.
Line 11: W/P G-11.
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Exhibit G
Sheet 2 of 3
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. Exhibit G
Sheet 3 of 3
I City of Vernon
Development of Surcharge for
Step 2 Rate Increase
Schedule Demands Amount Surcharge
A B C D
1 Spec. Cont. 113.521 $ 199,150
2 A-8 1,349,269 2,367,023
3 A-7 761,194 1,335,363
4 GS-2 569,142 998,446
5 GS-1 43,376 76,094
6 D 672 1,179
7 LS-1 6,417 11,257
8 LS-2 639 1,129
9 OL-l 10,369 18,190
10 PA-1 11,436 20,062
11 PA-2 9,154 16,059
12 TC-1 2,880 5,052
13 Total 2.878,071 $5,049,000
Demand Surcharge
Spec. Con t . , A-8
14 A-7 and GS-2 2,774,422 4,899.981 $1.766
15 Net for Energy Surcharge $ 149,019
16 kWh for Remaining Sch. 18,651 .799~
Sources:
Line 16:
Line 14,
Exhibit C, Sheet 3.
Line 13: Di fference
Sheets 3 &
Exhibit C, Sheet 3.
Column B: Exhibit C,
Between Exhibit B,
4.
Column B:
Column C,
Sheet 3.
City of Vernon
Base Rate For
Energy Cost Adjusstment
A
1 Energy Purchases from Edison
2 Edison Energy Rate
3 Cost of Energy Purchase
4 Vernon Sales
5 Base Cost of Energy
6 Existing Base Cost
7 Increase in Base Cost
Sources:
~..
;
"
Li ne 1:
Line 2:
Line 4:
Exhibit H
Sheet 1 of 4
B
1,21],974,200 kWh
.04963 $/kWh
$60,249,540
1,162,058,349 kWh
5. 185tlkWh
4.41 h! /kWh
.774t!/kWh
Exhibit B, Sheet 3.
Step 1 Rates in Docket No. ER82-47.
Exhibit C, Sheet 3.
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Exhibit H
Sheet 2 of 4
City of Vernon
Procedures for Calculating the
Energy Clause Adjustment Billing Factor
The rate schedules contained herein are to contain, in
addition to the base rates included in the current tariff,
an Energy Clause Adjustment Billing Factor (ECABF) to
reflect changes in the cost of fuel and purchased energy.
The ECABF is to be calculated pursuant to the following
equation:
ECABF =
EC + C
e
- B
S
e
Where,
ECABF = Energy Cost Adjustment Billing Factor per Kilowatt
Hour Sold
EC
e
= Estimated Fuel and Energy Costs for the Current
Period
C
= Correcti~n for Previous Period's Over- or Under-
recovery
= Estimated Kilowatt hours to be Sold in Current
Period
Se
B
= Energy Cost per Kilowatt Hour included in Base
Rates =5.185~/kWh
1
If the previous period average costs were less than
5.185~ per kWh, C is negative. If such average ~osts
were greater than 5.185~ per kWh, C is positive.
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Exhibit H
Sheet 3 of 4
Energy Clause Adjustment Billing Factor
(Continued)
ECA Computation Sheet
Schedule V-1 is attached to provide the computation sheet
for all periods once implementation is completed.
Estimated Energy Costs (ECel
Items 1 through 3 represent the estimated energy costs which
are to be used iin computing the period's ECA. This is an
estimate of the costs the City expects to incur for the
three month period to which this ECA will apply. It is
comprised only of commodity or energy costs in keeping with
standards only of commodity or energy costs in keeping with
standards established by the Federal Energy Regulatory
Commission and various state regulatory bodies.
To calculate items l(a) and 1(b), the City must obtain
estimates from Edison of the kilowatt hours expected to be
sold to the City of Vernon during the period the ECA will be
in effect. Edison must also provide an estimate of the ECA
that they will be charging the City during that period.
Line 2 would be comprised of estimated fuel costs required
to operate t~e City's generating units. This charge would
be designated on the billing for operating expenses as being
charged to FERC account 547, Fuel. At the outset there will
probably be no cost associated with this line item. However
it will become a factor when the units become operational
once again.
Line 3 represents an estimate of the cost of interruptible
energy to be purchased during the period the ECA will be in
effect.
Correction Factor
Lines 4 through 7 of the computation sheet are used to
calcualte the amount needed to correct for over- or under-
recovery of energy costs in previous periodS. Line 4
represents a true-up of the previous period'S estimate of
energy costs on Lines 1 and 2. These amounts can be taken
from the billings of Edison both for purchased power and for
fuel used by the Vernon generating units for the appropriate
periods being corrected.
Because there is a delay in the availability of expense and
revenue data for individual months, the period for which a
correction factor is calculated will lag behind by one
month.
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City of Vernon
Energy Cost Adjustment
Computation Sheet
For Three Months Ending
Exhibit H
Sheet 4 of 4
19
Estimated Energy Costs
1. Purchased Power from SCE
(a) Energy Charge
(b) Energy Cost Adjustment
2. Generation Fuel Costs (Account 547)
3. Costs of In terr upt i b 1 e Purchases
4. Total Energy Costs (1 +2+3)
Correction Factor
5. Actual Energy Expenses for
Previous Period
6. Unrecovered Energy Ex penses
from Previous Periods
7. Less: Billed Base Rate and ECA
Revenues from Previous Period
8. Unrecovered (Over-recovered)
Energy Expenses {4+5-6}
9. Total Costs to be Recovered (3+7)
Calculation ~f Factor
10. Estimated Kwhr Sales
11. Total Energy Cost per Kwhr
(8+9)
12. Less: Amount in Base Rates
13. Energy Cost Adjustment Factor
( 10-11 )
$
$
$
$
$
$
$
$
$
$
$ .05185
$
All kWh t . per kWh........... .. . . . . . . . . . . . . . . . .
8.892~
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Schedule No. GS-l
GENERAL SERVICE
APPLICABILITY
Applicable to single- and three-phase general service including
lighting and power. This schedule is not applicable when, in the
opinion of the Company, the customer's load and use characteristics
indicate that-the maximum demand may exceed 20 kW.
TERRITORY
Within the city limits of the City of Vernon.
RATES Per Meter
Per Month
Customer Charge..............................$ 4.90
Energy Charge (to be added to Customer Charge):
Minimum Charge:
The monthly minimum charge shall be the
monthly Customer Charge.
SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard voltage.
2. X-Ray Installations: Where the Company installs the standard
transformer capacity requested by a customer to serve separately an
X-ray installation, the customer charge will be increased by $1.00 per
kVA of transformer capacity requested.
3. Temporary Discontinuance of Service: Where the use of energy
is seasonal or intermittent, no adjustments will be made for a
temporary discontinuance of service. Any customer prior to resuming
service within twelve months after such service was discontinued will
be required to pay all charges which would have been billed if service
had not been discontinued.
4. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary Statement.
The applicable energy cost adjustment billing factors and fuel
collection balance adjustment billing factor set forth therein will be
applied to kWh billed under this schedule.
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Schedule No. GS-2
GENERAL SERVICE
APPLICABILITY
Applicable to single- and three-phase general service including
lighting and power.
TERRITORY
Within the city limits of the City of Vernon.
RATES
Per Meter
Demand Charge: Per Month
First 20 kW or less of billing demand.... $116.00
All excess kW of billing demand, per kW.. $ 5.82
Energy charge (to be added to Demand Charge): 5.92c
Minimum Charge:
The monthly minimum charge shall be the monthly Demand
Charge.
SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard voltage.
2. Billing Demand: Billing demand shall be the kilowatts of
maximum demand but not less than 50% of the highest maximum demand
established in the preceding elevent months, however, in no case shall
the billing demand be less than 20 kW. Billing demand shall be
determined to the nearest 1/10 kW.
3. Maximum Demand: The maximum demand in any month shall be the
measured maximum average kilowatt input, indicated or recorded by
instruments to be supplied by the Company, during any 15-minute
metered interval in the month, but shall not be less than the
diversified resistance welder load computed in accordance with the
section designated Welder Service in Rule No.2.
4. X-Ray Installations: Where the Company installs the standard
transformer capacity requested by a customer to serve separately an
X-Ray installation, the minimum charge will be increased by $1.00 per
kVA of transformer capacity requested.
5. Temporary Discontinuance Service: Where the use of energy is
seasonal or intermittent, no adjustments will be made for a temporary
discontinuance cf service. Any customer prior to resuming service
within twelve months after such service was discontinued will be
required to pay all charges which would have been billed if service
had not been discontinued.
(Continued)
(Cont inued)
Schedule No. GS-2
GENERAL SERVICE
6. Energy Cost Adjustment: The rates above are subject to ad-
justment as provided for in Part G of the Preliminary Statement.
The applicable energy cost adjustment billing factors and fuel col-
lection balance adjustment billing factor set forth therein will be
applied to kWh billed under this schedule.
7. Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either required by
the Company because of the nature of the customer's load or
requested by the customer. Excess transformer capacity shall be
billed at $1.00 per kVA per month.
8. Contract Demand: A contract demand will be established by
the Company, based on applicant's demand requirements for any
customer newly requesting service on this schedule and for any
customer of record on this schedule who requests an increase of
decrease in transformer capacity in accordance with Rule No. 12D.
A contract demand arrangement is available upon request for all
customers of record on this schedule. Contract demand is based
upon the nominal kilovolt-ampere rating of the Company's serving
transformer(s} or the standard transformer size determined by the
Company as required to serve the customer's stated measurable
kilowatt demand, whichever is less and is expressed in kilowatts.
9. Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall be computed by
multiplying the billing demand by the demand charge per kilowatt.
Where a contract demand is involved, the monthly minimum demand
charge shall be the greater of:
a. The charge as computed by multiplying the billing demand
by the demand charge per kilowatt; or
b. A facilities charge of $1.00 per kilowatt of contract
demand.
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Sched <lIe No. A-7
GENE HAL SERVICE
APPLICABILITY
Applicable to single- and three-phase general service including
lighting and power.
TERRITORY
Within the city limits of the City of Vernon.
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RATES
Per Meter
Demand Charge: Per Month
First 200 kWof less of billing demand.........$1,200.00
All excess kW of billing demand, per kW........$ 6.00
Energy Charge (to be added to Demand Charge):....
5.6095
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Minimum Charge:
The monthly minimum charge shall be the monthly Demand Charge.
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SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard voltage.
2. Billing Demand: The billing demand shall be the kilowatts of
maximum demand but not less than 501 of the highest maximum demand
established in the preceding eleven monthS, however, in no case shall
the billing demand be less than 200 kW. Billing demand shall be
determined to the nearest kW.
3. Maximum Demand: The maximum demand in any month shall be the
measured maximum average kilowatt input, indicated or recorded by
instruments to be supplied by the Company, during any 15-
minute metered interval in the month, but shall not be less than the
diversified resistance welder load computed in accordance with the
section designated Welder Service in Rule No.2. Where the demand is
intermittent or subject to violent fluctuations, a 5-minute interval
may be used.
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4. Voltage Discount: The charges before adjustments will be
reduced by 31 for service delivered and metered at voltages of from 2
kV to 10 kV; and by 5% for service delivered and metered at voltages
over 50 kV; except that when only one transformation from a
transmission voltage level is involved, a customer normally entitled
to a 31 discount will be entitled to a 4~ discount.
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(Cont inued )
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(Cont,
Schedule No. A-7
GENERAL SERVICE
SPECIAL CONDITIONS (Continued)
10. Excess Transformer Capacitx: The transformer capacity in
excess of a customer's contract demand which is either required
by the Company because of the nature of the customer's load or
requested by the customer. Excess transformer capacitY shall be
billed at $1.00 per kVA pel. month.
11. Contract Demand: A contract demand will be established
by the Company, based on applicant's demand requirements for any
customer newly requesting service on this schedule and for any
customer of record on this schedule who requests an increase or
decrease in transformer capacity in accordance with Rule No. 12D.
A contract demand arrangement is available upon request for all
customers of record on this schedule. Contract demand is based
upon the nominal kilovolt-ampere rating of the Company's serving
transformer(s) or the standard transformer size determined by the
Company as required to serve the customer's stated measurable
kilowatt demand. whichever is less and is expressed in kilowatts.
12. Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall be computed by
multiplying the billing demand by the demand charge per kilowatt.
Where a contract demand is involved, the monthly minimUM demand
charge shall be the greater of:
a. The charge as computed by multiplying the billing
demand by the demand charge per kilowatt; or
b. A facilities charge of $1.00 per kilowatt of contract
demand.
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Schedule No. A-8
GENERAL SERVICE-LARGE
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APPLICABILITY
Applicable to general service, including lighting and power.
This schedule is applicable for all customers of record on April 3,
1980 and thereafter to all customers whose monthly maximum demand
exceeds 1,000 KW for all three months during the preceding 12 months.
Any customer whose monthly maximum demand has fallen below 900 KW for
12 consecutive months may elect to take service on any other
applicable schedule.
TERRITORY
Within the city limits of the City of Vernon.
RATES
Demand Charge:
First 1000 KW or less of billing
All excess KW of billing demand,
Per Meter
Per Month
demand.......$5,418.00
per KW.......$5.418
Energy Charge (to be added to Demand Charge):... 5.580t
Minimum Charge:
The monthly minimum charge shall be the monthly Demand
Charge.
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SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard
vol tage .
2. Billin~ Demand: The billing demand shall be the kilo
watts of maximum demand but not less than 50~ of the highest maximum
demand established in the preceding 11 months, however, in no case
shall the billing demand be less than 1000 KW. Billing demand shall
be determined to the nearest KW.
3. Maximum Demand: The maximum demand in any month shall be
measured maximum average kilowatt input indicated or recorded by
instruments to be supplied by the Company, during any 15-minute
metered interval in the month, but not less than the diversified
resistance welder load computed in accordance with the section
designated Welder Service in Rule No.2. Where the monthly demand
exceeds 5000 KW per month, the maximum demand shall be based on a
30-minute interval. Where the demand is intermittent or subject to
violent fluctuations, a 5-minute interval may be used.
(Continued)
(Cont inued)
Schedule No. A-8
GENERAL SERVICE
SPECIAL CONDITIONS (Continued)
. 8. Contracts: An additional initial three-year facilities
contract may be required where Applicant requires new or added
serving capacity exceeding 2,000 KVA.
9. Customer's Right to Terminate: In the event the net bill
for electric service to the customer is increased during the term
of the requirements contract, provided for herein, 'as a result of
changes in this schedule, the customer shall have the right to
terminate the requirements contract on not less than 30-months
notice to the utility. Ssuch notice shall be given within 180
days after the effective date of such change.
10. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary Statement.
The applicable energy cost adjustment billing factors andd fuel
collection balance adjustment billing factor set forth therein
will be applied to KWHR billing under this schedule.
11. Excess Transformer Capacity: The transformer capacity in
excess of a customer's contract demand which is either required by
the Company because of the nature of the customer's load or
requested by the customer. Excess transformer capacity shall be
billed at $1.00 per kVA per month.
12. Contract Demand: A contract demand will be established by
the Company, based on applicant's demand requirements for any
customer newly requesting service on this schedule and for any
customer of record on this schedule who requests an increase or
decrease in transformer capacity in accordance with Rtlle No. 12D.
A contract demand arrangement is available upon request for all
customers of record on this schedule. Contract demand is based
upon the nominal kilovolt-ampere rating of the Company's serving
transformer(s) or the standard transformer size determined by the
Company as required to serve the customer's stated measurable
kilowatt demand, whichever is less and is expressed in kilowatts.
13. Minimum Demand Charge: Where no contract demand is
involved, the monthly minimum demand charge shall be computed by
multiplying the billing demand by the demand charge per kilowatt.
Where a contract demand is involved, the monthly minimum demand
charge shall be the greater of:
a. The charge as computed by multiplying the billing
demand by the demand charge per kilowatt; or
b. A facilities charge of $1.00 per kilowatt of contract
demand.
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Schedule No. D
DOMESTIC SERVICE
APPLICABILITY
Applicable to domestic service including lighting, heating, cooking
and power or combination thereof in a single-family accommodation;
also to domestic farm service when supplied through the farm
operat6r's domestic meter.
TERRITORY
Within the city limits of the City of Vernon.
RATES
Per Meter Per Month
Domestic Service
Customer Charge............................$
$ 1 . 50
Energy Charge (to be added to Customer
3.60t
Charge): ..................................
Minimum Charge:
The monthly minimum charge shall be the
monthly Customer Charge.
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SPECIAL CONDITIONS
1. Seasonal Service: For summer cottage customers and others who
normally require service for only part of the year, the schedule is
applicable only on annual contract.
2. Energy Cost Adjustment: The rates above include the adjustment
as provided for in Part G of the Preliminary Statement.
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Schedule No. LS-1
Energy Curtailment Service
Midnight or
Equivalent Facili ties
Service Charge
Per Lamp Per Lamp
Per Month Per Month
$ 6.73 $ 5.10
7.76 5.10
9.70 5.75
12.74 6.05
18.00 6.40
24.26 6.45
$ 6.92 $ 5.35
7.54 5.50
8.86 6.00
9.93 6.35
10.59 6.40
13.57 6.70
LIGHTING-STREET AND HIGHWAY
UTILITY-OWNED SYSTEM
APPLICABILITY
Applicable to street and highway lighting service supplied from
overhead lines where the Company owns and maintains the street
lighting equipment.
TERRITORY
Within the city limits of the City of Vernon.
RATES
All Night Service
Lamp Size-Lumens
Per Lamp
Per Month
MERCURY VAPOR LAMPS
3,500 Lumens..............$
7,000 Lumens..............
11,000 Lumens..............
20,000 Lumens..............
35,000 Lumens..............
55,000 L~ens..............
7.91
10.18
13.35
19.12
29.60
42.62
HIGH PRESSURE SODIUM VApOR LAMPS
5,800 Lumens..............$ 7.69
9,500 L~ens.............. 8.87
16,000 Lumens.............. 11.02
22,000 Lumens.............. 12.86
25,500 Lumens.............. 14.04
47,000 Lumens.............. 19.70
(Continued)
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Schedule No. LS-2
LIGHTING-STREET AND HIGHWAY
CUSTOMER-OWNED INSTALLATION
APPLICABILITY
Applicable to service for the lighting of streets, highways,
other public thoroughfares, and publicly-owned and publicly- operated
automobile parking lots which are open to the general .public, where
the customer owns the street lighting equipment.
TERRITORY
Within the city limits of the City of Vernon.
RATE A-UNMETERED SERVICE:
All Night
Multiple
For each kW of lamp load, per kW..$26.19
RATES
Per
Service
Series
$34.06
Month
Midnight
Multiple
$15.23
Service
Series
$18.51
RATE B-UNMETERED SERVICE: Per Meter
Meter Charge: Per Month
Multiple Service.............................$ 4.50
Series Service............................... 12.00
Energy Charge (to be added to Meter Charge):
All kWh', per kWh............................. 7.03t
RATE C-UNMETERED SERVICE-OPTIONAL:
In addition to the Rate A and Rate B charges
Lamp Rating
Lumens
1 , 000
2,500
4,000
6,000
10,000
3,500
7,000
11,000
20,000
35,000
55,000
5,800
9,500
16,000
22,000
25,500
47,000
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Per Lamp
Lam~ Type Per Month
Incandescent Extended Service......$ 0.33
Incandescent Extended Service...... 0.38
Incandescent Extended Service...... 0.40
Incandescent Extended Service...... 0.42
Incandescent Extended Service...... 0.45
Mercury Vapor...................... 0.36
Mercury Vapor...................... 0.33
Mercury Vapor...................... 0.40
Mercury Vapor...................... 0.36
Mercury Vapor...................... 0.54
Mercury Vapor...................... 0.49
High Pressure Sodium Vapor......... 0.80
High Pressure Sodium Vapor......... 0.80
High Pressure Sodium Vapor......... 0.78
High Pressure Sodium Vapor......... 0.79
High Pressure Sodium Vapor......... 0.79
High Pressure Sodium Vapor......... 0.81
(Continued)
7,000 Lumens. . . . . . .
20,000 Lumens. .
. $10.23
$20.26
$ 7.81
$1 3. 35
$5. 15
$6.10
Sched ule No. OL-1
OUTDOOR AREA LIGHTING SERVICE
APPLICABILITY
Applicable to outdoor area lighting service, other than street
and highway lighting service, supplied from overhead lines where the
Company owns and maintains the area lighting equipment.
TERRItORY
Within the City limits of the City of Vernon.
RATES
LUMINAIRE CHARGE: ENERGY CURTAILMENT SERVICE
MIDNIGHT OR
EQUIVALENT FACILITIES
ALL NIGHT SERVICE SERVICE CHARGE
LAMP SIZE-LUMENS
PER LAM P
PER MONTH
PER LAt4P
PER MONTH
PER LAM P
PER MONTH
*
MERCURY VAPOR LAMPS
HIGH PRESSURE SODIUM VAPOR LAMPS
5,800 Lumens. .
9, 500 Lumens. .
22,000 Lumens.
. . . .
$ 7.74
$ 8.92
. $12.91
$ 6.97
$ 7.58
$ 9.98
$5.40
$5.55
$6.40
POLE CHARGE (to be added to
Luminaire Charge):
PER POLE
PER MONTH
For each additional new wood pole installed.
. $ 2.59
.Closed to new installations as of February 1, 1980.
SPECIAL CONDITIONS
1. Area all night lighting service waill be furnished from dusk to
dawn, approximately 4,140 hours per year, by Company- owned luminaries
supplied from the Company'sexisting 120/240 volt overhead circuits and
mounted on existing Company-owned wood poles as standard equipment.
2. Where the customer requests the installation of other than the
standard equipment furnished by the Company and such requested
(Continued)
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Schedule No. PA-l
POWER-AGRICULTURAL AND PUMPING
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CONNECTED LOAD BASIS
APPLICABILITY
Applicable to power service for general agricultural purposes or
for general water or sewerage pumping.
TERRITORY
Within the city limits of the City of Vernon.
RATES
Monthly
Service Charge
Per Meter
Horsepowe!~ of
Connected Load
Per Meter
Per hE
2 and over
$1.00
Energy Charge to be added to Service Charge-Rate
PerKW"H: . . . . . . . . . . . . . . . . . . . ... . . . . . . . . . . . . . . . . . . .
6.729t
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Minimum Charge: The annual minimum charge shall be the annual
Service Charge.
SPECIAL CONDITIONS
1. Volta~e: Service will be supplied at one standard power
voltage.
2. Connected Load: Connected load is the sum of the rated
capacities of all of the customer's equipment that it is possible to
connect to the Company's lines at the same time, determined to the
nearest 1/10 hp. In no case will charges be based on less than 2 hp
for single-phase service or no less than 3 hp for three-phase service.
The rated capacity of the customer's equipment will be the rated
horsepower output of standard rated motors, the rated horsepower of
welders determined in accordance with the section designated Welder
Service in Rule No.2, and the rated kilovolt-ampere input capacity of
other equipment, with each kilovolt-ampere of input considered equal
to one horsepower. Normally such ratings will be based on the
manufacturer's rating as shown on the nameplate or elsewhere but may,
at the option of the Company, be based on tests or other reliable
information.
(Continued)
Sched ule No. PA-2
POWER-AGRICULTURAL AND PUMPING
DEMAND BASIS
APPLICABILITY
Applicable to power service for general agric~ltural purposes or
for general water or sewerage pumping.
TERRITORY
Within the city limits of the City of Vernon.
RATES
Demand Char'ge:
First 75 KW or less of billing demand.....
All excess KW of billing demand, per KW...
Per Meter
Per Month
$ 420.00
$ 5.60
Energy Charges (to be added to Demand Charge):
6.13t
Minimum Charge:
The monthly minimum charge shall be the monthly Demand Charge.
SPECIAL CONDITIONS
1. Voltage: Service will be supplied at one standard voltage.
{. 2. Billing Demand: The billing demand shall be the kilowatts of
maximum demand but not less than 50% of the highest maximum demand
established in the preceding eleven months, however, in no case shall
the billing demand be less than 75 KW. Billing demand shall be
determined to the nearest 1/10 KW.
3. Maximum Demand: The maximum demand in any month shall be the
measured maximum average kilowatt input, indicated or recorded by
instruments to be supplied by the Company, during any 15-minute
metered interval in the month. but not less than the diversified
resistance welder load computed in accordance with the section
designated Welder Service in Rule No.2. Where demand is intermittent
or subject to violent fluctuations, a 5-minute interval may be used.
4. Power Factor Adjustment: When the billing demand has exceeded
200 KW for three consecutive months, a kilovar-hour meter will be
installed as soon as practical, and, therefore, until the billing
demand has been less than 150 KW for twelve consecutive months, the
charges will be adjusted each month for power factor, as follows:
(Contined)
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Schedule No. S
STANDBY
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APPLICABILITY
Applicable to standby or breakdown service where the entire elec-
trical requirements on the customer's premises are not regularly
supplied by the utility.
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TERRITORY
Within the city limits of the City of Vernon.
.
RATES
Per Meter
Standby Charge: Per Month
First 20 kW of contract demand, per kW........$ 4.00
All excess kW of demand, per kW...............$ 1.71
.
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The standby charge shall not be less than $20.00 per month.
.
Regular Schedule Charges (to be added to Standby Charge):
All energy charges of the applicable regular service
schedule designated in the service contract plus a charge of
$9.25 per kW of on-peak demand in any month.
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Minimum Charge: The monthly minimum charge shall be the standby
charge plus the regular schedule minimum charge.
SPECIAL CONDITIONS
1. Contract Demand: In case the customer desires the utility to
stand ready to supply the entire connected load of the customer's
plant, or an issolated part thereof, then such maximum load will be
estimated by the utility, based on tests and other information
available. In case the customer desires the utility to stand ready to
supply a number of kilowatts less than the maximum demand of the
entire customer's plant, or an isolated part thereof, then the
customer and the utility shall agree upon the number of kilowatts the
utility will stand ready to supply; and the customer shall, at his own
expense, furnish and install a suitable circuit breaker enclosed in a
steel box equipped with a lock, all to be approved by and under the
sole control of the utility, and adjustment and operation of said
circuit breaker to be in no way interfered with by the customer. This
circuit breaker shall be set to break the connection with the
utility's service when the customer's maximum demand exceeds the
ntlmber of kilowatts which the utility stands ready to supply, in which
case the utility will renew the connections upon due notice.
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2. Contract: This schedule will apply only where the customer
will sign a service contract for at least one year.
(Continued)
Energy Charge (to be added to Customer Charge):
All kWh, per kWh
6.705t
Schedule No. TC-l
TRAFFIC CONTROL SERVICE
APPLICABILITY
Applicable to single-phase service for traffic directional signs
or traffic signal systems located on streets, highways and other
public thoroughfares and to railway crossing and track signals.
TERRITORY
Within the City limits of the City of Vernon.
RATES
PER METER
PER MONTH
Customer Charge:
$ 4. 32
Minimum Charge: The monthly mInImum charge shall be the monthly
Customer charge.
SPECIAL CONDITIONS
1. Voltage: Service willbe supplied at one standard voltage not
t in excess of 240 volts or, at the option of the Company, at 240/480
volts, three wire, single phase.
2. Energy Cost Adjustment: The rates above are subject to
adjustment as provided for in Part G of the Preliminary Statement.
The applicable energy cost adjustment billing factors and fuel
collection balance adjustment billing factor set forth therein will be
applied to kWh billed under this schedule.
Vel'non Schedule No. SC
SPECIAL CONTRACT
APPLICABILITY
This schedule is applicable when (1) any customer's maximum demand
exceeds 10,000 kW for any month during the preceding 12 months; or (2)
in the opinion of the City, the customer offers to enter into a
contract wherein the customer's load and use characteristics are
altered during peak demand periods and said alterations provide cost
reductions to the City of Vernon. .
TERRITORY
Within the city limits of the City of Vernon.
RATES
Rates are to be established pursuant to contract and shall recover
all cost incurred in the delivery of said service.
SPECIAL CONDITIONS
1. Conditions: Conditions are to be established pursuant to
contract, however, in the event said contract is not complied with
then all electrical services supplied during the contract period shall
be rebilled at the following rates with a credit allowed for payments
received pursuant to the contract.
RATES:
PER METER
PER MONTH
Demand Charge:
All kWs, per kW
$ 10.00
Energy Charge (to be added to
Demand Charge):
5.185t
2. Energy Cost Adjustment: The rates above are subject to adjust-
ment as provided for in Part G of the Preliminary Statement. The
applicable energy cost adjustment billing factor and fuel collection
balance adjustment billing factor set forth therein will be applied to
kWh billed under this schedule.
Schedule No. SE
SERVICE ESTABLISHMENT CHARGE
APPLICABILITY
Applicable to General Set"vice and Domestic Service customers.
TERRITORY
Within the city limits of the City of Vernon.
RATE
For each establishment of electric service..............$5.00
SPECIAL CONDITIONS
1. The service establishment charge provided for herein is in
addition to the charges calculated in accordance with the applicable
schedule and may be made each time an account is established. As used
herein, establishment means each time an account is opened, including
a turn on of electric service or a change of name which requires a
meter reading.
2. In case the customer requests that electric service be
established on the day of his request or outside of regular business
hours, an additional charge of $5.00 may be made.
3. The service establishment charge is not applicable by customers
of the Company to service rendered through submeters to tenants.
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SERVICE ESTABLISHMENT CHARGE
Schedule No. SE
APPLICABILITY
Applicable to General Se,'vice and Domestic Service customers.
TERRITORY
Within the city limits of the City of Vernon.
RATE,
For each establishment of electric service..............$5.00
SPECIAL CONDITIONS
1. The service establishment charge provided for herein is in
addition to the charges calculated in accordance with the applicable
schedule and may be made each time an account is established. As used
herein, establishment" means each time an account is opened, including
a turn on of electric service or a change of name which requires a
meter reading.
2. In case the customer requests that electric service be
established on the day of his request or outside of regular business
hours, an additional charge of $5.00 may be made.
3. The service establishment charge is not applicable by customers
of the Company to service rendered through submeters to tenants.
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Commencing at 12:01 a.m. November 1 and continuing through April 30 of
the following year, each exclusive of holidays. Holidays include New
Year's Day, Washington's Birthday, Memorial Day, Independence Day,
Labor Day, Veteran's Day, Thanksgiving Day, and Christmas.
SECTION 3: Billin~ Demand.
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The billing demand shall be the kilowatts of maximum "on-peak"
demand established during the time this contract is in effect.
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SECTION 4: Maximum Demand.
The maximum demand in any month shall be measured maximum average
kilowatt imput, indicated or recorded by instruments to be supplied by
City, during any 30-minute metered interval in the month. Where
demand is intermittent or subject to violent fluctuations, a 5-minute
interval may be used.
SECTION 5: Rates.
Byron Jackson agrees to pay the following rates during the terms
of this Agreement and City agrees to make the following charges
during the term of this Agreement.
A. KINETIC METER FACILITY (ACCOUNT 19522005)
PER METER
PER MONTH
Customer Charge:
$ 30,780.00
Demand Charge:
All KWS of billing demand, per KW
$
8.00
Energy Charge (to be added to demand
charge) :
All KWH, per KWH
5.06215
Added Facilities Charge:
Added facilities charge pursuant to
Ordinance No. 911 shall continue to
be applicable
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Energy Charge (to be added to demand charge):
All KWH, per KWH
5.261t!
Minimum Charge:
Tne monthly minimum charge shall be
the monthly customer charge
Energy Cost Adjustment Billing Factor:
All energy used shall be charged the then
current energy adjustment billing demand
factor adopted by resolution of the City
Council. Said energy adjustment billing
demand factor shall be applied to the
energy consumed by Byron Jackson (kinetic
Meter Facility) in the same fashion as if
Byron Jackson (Kinetic Meter Facility) were
still part of the A-8 classification.
Power Factor Adjustment:
The charges will be adjusted each month for
reactive demand. The charges will be increased
by twenty cents (20t!) per kilovar of maximum
reactive demand imposed on the utility in excess
of twenty percent (20~) of the number of
kilowatts of billing demand.
The maximum reactive demand shall be the highest
co-incident measured maximum average kilovar
demand, indicated or recorded by metering to be
supplied by the utility during any 30-minute
metered interval in the month. The kilovars
shall be determined to the nearest unit. A
device will be installed on each kilovar meter to
prevent reverse operation of the meter.
B. BYRON JACKSON ("BEE JAY") METER FACILITY (Account #9523015)
)
PER METER
PER MONTH
Customer Charge:
$13,680.00
Demand Charge:
All KWS of billing demand, per KW
$
8.00
Added Facilities Charge:
Added facilities charge pursuant to
Ordinance No. 911 shall continue
to be applicable
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CITY OF VERNON
for service which will not reimburse the City for all of its costs
associated with providing said service to Steel Casting.
SECTION 12: Off-Peak Demand.
Steel Casting's maximum demand during the off-peak periods shall
be 4,000 kW.
IN WITNESS WHEREOF the parties hereto have executed this Contract,
or caused it to be executed as of the day, month and year first above
written.
~
Leonis C. Malburg, Mayor
ATTEST:
By
Bruce V. Malkenhorst, City Clerk
. STEEL CASTING COMPANY
By
APPROVED AS TO FORM:
By
David B. Brearley, City Attorney
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Energy Charge (to be added to demand charge):
All KWH, per KWH 5.062c
Added Facilities Charge:
Added facilities charge pursuant to Ordinance
No. 911 shall continue to be applicable.
Minimum Charge:
The monthly minimum charge shall be the
monthly demand.
Energy Cost Adjustment Billing Factor:
All energy used shall be charged the then current
energy adjustment billing demand factor adopted
by resolution of the City Council. Said energy
adjustment billing demand factor shall be applied
to the energy consumed by Steel Casting in the
same fashion as if Steel Casting were still part
of the A-8 classification.
Power Factor Adjustment:
The charge will be adjusted each month for
reactive demand. The charges will be increased
by twenty cents (20i) per kilovar of maximum
'reactive demand imposed on the utility in excess
of twenty percent (20%) of the number of
kilowatts of billing demand.
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The maximum reactive demand shall be the highest
co-incident measured maximum average kilovar
demand, indicated or recorded by metering to be
supplied by the utility during any 30-minute
metered interval in the month. The kilovars
shall be determined to the nearest unit. A
device will be installed on each kilovar meter to
prevent reverse operation of the meter.
SECTION 6: Voltage Service.
Service will be supplied only at 66,000 volts of service.
SECTION 7: Temporatry Discontinuance of Service.
Where the use of energy is seasonable or intermittent, no
adjustments will be made for a temporary discontinuance of
service. The customer prior to resuming service, after such
service was discontinued, shall be required to pay all charges
which would have been billed if the service
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the following year, each exclusive of holidays. Holidays include
New Year's Day, Washington's Birthday, Memorial Day, Independence
Day, Labor Day, Veteran's Day, Thanksgiving Day, and Christmas.
SECTION 3: Billing Demand.
The billing demand shall be the kilowatts of max imum
"on-peak" demand established during the time this contract is in
effect.
SECTION 4: Maximum Demand.
The maximum demand in any month shall be measured maximum
average kilowatt imput, indicated or recorded by instruments to
be supplied by City, during any 30-minute metered interval in the
month. Where demand is intermittent or subject to violent
fluctuations, a 5-minute interval may be used.
SECTION 5: Rates.
Bethlehem Steel agrees to pay the following rates during the
terms of this Agreement and City agrees to make the following
Charges during the term of this Agreement.
Demand Charge
PER METER
PER MONTH
First 6,000 KWS or less of billing demand
All excess KWS of billing demand, per KW
$135,000.00
$ 8.00
Energy Charge (to be added to Demand Charge):
All KWH, per KWH
5. OBi
Minimum Charge:
The monthly minimum charge shall be the monthly demand
Energy Cost Adjustment Billing Factor:
All energy used shall be charged the then current
energy adjustment billing demand factor adopted by
resolution of the City Council. Said energy
adjustment billing demand factor shall be applied
to the energy consumed by Bethlehem Steel in the
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this Contract.
SECTION 10: Term of Contract.
This Contract shall be effective on January 15, 1982 and
shall continue through December 31, 1982. However, in the event
that the Federal Energy Regulatory Commission or Southern
California Edison Company takes any action which would increase
the cost of providing said services to the City, then the City
shall be permitted to adjust the rates provided for above in
order to recover any such additional increases in costs.
Bethlehem Steel shall have the right to reopen negotiations
on the rate structure should its business picture change.
SECTION 11: Special Conditions.
All conditions of the Vernon A-8 Schedule as authorized by
City Ordinance Nos. 895, 898, 905 and 911 except where
inconsistent with any of the conditions provided for herein,
shall be in effect. In the event there is a dispute shall be
resolved by agreement of the parties under no circumstances shall
the City be obligated to apply a rate for services which will not
reimburse the City for all of its costs associated with providing
said service to Bethlehem Steel.
SECTION 12: Off-Peak Demand.
Bethlehem's maximum demand during the off-peak periods shall
be 60,000 kW.
CITY OF VERNON
for service which will not reimburse the City for all of its costs
associated with providing said service to Steel Casting.
SECTION 12: Off-Peak Demand.
Steel Casting's maximum demand during the off-peak periods shall
be 4,000 kW.
IN WITNESS WHEREOF the parties hereto have executed this Contract,
or caused it to be executed as of the day, month and year first above
written.
By
Leonis C. Malburg, Mayor
ATTEST:
By
Bruce V. Malkenhorst, City Clerk
. STEEL CASTING COMPANY
By
APPROVED AS TO FORM:
By
David B. Brearley, City Attorney
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